http://tainguyenso.vnu.edu.vn/jspui/handle/123456789/7492 2026-05-17T17:53:37Z 2026-05-17T17:53:37Z Nguyen, Hai An Le, Xuan Lan http://tainguyenso.vnu.edu.vn/jspui/handle/123456789/7720 2011-05-19T05:52:01Z 2010-01-01T00:00:00Z

Combination of Underground CO2 Storage and Increased Oil Recovery in Su Tu Den - SW Fractured Basement Reservoir Nguyen, Hai An; Le, Xuan Lan The Su Tu Den-South West (STD-SW) field is located in the Cuu Long basin. The basement reservoir contained 450 MMstb oil initial in place. The current oil recovery after 7 years of production is about 87 MMstb. The area was produced by water injection with support of bottom aquifer. The producers, located at the crest of the high relief structure are exhibiting a high water cut. Since 2007, some producers with high water cut have been side tract to optimize the oil production of the reservoir that consists of granite. A kaolinezed weathered zone ranging in thickness from 4 to 55m covers the fresh granite. A Black Oil model was used to simulate the flow in the both weathered and granite zones. The main recovery mechanisms for this reservoir are imbibition and water/oil gravity drainage. The study results show that an economical attractive option for the field development is establishing an underground CO2 storage after using EOR-CO2 technique. The CO2 injection lead to CO2/oil gravity drainage of the oil and water present in the micro fractures of reservoir. The oil collected by the horizontal producers, resutling in incremental oil recovery of up to 15% of oil in place. To increase the amount of CO2, that can be used for underground, water (and more oil) have to be withdrawn from the reservoir.

2010-01-01T00:00:00Z Bui, Thi Luan http://tainguyenso.vnu.edu.vn/jspui/handle/123456789/7719 2011-05-19T05:48:44Z 2010-01-01T00:00:00Z

Petroleum Potential of Source Beds in The Cuu Long Basin Bui, Thi Luan In the Cuu Long basin, three source beds are identified: Lower Miocene, Upper Oligocene, Upper Eocene + Lower Oligocene. They are separated from each other by sand-clay layers. Only Upper Oligocene and Upper Eocene + Lower Oligocene source beds are two main source beds supplying a great part of organic matter into traps. Petroleum source potential of Upper Oligocene source bed (66.30 billion tons) is greater than Upper Eocene + Lower Oligocene bed (29.88 billion tons). Total amount of hydrocarbon has ability to take part in accumulation process at the petroleum-bearing traps from Upper Oligocene and Upper Eocene + Lower Oligocene source beds is over 2.19 billion tons and below 1.16 billion tons respectively. Thus, in whole Cuu Long basin, source rocks have capacity to produce 96.18 billion tons of hydrocarbon in which accumulation is 3.35 billion tons making up 3.35% production quantity. Applying Monte - Carlo simulation method, using Crystal Ball software to calculate production potential and total amount of organic matter taking part into migration and accumulation process give rather appropriate result with difference level ≤ 1.25%. Prospecting levels are in the following order: (i) Central lift zone has the greatest prospects, next is Dong Nai lift zone, graben located in north west inclined slope, south east inclined slope, north east area of Tam Dao lift zone finally; (ii) Petroleum does not only accumulate in structural, combination traps but also in non-structural traps.

2010-01-01T00:00:00Z D. H., Hien S. , Jang Y. , Kim http://tainguyenso.vnu.edu.vn/jspui/handle/123456789/7718 2011-05-19T05:45:19Z 2010-01-01T00:00:00Z

Reverse Time Migration for Vertical Transversely Isotropic (VTI) Media D. H., Hien; S. , Jang; Y. , Kim One of main assumption for solving wave equation either numerically or analytically is to compensate the anisotropic properties those are usually observed in the earth materials. Consequently, most conventional prestack depth migration techniques based on wave equation solution, are not sufficient for these anisotropic media. Asymptotic analysis of wave propagation in vertical transversely isotropic (VTI) media yields a dispersion relation of couple P- and SV wave modes that then can be converted to fourth order scalar partial difference (PDE) wave equation. By setting the shear velocity equal 0 and defining the auxilary function, the fourth order PDE acoustic wave equation for VTI media can be reduced to a system of coupled second order PDEs and then can be solved numerically by finite difference method (FDM). The result of this P wavefield simulation is kinematically similar to the one of elastic VTI wavefield simulation. Since the FDM approach can simulate the wavefield propagation in the VTI media, and reverse time migration (RTM) images the reflectors by using time extrapolation to synthesize source and receivers wavefield in the subsurface by FDM, the RTM technique is then promptly suggested to image the subsurface. The proposed algorithm has been shown the accuracy of subsurface imaging by VTI Marmousi synthetic example.

2010-01-01T00:00:00Z Lieu, Kim Phuong T., Drobek W., Altermann R.W. , Stark http://tainguyenso.vnu.edu.vn/jspui/handle/123456789/7717 2011-05-19T05:42:02Z 2010-01-01T00:00:00Z

Pore Surface Topography in Sandstone Reservoirs Lieu, Kim Phuong; T., Drobek; W., Altermann; R.W. , Stark For the development of tertiary oil and gas exploitation methods, it is important to understand the interaction of the various fluid and gas phases with the hydrocarbon reservoir rocks. The wetting properties of the inner surface of the rock have a great impact on multiphase flow and saturation, as well as on productivity and recovery. The morphology of pore surfaces in clastic sedimentary reservoir rocks is formed by the modified mineral grain surfaces, and gradually altered in diagenetic processes as well as during epidiagenesis, due to changing temperature, pressure and chemical and physical conditions of the environment. Thus, very different types of surfaces can occur, ranging from very rough, fractal-like surfaces to flat, smooth crystal facets. In this paper, we analyzed sandstones from a German gas deposit by digital laser scanning microscopy, raman spectroscopy and scanning electron microscopy. The pore surface morphology shows textures of clastic grains, authigenic minerals characteristics and pore throats that have been blocked by cementation, reducing the connection between pore spaces. Authigenic minerals with needle and prism shapes, have grown in pores at the same time with and subsequently to cement accumulation. Due to the high aspect ratio, these crystals have a significant influence on fluid flow in the pore network. Although their influence on the pore volume may be small, they can dramatically decrease the permeability of the pore network, because they reduce the cross-sectional area of the pores, and they can act as pinning sites for an oil-water interface and as crystallization seeds for later, secondary cements.

2010-01-01T00:00:00Z