AbstrakPertumbuhan industri minyak yang cepat, meningkatnya kebutuhan bahan bakar fosil, penemuan cadangan minyak yang menurun dan sulit ditemukan, serta penurunan produksi yang diperoleh dari aset yang sudah tua menyebabkan industri minyak menerapkan metode produksi alternatif. Metode yang paling umum untuk diterapkan adalah teknik enhanced oil recovery (EOR). Salah satu metode EOR yang paling diterapkan saat ini adalah injeksi surfaktan-polimer. Proses injeksi ini sangat tergantung pada karakteristik aliran, heterogenitas batuan dan interaksi antara fluida-batuan. Oleh karena itu, perlu dilakukan studi tertentu untuk memahami mekanisme injeksi. Hal ini dapat dilakukan dengan menggunakan simulator reservoir. Studi ini dilakukan melalui analisis komparatif dari 4 (empat) jenis injeksi yaitu injeksi air, injeksi polimer, injeksi surfaktan, dan injeksi surfaktan-polimer. Dapat dilihat bahwa injeksi air tidak bekerja optimal karena kandungan air telah mencapai nilai tertinggi 98%. Injeksi polimer bisa menyapu minyak yang terkandung dalam zona permeabilitas rendah sekitar 4% dari saturasi minyak sebelumnya. Injeksi surfaktan dapat mengurangi saturasi minyak yang tersisa di reservoir (ROS) sekitar 5% dari saturasi minyak sebelumnya pada zona permeabilitas tinggi. Injeksi surfaktan-polimer bisa menyapu minyak yang terkandung dalam kedua zona permeabilitas tinggi dan rendah hingga mengurangi residual oil saturation after waterflood (SORW) dan ROS masing-masing hingga 7% dan 11% dari saturasi minyak sebelumnya. Dengan demikian, injeksi surfaktan-polimer dianggap sebagai teknik EOR yang paling cocok untuk diterapkan di Lapangan NR.Kata kunci: Enhanced Oil recovery, saturasi minyak sisa, heterogenitas, surfaktan, polimer, reservoir bertingkat. AbstrakThe rapid oil industry growth, the increasing needs of fossil fuel, the decreasing and becoming more difficult oil discovery, and the decreasing production from the getting-old assets cause the industry to apply alternative production methods. The most common method to decide on has been applying enhanced oil recovery (EOR) technique. One of the most applied EOR methods these days is the surfactant-polymer injection. This injection process extremely depends on reservoir flow characteristics i.e. rock heterogeneity and fluid-rock interaction. Therefore, it is necessary to conduct a particular study to understand the mechanism of the injection. This can be done using a reservoir simulator. The study was carried out through a comparative analyses of 4 (four) types of injection namely water injection, polymer injection, surfactant injection, and surfactant-polymer injection. It was found that the water injection was no longer optimal since the water cut has reached a value as high as 98%. The polymer injection could sweep the oil contained in low-permeability zones of about 4% from the previous oil saturation. The surfactant injection could reduce the oil saturation (ROS) of about 5% from the previous oil saturation in high-permeability zones. The surfactant-polymer injection cou...
As time goes by, there will be decreasing of production rates of a field along with decreasing pressure. This led to the necessity for further efforts to increase oil production. Therefore, pressure support is required to improve the recovery factor. Supportable pressure that can be used can be either water flooding and polymer flooding. This study aims to compare recovery factor to scenarios carried out, such as polymer flooding with different concentrations modeled in the same reservoir model to see the most favorable scenario. The method used in this research is reservoir simulation method with Computer Modeling Group (CMG) STARS simulator. The study was carried out by observing at the pressure, injection rate, and polymer concentration on increasing field recovery factor. This study used cartesian grid with the assumption of homogeneous reservoir, there are no faults or other geological condition in the reservoir, and driving mechanism is only solution gas drive. This reservoir, oil type is light oil with API gravity 40.3˚API and layer of conglomerate rock. The simulation result performed with various scenarios provides a good result. Where the conditions case base case field recovery factor of 6.7%, and after water flooding produced 25.5% of oil, whereas with tertiary recovery method is polymer flooding was carried out with four concentrations of 640 ppm, 1,500 ppm, 3,000 ppm, and 4,000 ppm obtained optimum values at 4,000 ppm polymer concentration with recovery factor 28.9%, SOR reduction final value 0,5255, polymer adsorption of 818,700 ppm, reservoir final pressure 1,707 psi, and an increase in water viscosity to 0.94 cP.
AbstrakArea X merupakan bagian dari lapangan Y saat ini mengalami dalam kurun waktu 16 tahun terakhir penurunan laju alir produksi sebesar 64.4%. Diperlukan upaya untuk meningkat laju alir produksi minyak dan recovery factor dari area tersebut, upaya yang akan dilakukan adalah injeksi air atau waterflood dengan mengubah salah satu sumur produksi menjadi sumur injeksi (convert to injection). Penentuan kandidat sumur convert to injection (CTI) berdasarkan kondisi laju alir produksi, jarak antara sumur kandidat dan sumur produksi, serta korelasi antar sumur. Untuk memperoleh hasil yang optimal akan dibuat beberapa skenario yang akan disimulasikan dengan parameter rate injeksi dan penambahan perforasi. Penentuan rate injeksi dilakukan dengan uji sensitivitas terlebih dahulu dan memperhatikan tekanan fracture dari tiap lapisan. Penambahan perforasi dengan melihat korelasi dari data log yang ada sehingga sumur CTI dapat memberikan peningkatan terhadap sumur produksi. Hasil simulasi yang paling optimal dari skenario yang direncanakan diperoleh penambahan produksi sebesar 800 MSTB dan recovery factor sebesar 12.9%.
Deformation band at Petani Formation included in the type of disaggregation band, where deformation on this formation resulted from tectonics stress at Plio – Pleistocene affecting sandstone layer that being deformed and resulted strain localization feature, filling with iron oxide sand. The measurement for this research was using grain size analysis, distribution analysis of shear trends, and measurement of permeability for each deformation band. The result shows that grains size dominantly fine sand – medium sand (0.149 mm – 0.297 mm), followed by the distribution of deformation trends showing NW – SE direction, and also good in permeability (3.4 mD– 188.4mD). It can be concluded that the structural features of deformation band can also create good permeability for fluid flow.
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