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Taufan Marhaendrajana, Taufan
Institut Teknologi Bandung
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Journal : Journal of Engineering and Technological Sciences

 1 
The Effect of Surfactant Characteristics on IFT to Improve Oil Recovery in Tempino Light Oil Field Indonesia Swadesi, Boni; Marhaendrajana, Taufan; Mucharam, Leksono; Siregar, H.P. Septoratno
Journal of Engineering and Technological Sciences Vol 47, No 3 (2015)
Publisher : ITB Journal Publisher, LPPM ITB

Show Abstract | Download Original | Original Source | Check in Google Scholar | Full PDF (208.089 KB) | DOI: 10.5614/j.eng.technol.sci.2015.47.3.2

Abstract

Water injection has been employed in the Tempino oil field since 1996. The current oil recovery factor is 35% of OOIP. Even though the pressure is still high, the oil production rate has declined rapidly and the water cut is approaching 89%. In order to mobilize  the  oil from the  reservoir  more effectively, surfactant flooding is one of the solutions that can reduce residual oil saturation. Interaction between crude oil and compatible surfactant generates microemulsion,  as an indication of low interfacial tension. Hence the oil is expected to move out of the pore throat easily. In this research, thirty types of surfactants  were evaluated. The hydrophilic  lipophilic  balance (HLB)  was calculated and  the  interfacial tension (IFT)  with the  reservoir fluid  was measured. HLB criteria were established as an indicator of low IFT, which was then tested for Berea core flooding. The results indicate that an HLB between approximately 2.7 and 3.1 (on Davies’ Scale) or greater than 11.5 (on Griffin’s Scale) gives  low IFT  (~10-3 dynes/cm).  This characteristic  is possesed by surfactant  ethoxy  carboxylate  with a  linear hydrophobic structure.  This surfactant produces a high incremental oil recovery according to Berea core flood tests. The AN2NS and AN3 surfactants recovered 90% and 86% of OOIP respectively.
Surfactant-Polymer Coreflood Simulation and Uncertainty Analysis Derived from Laboratory Study Hakiki, Farizal; Maharsi, Dara Ayuda; Marhaendrajana, Taufan
Journal of Engineering and Technological Sciences Vol 47, No 6 (2015)
Publisher : ITB Journal Publisher, LPPM ITB

Show Abstract | Download Original | Original Source | Check in Google Scholar | Full PDF (767.754 KB) | DOI: 10.5614/j.eng.technol.sci.2015.47.6.9

Abstract

This paper presents a numerical simulation study on coreflood scale derived from a laboratory study conducted on light oil and water-wet sandstone samples from fields at Tempino and Kenali Asam, Sumatra, Indonesia. A rigorous laboratory study prompted a specified surfactant type among dozens of screened samples, i.e. AN3NS and AN2NS-M for Kenali Asam and Tempino, respectively. The coreflood scale numerical simulation study was performed using a commercial simulator, on the basis of the results from the laboratory study, at a constant temperature of 68°C, 0.3 cc/min injection rate and under 120 psia confining pressure. To get better recovery, the cores were tested using surfactant and polymer in a blended mode, containing 0.03% w/w polymer diluted in each field brine, which accommodated around 8000 ppm salinity. The most significant variable in the multiphase flow is the relative permeability curve, which is affected by interfacial tension (IFT) during waterflooding and surfactant-polymer (SP) flooding. This study shows that relative permeability will be shifted at ultra-low IFT (10-3 to 10-4 mN/m). This shifting phenomenon is governed by the interpolation parameter set, which implicitly represents the capillary number. Further work in matching the numerical results to the coreflood was conducted by changing the interpolation parameters.
Wettability Alteration Induced by Surface Roughening During Low Salinity Waterflooding Marhaendrajana, Taufan; Ridwan, Muhammad Ghifari; Kamil, Maulana Insan; Permadi, Pudji
Journal of Engineering and Technological Sciences Vol 50, No 5 (2018)
Publisher : ITB Journal Publisher, LPPM ITB

Show Abstract | Download Original | Original Source | Check in Google Scholar | Full PDF (14.19 KB) | DOI: 10.5614/j.eng.technol.sci.2018.50.5.4

Abstract

Wettability alteration during low salinity waterflooding (LSW) is expected to be one of the prominent reasons for enhanced oil recovery. However, the underlying mechanisms of improved oil recovery in sandstone during LSW are not entirely clear. Thus, a series of experiments was carried out to investigate the underlying mechanisms that drive the wettability alteration. FTIR spectroscopy was combined with thermogravimetric analysis to quantify the amount of adsorbed hydrocarbon components in sandstone with various clay contents. Afterward, the time-dependent contact angle in fabricated sandstone substrate (RMS roughness 9.911.31) was observed with various clay and brine contents to monitor the wettability alteration during LSW. The existence of divalent ions (Ca2+ and Mg2+) was found to stabilize the sandstone and prevent it from swelling. Surprisingly, with the presence of divalent ions, the rate of contact angle change was insignificant (, even though a reduction of divalent ions occurred and the rate of contact angle change with the sole presence of NaCl was notably altered (. Furthermore, the presence of higher clay content showed an increased contact angle alteration. We propose that these phenomena are partially driven by macroscopic phenomena of clay swelling, which leads to surface roughening and enhances the water-wetness.
The Effect of Surfactant Characteristics on IFT to Improve Oil Recovery in Tempino Light Oil Field Indonesia Boni Swadesi; Taufan Marhaendrajana; Leksono Mucharam; H.P. Septoratno Siregar
Journal of Engineering and Technological Sciences Vol. 47 No. 3 (2015)
Publisher : Institute for Research and Community Services, Institut Teknologi Bandung

Show Abstract | Download Original | Original Source | Check in Google Scholar | DOI: 10.5614/j.eng.technol.sci.2015.47.3.2

Abstract

Water injection has been employed in the Tempino oil field since 1996. The current oil recovery factor is 35% of OOIP. Even though the pressure is still high, the oil production rate has declined rapidly and the water cut is approaching 89%. In order to mobilize  the  oil from the  reservoir  more effectively, surfactant flooding is one of the solutions that can reduce residual oil saturation. Interaction between crude oil and compatible surfactant generates microemulsion,  as an indication of low interfacial tension. Hence the oil is expected to move out of the pore throat easily. In this research, thirty types of surfactants  were evaluated. The hydrophilic  lipophilic  balance (HLB)  was calculated and  the  interfacial tension (IFT)  with the  reservoir fluid  was measured. HLB criteria were established as an indicator of low IFT, which was then tested for Berea core flooding. The results indicate that an HLB between approximately 2.7 and 3.1 (on Davies' Scale) or greater than 11.5 (on Griffin's Scale) gives  low IFT  (~10-3 dynes/cm).  This characteristic  is possesed by surfactant  ethoxy  carboxylate  with a  linear hydrophobic structure.  This surfactant produces a high incremental oil recovery according to Berea core flood tests. The AN2NS and AN3 surfactants recovered 90% and 86% of OOIP respectively.
Surfactant-Polymer Coreflood Simulation and Uncertainty Analysis Derived from Laboratory Study Farizal Hakiki; Dara Ayuda Maharsi; Taufan Marhaendrajana
Journal of Engineering and Technological Sciences Vol. 47 No. 6 (2015)
Publisher : Institute for Research and Community Services, Institut Teknologi Bandung

Show Abstract | Download Original | Original Source | Check in Google Scholar | DOI: 10.5614/j.eng.technol.sci.2015.47.6.9

Abstract

This paper presents a numerical simulation study on coreflood scale derived from a laboratory study conducted on light oil and water-wet sandstone samples from fields at Tempino and Kenali Asam, Sumatra, Indonesia. A rigorous laboratory study prompted a specified surfactant type among dozens of screened samples, i.e. AN3NS and AN2NS-M for Kenali Asam and Tempino, respectively. The coreflood scale numerical simulation study was performed using a commercial simulator, on the basis of the results from the laboratory study, at a constant temperature of 68°C, 0.3 cc/min injection rate and under 120 psia confining pressure. To get better recovery, the cores were tested using surfactant and polymer in a blended mode, containing 0.03% w/w polymer diluted in each field brine, which accommodated around 8000 ppm salinity. The most significant variable in the multiphase flow is the relative permeability curve, which is affected by interfacial tension (IFT) during waterflooding and surfactant-polymer (SP) flooding. This study shows that relative permeability will be shifted at ultra-low IFT (10-3 to 10-4 mN/m). This shifting phenomenon is governed by the interpolation parameter set, which implicitly represents the capillary number. Further work in matching the numerical results to the coreflood was conducted by changing the interpolation parameters.
Wettability Alteration Induced by Surface Roughening During Low Salinity Waterflooding Taufan Marhaendrajana; Muhammad Ghifari Ridwan; Maulana Insan Kamil; Pudji Permadi
Journal of Engineering and Technological Sciences Vol. 50 No. 5 (2018)
Publisher : Institute for Research and Community Services, Institut Teknologi Bandung

Show Abstract | Download Original | Original Source | Check in Google Scholar | DOI: 10.5614/j.eng.technol.sci.2018.50.5.4

Abstract

Wettability alteration during low salinity waterflooding (LSW) is expected to be one of the prominent reasons for enhanced oil recovery. However, the underlying mechanisms of improved oil recovery in sandstone during LSW are not entirely clear. Thus, a series of experiments was carried out to investigate the underlying mechanisms that drive the wettability alteration. FTIR spectroscopy was combined with thermogravimetric analysis to quantify the amount of adsorbed hydrocarbon components in sandstone with various clay contents. Afterward, the time-dependent contact angle in fabricated sandstone substrate (RMS roughness 9.911.31) was observed with various clay and brine contents to monitor the wettability alteration during LSW. The existence of divalent ions (Ca2+ and Mg2+) was found to stabilize the sandstone and prevent it from swelling. Surprisingly, with the presence of divalent ions, the rate of contact angle change was insignificant (, even though a reduction of divalent ions occurred and the rate of contact angle change with the sole presence of NaCl was notably altered (. Furthermore, the presence of higher clay content showed an increased contact angle alteration. We propose that these phenomena are partially driven by macroscopic phenomena of clay swelling, which leads to surface roughening and enhances the water-wetness.
Correlation between Phase Behavior and Interfacial Tension for Mixtures of Amphoteric and Nonionic Surfactant with Waxy Oil Rani Kurnia; Deana Wahyuningrum; Doddy Abdassah; Taufan Marhaendrajana
Journal of Engineering and Technological Sciences Vol. 53 No. 5 (2021)
Publisher : Institute for Research and Community Services, Institut Teknologi Bandung

Show Abstract | Download Original | Original Source | Check in Google Scholar | DOI: 10.5614/j.eng.technol.sci.2021.53.5.1

Abstract

Phase behavior tests in the surfactant screening process for EOR applications remain one of the relatively convenient ways to design an optimum surfactant formulation. However, phase behavior studies are unable to provide quantitative data for interfacial tension, which is one of the parameters that must be considered when selecting surfactants for EOR. Several studies related to the prediction of interfacial tension through phase behavior testing have been carried out. In this paper, the Huh correlation was used to estimate the interfacial tension value based on phase behavior tests. It was found that the current form of the Huh correlation may be applied for the below-to-optimum salinity condition. Furthermore, the constants of the equation vary depending on the surfactant type and mixtures.  
Design of Magnetron Cooling Method Based on Heat Exchanger System for Microwave Heating Application Gerry Sasanti Nirmala; Doddy Abdassah; Erdilla Indriyani; Anugerah Solida; Sudjati Rachmat; Taufan Marhaendrajana; Achmad Munir
Journal of Engineering and Technological Sciences Vol. 54 No. 3 (2022)
Publisher : Institute for Research and Community Services, Institut Teknologi Bandung

Show Abstract | Download Original | Original Source | Check in Google Scholar | DOI: 10.5614/j.eng.technol.sci.2022.54.3.6

Abstract

Microwave heating is a novel thermal recovery technique developed for heavy oil reservoirs. Particulary in deep reservoirs, it allows more effective thermal recovery to counter heat loss.. The magnetron as a microwave generator works based on cavity resonant vibrations and it needs an appropriate cooling system to avoid damage to its cavity elements. In this paper, the design of a cooling system based on a heat exchanger as well as the investigation of the proper material and coolant to fit the microwave characteristics are proposed.
Co-Authors Achmad Munir Adrianto, Adrianto Anugerah Solida Asri Nugrahanti Billal Aslam Boni Swadesi Dara Ayuda Maharsi Dara Ayuda Maharsi, Dara Ayuda Deana Wahyuningrum Doddy Abdassah Doddy Abdassah Doddy Abdassah Doddy Abdassah Dyah Rini Ratnaningsih Erdilla Indriyani Farizal Hakiki Farizal Hakiki, Farizal Gerry Sasanti Nirmala H.P. Septoratno Siregar H.P. Septoratno Siregar, H.P. Septoratno I GB Eddy Sucipta Kamil, Maulana Insan Kharisma Idea Leksono Mucharam Leksono Mucharam Maulana Insan Kamil Muhammad Ghifari Ridwan Muhammad Hasto Nugroho Muhammad Taufiq Fathaddin, Muhammad Taufiq Onnie Ridaliani Prapansya Pudji Permadi Pudji Permadi, Pudji Rani Kurnia Ridwan, Muhammad Ghifari Rini Setiati Septoratno Siregar Sonny Irawan Sonny Irawan Sri Feni Sri Feni Maulindani Sri Feni Maulindani Sudjati Rachmat Suryo Prakoso, Suryo Sutopo Sutopo Syihab, Zuher Yarra Sutadiwiria Zona Nuansa Antariksa