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Abstrak :
Enhanced Oil Recovery (EOR) merupakan metode tersier yang digunakan untuk meningkatkan produksi minyak bumi. Salah satu teknik yang digunakan dalam EOR yaitu chemical flooding dengan menginjeksikan bahan kimia ke dalam reservoir. Seleksi dilakukan terhadap surfaktan jenis SA (Sodium Lauril Sulfat), surfaktan jenis SB (Polioksietilen alkil eter fosfat) , dan surfaktan jenis SC (Etilen oksida propilen oksida blok kopolimer). Seleksi ini dilakukan berdasarkan 5 paramater uji yaitu Kompatibilitas, Stabilitas Termal, Kelakuan Fasa, Interfacial Tension, dan Imbibisi. Pada konsentrasi 1%, uji kompatibilitas untuk ketiga jenis surfaktan baik. Uji stabilitas termal terhadap surfaktan jenis SA cenderung stabil terhadap pemanasan, surfaktan jenis SB terdegradasi pada hari ke-30, surfaktan jenis SC mencapai cloud point pada hari ke-1 dan terdegradasi pada hari ke-60. Uji kelakuan fasa menghasilkan emulsi fasa bawah untuk ketiga jenis surfaktan. Pengukuran Interfacial Tension untuk surfaktan jenis SA, SB, dan SC berturut-turut yaitu 0,1723 mN/m, 0,0353 mN/m, dan 0,2001 mN/m. Uji Imbibisi menggunakan batuan sintetik (Pasir 70% : semen 30%), menghasilkan recovery oil untuk surfaktan jenis SA, SB, dan SC sebesar 2,09%, 0%, dan 4,16%. Uji Imbibisi menggunakan batuan sintetik (Pasir 90% : semen 10%), menghasilkan recovery oil untuk surfaktan jenis SA, SB, dan SC sebesar 2,42%, 0%, dan 4,69%. Formulasi surfaktan SC dan SA (0,9gr : 0,1gr) pada konsentrasi 1% menghasilkan nilai IFT yang optimal sebesar 0,13 mN/m dan uji Imbibisi menghasilkan recovery oil sebesar 4,84%. ...... Enhanced Oil Recovery (EOR) is a tertiary method used to improve oil production. One of technique is used in chemical EOR is flooding by injecting chemicals into the reservoir. The selection of the surfactant types are SA (Sodium lauryl sulfate), SB (polyoxyethylene alkyl ether phosphate), and SC (Ethylene oxide propylene oxide block copolymers). Selection is done by 5 parameter tests, namely compatibility, thermal stability, phase behavior, Interfacial Tension, and imbibition. At the concentration of 1%, the third compatibility test for both three types of surfactants is are relative good. Thermal stability test of the surfactant types SA tend to be stable against heating, surfactant types SB degraded on 30th day, the surfactant types SC reached the cloud point at day 1 and degraded on the 60th day. Phase behavior test of emulsions give under phase for the three types of surfactants. Measurement of Interfacial Tension for surfactant types SA, SB, and SC are 0.1723 mN/m, 0.0353 mN/m, and 0.2001 mN/m respectively. Imbibition test using synthetic rock (sand 70% : cement 30%), resulting in recovery of oil to surfactant types SA, SB and SC up to 2.09%, 0% and 4.16%. Imbibition test using synthetic rock (sand 90% : cement 10%), resulting in recovery of oil to surfactant types SA, SB, and SC up to 2.42%, 0% and 4.69%. Surfactant formulations of SC and SA (0,9 gr : 0,1 gr) at a concentration of 1% produces optimal IFT value of 0.13 mN / m and test imbibition oil recovery of 4.84%.

Abstrak :
The formation of microemultion in the injection of surfacant at chmical flooding is crucial for the effectiveness of injection. Microemultion can be obtained either by mixing the surfactant and oil at the surface or injecting surfactant into the reservoir to form in situ microemultion. Its transculent homogeneous mixtures of oil and water in the presence of surfacant is believed to displace the remaining oil in the reservoir. Preveriously, we showed the effect of microemultion-based surfactant formulation to reduce the interfacial tension (IFT) of oil and water to the ultralow level that sufficient enough to overcome the capillary pressure in the pore throat and mobilize the residual oil. However, the effectiveness of microemultion flooding to enchance the oil recovery in targeted representative core has not been investigated. In this artice, the performance of microemultion-based surfactant formulation to improve the oil recovery in the reservoir condition was investigated in the laboratory scale trought the core flooding experiment. Microemultion-based formulation consist of 2% surfactant A and 0.85% of alkaline sodium carbonate (Na2CO3) were prepared by mixing with synthetic soften brine (SSB) in the presence of various concentration of polymer for improving the mobility control. The viscocity of surfactant-polymer in the presence of alkaline (ASP) and polymer drive that used for chemical injection slug were measured. The tertiary oil recovery experiment was carried out using core flooding apparatus to study the ability of microemultion-based formulation t recover the oil production. the results showed that polymer at 2200 ppn in the ASP mixture can generate 12.16cP solution which is twice higher than the oil viscosity to prevent the fingering occurence. Whereas single polymer drive at 1300 ppm was able to produce 15.15 cP polymer solution due to the absence of alkaline. Core flooding experiment result with design of injection of 0.15 PV ASP followed by 1.5 PV polymer showed that the additional oil recover after waterflood can be obtained as high as 93.41% of remaining oil saturation after waterflood (Sor), or 57.71%of initial oil saturation (Soi). Those results conclude that the microemultion-based surfactant flooding is the most effective mechanism to achieve the optimum oil recovery in the targeted reservoir

Abstrak :
Surfaktan Alkil Poliglikosida merupakan surfaktan ramah lingkungan yang dapat diproduksi dari bahan baku alkohol lemak dan glukosa dengan bantuan katalis asam p-toluenasulfonat (PTSA). Sifatnya yang nonionik serta tidak terpengaruh terhadap kesadahan dan perubahan pH, menyebabkan surfaktan ini berpotensi untuk dijadikan alternatif surfaktan untuk aplikasi chemical flooding. Tujuan dari penelitian ini adalah mengetahui pengaruh panjang rantai karbon pada alkohol lemak terhadap nilai tegangan antar muka serta kemampuannya untuk mengambil minyak pada saat aplikasi sebagai chemical flooding. Alkohol lemak yang digunakan pada penelitian ini adalah 1-dodekanol dan 1-tetradekanol. Hasil penelitian menunjukkan bahwa APG-C14 memiliki nilai tegangan antar muka yang lebih rendah dibandingkan APG-C12 dikarenakan rantai karbon pada sisi hidrofobik yang lebih panjang. Hal tersebut terlihat dari nilai tegangan antar muka pada konsentrasi surfaktan 3% (b/b) untuk APG-C12 adalah 1,32 x 10-2 dyne/cm, sedangkan APG-C14 adalah 3,72 x 10-4 dyne/cm. Dengan menggunakan metode pengujian tekanan kapiler diketahui nilai minyak yang terambil dari batuan sintetik untuk APG-C12 adalah 10,733% dan APG-C14 adalah 13,797%. Hal ini menunjukkan bahwa APG-C14 memiliki potensi untuk dikembangkan lebih lanjut sebagai chemical flooding.

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Alkylpolyglucosides (APG) is an environment-friendly surfactant prepared from fatty alcohol and glucose with p-toluenesulfonic acid catalyst. This nonionic surfactant does not affected on hard water dan pH changes, makes it potentially used as chemical flooding surfactant. This research has been conducted to determine the effect of carbon chain length of fatty alcohol as APGs hydrophobic side towards interfacial tension and its capability as chemical flooding surfactant. 1-dodecanol and 1-tetradecanol were used as fatty alcohol precursor. The result exhibit APG-C14 has lower interfacial tension than APG-C12 as the effect of longer hydrophobic carbon chain. The phenomenon was observed on interfacial tension of 3% (w/w) APG-C12 1,32 x 10-2 dyne/cm compare APG-C14 3,72 x 10-4 dyne/cm. Oil recovery on capillary pressure test was 10,733% for APG-C12 and 13,79% for APG-C14. Thus, the APG-C14 potentially developed for chemical flooding.

Abstrak :
Natural-based surfactant such as methyl esther sulfonate, which is derived from palm oil, has increasingly become the focus of study for the last decade to improve oil recovery due to the abundant raw materials availability and the need for oil as a source of energy. Surfactant MES development with the targeted fluid reservoir characteristics has been conducted in the laboratory scale as well as in the field scale. In this study, the addition of polyethylene glycol mono-oleate as co-surfactant to enhanced oil recovery in the "L" oillfield in Central Java was investigated in the laboratory scale through compatibility observation, IFT measurement, thermal stability and core flooding tests. The result showed that the presence of PMO improved the solubility of surfactant mixture in the water which formed one phase milky solution. Decreasing IFT as the crucial factor for surfactant flooding was also achieved until 10-3 dyne/cm and thermally stable for two months. Furthermore, core flooding experiments to study the performance of surfactant to recover oil production showed that the mixture of MES and PMO are able to enhance oil recovery until 55.35%S and have potential to be used as chemicals for chemical flooding in the targeted oilfield.