Adsorption of a Switchable Cationic Surfactant on Natural Carbonate Minerals

SPE Journal ◽  
2014 ◽  
Vol 20 (01) ◽  
pp. 70-78 ◽  
Author(s):  
Leyu Cui ◽  
Kun Ma ◽  
Ahmed A. Abdala ◽  
Lucas J. Lu ◽  
Ivan Tanakov ◽  
...  
Keyword(s):  
High Pressure ◽  
Nonionic Surfactant ◽  
Cationic Surfactant ◽  
Divalent Cations ◽  
Surfactant Solution ◽  
Mobility Control ◽  
Carbonate Formation ◽  
Surfactant Precipitation ◽  
High Pressure Co2 ◽  
Carbon Dioxide Co2

Summary A switchable cationic surfactant (e.g., tertiary amine surfactant Ethomeen C12) was previously described as a surfactant that one can inject in high-pressure carbon dioxide (CO2) for foam-mobility control. C12 can dissolve in high-pressure CO2 as a nonionic surfactant and equilibrate with brine as a cationic surfactant. Here, we describe the adsorption characteristics of this surfactant in carbonate-formation materials. The adsorption of this surfactant is sensitive to the equilibrium pH, the electrolyte composition of the brine, and the minerals in carbonate-formation materials. Pure C12 is a nonionic surfactant. When it is mixed with brine, the solution has a high pH and limited solubility. However, when the surfactant solution in brine is equilibrated with high-pressure CO2, the pH is approximately 4; the surfactant switches to a cationic surfactant and becomes soluble. Thus, the adsorption is also a function of pH. The adsorption of C12 on calcite at low pH is low (e.g., 0.5 mg/m2). However, if the carbonate formation contains silica or clays, the adsorption is high, as is typical for cationic surfactants. The adsorption of C12 on silica decreases with an increase in divalent (Ca2+ and Mg2+) and trivalent (Al3+) cations. This is because of the competition for the negatively charged silica sites between the multivalent cations and the monovalent cationic surfactant. An additional effect of the presence of divalent cations in the brine is that it reduces the dissolution of calcite or dolomite in the presence of high-pressure CO2. The dissolution of calcite and dolomite is harmful because of formation damage and increased alkalinity. The latter raises the pH and thus increases the adsorption of C12 or even causes surfactant precipitation.

Evaluation of a Nonionic Surfactant Foam for CO2 Mobility Control in a Heterogeneous Carbonate Reservoir

SPE Journal ◽  
2020 ◽  
Vol 25 (06) ◽  
pp. 3481-3493
Author(s):  
Guoqing Jian ◽  
Zachary Alcorn ◽  
Leilei Zhang ◽  
Maura C. Puerto ◽  
Samaneh Soroush ◽  
...  
Keyword(s):  
Nonionic Surfactant ◽  
Computer Modelling ◽  
Surfactant Solution ◽  
Carbonate Reservoir ◽  
Mobility Control ◽  
Oxygen Scavenger ◽  
Fractional Flow ◽  
Foam Flow ◽  
Co2 Foam ◽  
Flow Test

Summary In this paper, we describe a laboratory investigation of a nonionic surfactant for carbon dioxide-(CO2-) foam mobility control in the East Seminole field, a heterogeneous carbonate reservoir in the Permian Basin of west Texas. A method of high-performance liquid chromatography-evaporativelight-scattering detector (HPLC-ELSD) was followed for characterizing the surfactant stability. The foam transport process was studied in the absence and the presence of East Seminole crude oil, with test results showing that strong CO2-foam forms in either a bulk-foam test or foam-flow test. An oxygen scavenger, carbohydrazide, was found effective for controlling the stability of the surfactant up to 80°C and total dissolved solid of ∼34,000 ppm. Moreover, a phosphonate scale inhibitor was investigated and found to be compatible with the oxygen scavenger to accommodate a surfactant solution in a gypsum-oversaturated reservoir brine. During the oil-fractional flow test, an emulsion appears to form, causing a noticeable pressure increase; however, emulsion generation failed to cause a significant phase plugging in the test. Also, a STARS™ (Computer Modelling Group Ltd., Calgary, Alberta, Canada) foam model was applied to obtain the foam parameters from the foam-flow experiments at steady-state conditions. The insights from laboratory experiments better enable translation of the foam technology to the field.

Surfactant Prefloods During Carbon Dioxide Foam Injection for Integrated Enhanced Oil Recovery in Fractured Oil-Wet Carbonates

SPE Journal ◽  
2019 ◽  
Vol 24 (03) ◽  
pp. 1139-1153 ◽  
Author(s):  
S. B. Fredriksen ◽  
Z. P. Alcorn ◽  
A.. Frøland ◽  
A.. Viken ◽  
A. U. Rognmo ◽  
...  
Keyword(s):  
Carbon Dioxide ◽  
Enhanced Oil Recovery ◽  
Oil Recovery ◽  
Surfactant Solution ◽  
Mobility Control ◽  
Threshold Pressure ◽  
Oil Saturation ◽  
Co2 Foam ◽  
Matrix Blocks ◽  
Carbon Dioxide Co2

Summary An integrated enhanced-oil-recovery (EOR) (IEOR) approach is used in fractured oil-wet carbonate core plugs where surfactant prefloods reduce interfacial tension (IFT), alter wettability, and establish conditions for capillary continuity to improve tertiary carbon dioxide (CO2) foam injections. Surfactant prefloods can alter the wettability of oil-wet fractures toward neutral/weakly-water-wet conditions that in turn reduce the capillary threshold pressure for foam generation in matrix and create capillary contact between matrix blocks. The capillary connectivity can transmit differential pressure across fractures and increase both mobility control and viscous displacement during CO2-foam injections. Outcrop core plugs were aged to reflect conditions of an ongoing CO2-foam injection field pilot in west Texas. Surfactants were screened for their ability to change the wetting state from oil-wet using the Darcy-scale Amott-Harvey index. A cationic surfactant was the most effective in shifting wettability from an Amott-Harvey index of –0.56 to 0.09. Second waterfloods after surfactant treatments and before tertiary CO2-foam injections recovered an additional 4 to 11% of original oil in place (OIP) (OOIP), verifying the favorable effects of a surfactant preflood to mobilize oil. Tertiary CO2-foam injections revealed the significance of a critical oil-saturation value below which CO2 and surfactant solution were able to enter the oil-wet matrix and generate foam for EOR. The results reveal that a surfactant preflood can reverse the wettability of oil-wet fracture surfaces, lower IFT, and lower capillary threshold pressure to reduce oil saturation to less than a critical value to generate stable CO2 foam.

Green approach for fabrication of bacterial cellulose-chitosan composites in the solutions of carbonic acid under high pressure CO2

2021 ◽  
Vol 258 ◽  
pp. 117614
Author(s):  
Ilya V. Novikov ◽  
Marina A. Pigaleva ◽  
Alexander V. Naumkin ◽  
Gennady A. Badun ◽  
Eduard E. Levin ◽  
...  
Keyword(s):  
High Pressure ◽  
Bacterial Cellulose ◽  
Carbonic Acid ◽  
Green Approach ◽  
High Pressure Co2

An experimental study on the flow characteristics during the leakage of high pressure CO2 pipelines

2019 ◽  
Vol 125 ◽  
pp. 92-101 ◽  
Author(s):  
Shuaiwei Gu ◽  
Yuxing Li ◽  
Lin Teng ◽  
Cailin Wang ◽  
Qihui Hu ◽  
...  
Keyword(s):  
Experimental Study ◽  
High Pressure ◽  
Flow Characteristics ◽  
High Pressure Co2

Cross-linked open-pore elastic hydrogels based on tropoelastin, elastin and high pressure CO2

Biomaterials ◽  
2010 ◽  
Vol 31 (7) ◽  
pp. 1655-1665 ◽  
Author(s):  
Nasim Annabi ◽  
Suzanne M. Mithieux ◽  
Anthony S. Weiss ◽  
Fariba Dehghani
Keyword(s):  
High Pressure ◽  
High Pressure Co2

Open and closed forms of the interpenetrated [Cu2(Tae)(Bpa)2](NO3)2·nH2O: magnetic properties and high pressure CO2/CH4 gas sorption

2018 ◽  
Vol 47 (3) ◽  
pp. 958-970
Author(s):  
Roberto Fernández de Luis ◽  
Edurne S. Larrea ◽  
Joseba Orive ◽  
Arkaitz Fidalgo-Marijuan ◽  
Luis Lezama ◽  
...  
Keyword(s):  
High Pressure ◽  
Magnetic Properties ◽  
Porous Structure ◽  
Open Form ◽  
Gas Sorption ◽  
Solvent Loss ◽  
High Pressure Co2 ◽  
Dynamic Aperture ◽  
Volume Cell

Cationic [Cu2(Tae)(Bpa)2]2+[NO3]22−·nH2O interpenetrated networks show a solvent loss triggering dynamic aperture of the porous structure from a closed to an open form with a difference of 29% of the volume cell.

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