scholarly journals Simulation study of fireflooding (Part 3) - On the influence of residual oil saturation, oil density and air injection rate.

1989 ◽  
Vol 54 (5) ◽  
pp. 350-358
Author(s):  
Heiji ENOMOTO ◽  
Cheng-Xie HONG ◽  
Shozo TANAKA ◽  
Tadashi CHIDA
Keyword(s):  
Simulation Study ◽  
Injection Rate ◽  
Air Injection ◽  
Residual Oil ◽  
Oil Saturation ◽  
Residual Oil Saturation ◽  
Oil Density

Microscopic Studies of Immiscible Displacement Behavior in Interconnected Fractures and Cavities

2019 ◽  
Vol 141 (9) ◽  
Author(s):  
Qingbang Meng ◽  
Sai Xu ◽  
Jianchao Cai
Keyword(s):  
Steady State ◽  
Video Camera ◽  
Injection Rate ◽  
Residual Oil ◽  
Water Displacement ◽  
Oil Saturation ◽  
Residual Oil Saturation ◽  
Digital Video Camera ◽  
Water Breakthrough ◽  
Microscopic Studies

Carbonate rocks are generally highly heterogeneous that make it difficult to accurately assess the behavior of fluid flow and transport in them. In this paper, we experimentally investigate the oil–water displacement in carbonate reservoirs by mimicking the typical pore vugs of carbonates through fabricating glass micromodels. The micromodels were saturated completely with oil, and then water was injected continuously at a constant rate until a steady state was achieved. After that, the injection rate was increased in steps. For each injection rate, water was continuously injected until a steady state was achieved and then increased to the next injection rate. For each injection rate, the displacement process of oil and water in the micromodel was captured by a digital video camera. Experimental results show that water breakthrough occurs in pure-fracture channels earlier than that in fracture-cavity channels. The wettability and pore networks of fractures and vugs have a significant impact on the distribution of trapped oil. Oil is preferential to be trapped in the oil-wet zone and the zone where deviation from the mainstream line starts. Residual oil saturation shows no noticeable change with relatively low injection rates. However, when the injection rate exceeds a critical value, residual oil saturation decreases with an increase in the injection rate.

Relationship between Residual Saturations and Wettability using Pore-Network Modeling

2021 ◽  
Author(s):  
Prakash Purswani ◽  
Russell T. Johns ◽  
Zuleima T. Karpyn
Keyword(s):  
Contact Angle ◽  
Oil Recovery ◽  
Network Modeling ◽  
Pore Network ◽  
Residual Oil ◽  
Residual Saturation ◽  
Oil Saturation ◽  
Pore Network Modeling ◽  
Residual Oil Saturation ◽  
Eor Processes

Abstract The relationship between residual saturation and wettability is critical for modeling enhanced oil recovery (EOR) processes. The wetting state of a core is often quantified through Amott indices, which are estimated from the ratio of the saturation fraction that flows spontaneously to the total saturation change that occurs due to spontaneous flow and forced injection. Coreflooding experiments have shown that residual oil saturation trends against wettability indices typically show a minimum around mixed-wet conditions. Amott indices, however, provides an average measure of wettability (contact angle), which are intrinsically dependent on a variety of factors such as the initial oil saturation, aging conditions, etc. Thus, the use of Amott indices could potentially cloud the observed trends of residual saturation with wettability. Using pore network modeling (PNM), we show that residual oil saturation varies monotonically with the contact angle, which is a direct measure of wettability. That is, for fixed initial oil saturation, the residual oil saturation decreases monotonically as the reservoir becomes more water-wet (decreasing contact angle). Further, calculation of Amott indices for the PNM data sets show that a plot of the residual oil saturation versus Amott indices also shows this monotonic trend, but only if the initial oil saturation is kept fixed. Thus, for the cases presented here, we show that there is no minimum residual saturation at mixed-wet conditions as wettability changes. This can have important implications for low salinity waterflooding or other EOR processes where wettability is altered.

scholarly journals SURFACTANT-POLYMER FLOODING PERFORMANCE IN HETEROGENEOUS TWO-LAYERED POROUS MEDIA

2011 ◽  
Vol 12 (1) ◽  
pp. 31-38 ◽  
Author(s):  
Muhammad Taufiq Fathaddin ◽  
Asri Nugrahanti ◽  
Putri Nurizatulshira Buang ◽  
Khaled Abdalla Elraies
Keyword(s):  
Porous Media ◽  
Oil Recovery ◽  
Polymer Flooding ◽  
Water Flooding ◽  
Residual Oil ◽  
Oil Saturation ◽  
Reservoir Heterogeneity ◽  
Residual Oil Saturation ◽  
Layered Porous Media ◽  
Multiple Porosity

In this paper, simulation study was conducted to investigate the effect of spatial heterogeneity of multiple porosity fields on oil recovery, residual oil and microemulsion saturation. The generated porosity fields were applied into UTCHEM for simulating surfactant-polymer flooding in heterogeneous two-layered porous media. From the analysis, surfactant-polymer flooding was more sensitive than water flooding to the spatial distribution of multiple porosity fields. Residual oil saturation in upper and lower layers after water and polymer flooding was about the same with the reservoir heterogeneity. On the other hand, residual oil saturation in the two layers after surfactant-polymer flooding became more unequal as surfactant concentration increased. Surfactant-polymer flooding had higher oil recovery than water and polymer flooding within the range studied. The variation of oil recovery due to the reservoir heterogeneity was under 9.2%.

Validation of Gravity-dominated Relative Permeability and Residual Oil Saturation in a Giant Oil Reservoir

1998 ◽  
Author(s):  
J.T. Edwards ◽  
M.M. Honarpour ◽  
R.D. Hazlett ◽  
M. Cohen ◽  
A. Membere ◽  
...  
Keyword(s):  
Relative Permeability ◽  
Oil Reservoir ◽  
Residual Oil ◽  
Oil Saturation ◽  
Residual Oil Saturation
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