CO<sub>2</sub> Foamed Viscoelastic Gel-Based Seawater Fracturing Fluid for High-Temperature Wells
This study investigates the development of a novel CO<sub>2</sub>-foamed viscoelastic gel-based fracturing fluid to address the challenges of high-temperature formations. The influence of various parameters, including surfactant type and concentration, gas fraction, shear rate, water sal...
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| Format: | Article |
| Language: | English |
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MDPI AG
2024-11-01
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| Series: | Gels |
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| Online Access: | https://www.mdpi.com/2310-2861/10/12/774 |
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| author | Jawad Al-Darweesh Murtada Saleh Aljawad Muhammad Shahzad Kamal Mohamed Mahmoud Shabeeb Alajmei Prasad B. Karadkar Bader G. Harbi |
| author_facet | Jawad Al-Darweesh Murtada Saleh Aljawad Muhammad Shahzad Kamal Mohamed Mahmoud Shabeeb Alajmei Prasad B. Karadkar Bader G. Harbi |
| author_sort | Jawad Al-Darweesh |
| collection | DOAJ |
| description | This study investigates the development of a novel CO<sub>2</sub>-foamed viscoelastic gel-based fracturing fluid to address the challenges of high-temperature formations. The influence of various parameters, including surfactant type and concentration, gas fraction, shear rate, water salinity, temperature, and pressure, on foam viscosity was systematically explored. Rheological experiments were conducted using a high-pressure/high-temperature (HPHT) rheometer at 150 °C and pressures ranging from 6.89 to 20.68 MPa. To simulate field conditions, synthetic high-salinity water was employed. The thermal stability of the CO<sub>2</sub> foam was evaluated at a constant shear rate of 100 1/s for 180 min. Additionally, foamability and foam stability were assessed using an HPHT foam analyzer at 100 °C. The results demonstrate that liquid phase chemistry, experimental conditions, and gas fraction significantly impact foam viscosity. Viscoelastic surfactants achieved a peak foam viscosity of 0.183 Pa·s at a shear rate of 100 1/s and a 70% foam quality, surpassing previous records. At lower foam qualities (≤50%), pressure had a negligible effect on foam viscosity, whereas at higher qualities, it increased viscosity by over 30%. While a slight increase in viscosity was observed with foam qualities between 40% and 60%, a significant enhancement was noted at 65% foam quality. The addition of polymers did not improve foam viscosity. The generation of viscous and stable foams is crucial for effective proppant transport and fracture induction. However, maintaining the thermal stability of CO<sub>2</sub> foams with minimal additives remains a significant challenge in the industry. This laboratory study provides valuable insights into the development of stable CO<sub>2</sub> foams for stimulating high-temperature wells. |
| format | Article |
| id | doaj-art-c8dd8ecd915041c69dcc5a939f4c4125 |
| institution | OA Journals |
| issn | 2310-2861 |
| language | English |
| publishDate | 2024-11-01 |
| publisher | MDPI AG |
| record_format | Article |
| series | Gels |
| spelling | doaj-art-c8dd8ecd915041c69dcc5a939f4c41252025-08-20T02:00:46ZengMDPI AGGels2310-28612024-11-01101277410.3390/gels10120774CO<sub>2</sub> Foamed Viscoelastic Gel-Based Seawater Fracturing Fluid for High-Temperature WellsJawad Al-Darweesh0Murtada Saleh Aljawad1Muhammad Shahzad Kamal2Mohamed Mahmoud3Shabeeb Alajmei4Prasad B. Karadkar5Bader G. Harbi6Department of Petroleum Engineering, King Fahd University of Petroleum & Minerals, Dhahran 31261, Saudi ArabiaDepartment of Petroleum Engineering, King Fahd University of Petroleum & Minerals, Dhahran 31261, Saudi ArabiaCenter for Integrative Petroleum Research, King Fahd University of Petroleum & Minerals, Dhahran 31261, Saudi ArabiaDepartment of Petroleum Engineering, King Fahd University of Petroleum & Minerals, Dhahran 31261, Saudi ArabiaDepartment of Petroleum Engineering, King Fahd University of Petroleum & Minerals, Dhahran 31261, Saudi ArabiaEXPECR ARC, Saudi Aramco, Dhahran 31311, Saudi ArabiaEXPECR ARC, Saudi Aramco, Dhahran 31311, Saudi ArabiaThis study investigates the development of a novel CO<sub>2</sub>-foamed viscoelastic gel-based fracturing fluid to address the challenges of high-temperature formations. The influence of various parameters, including surfactant type and concentration, gas fraction, shear rate, water salinity, temperature, and pressure, on foam viscosity was systematically explored. Rheological experiments were conducted using a high-pressure/high-temperature (HPHT) rheometer at 150 °C and pressures ranging from 6.89 to 20.68 MPa. To simulate field conditions, synthetic high-salinity water was employed. The thermal stability of the CO<sub>2</sub> foam was evaluated at a constant shear rate of 100 1/s for 180 min. Additionally, foamability and foam stability were assessed using an HPHT foam analyzer at 100 °C. The results demonstrate that liquid phase chemistry, experimental conditions, and gas fraction significantly impact foam viscosity. Viscoelastic surfactants achieved a peak foam viscosity of 0.183 Pa·s at a shear rate of 100 1/s and a 70% foam quality, surpassing previous records. At lower foam qualities (≤50%), pressure had a negligible effect on foam viscosity, whereas at higher qualities, it increased viscosity by over 30%. While a slight increase in viscosity was observed with foam qualities between 40% and 60%, a significant enhancement was noted at 65% foam quality. The addition of polymers did not improve foam viscosity. The generation of viscous and stable foams is crucial for effective proppant transport and fracture induction. However, maintaining the thermal stability of CO<sub>2</sub> foams with minimal additives remains a significant challenge in the industry. This laboratory study provides valuable insights into the development of stable CO<sub>2</sub> foams for stimulating high-temperature wells.https://www.mdpi.com/2310-2861/10/12/774viscoelastic surfactantsCO<sub>2</sub> foamthermally stablefracturingproppant transport |
| spellingShingle | Jawad Al-Darweesh Murtada Saleh Aljawad Muhammad Shahzad Kamal Mohamed Mahmoud Shabeeb Alajmei Prasad B. Karadkar Bader G. Harbi CO<sub>2</sub> Foamed Viscoelastic Gel-Based Seawater Fracturing Fluid for High-Temperature Wells Gels viscoelastic surfactants CO<sub>2</sub> foam thermally stable fracturing proppant transport |
| title | CO<sub>2</sub> Foamed Viscoelastic Gel-Based Seawater Fracturing Fluid for High-Temperature Wells |
| title_full | CO<sub>2</sub> Foamed Viscoelastic Gel-Based Seawater Fracturing Fluid for High-Temperature Wells |
| title_fullStr | CO<sub>2</sub> Foamed Viscoelastic Gel-Based Seawater Fracturing Fluid for High-Temperature Wells |
| title_full_unstemmed | CO<sub>2</sub> Foamed Viscoelastic Gel-Based Seawater Fracturing Fluid for High-Temperature Wells |
| title_short | CO<sub>2</sub> Foamed Viscoelastic Gel-Based Seawater Fracturing Fluid for High-Temperature Wells |
| title_sort | co sub 2 sub foamed viscoelastic gel based seawater fracturing fluid for high temperature wells |
| topic | viscoelastic surfactants CO<sub>2</sub> foam thermally stable fracturing proppant transport |
| url | https://www.mdpi.com/2310-2861/10/12/774 |
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