Transport of Polymers in Low Permeability Carbonate Rocks

2021 ◽  
Author(s):  
Haofeng Song ◽  
Pinaki Ghosh ◽  
Kishore Mohanty
Keyword(s):  
Polymer Concentration ◽  
Material Balance ◽  
Economic Feasibility ◽  
Resistance Factor ◽  
Residual Oil ◽  
Residual Resistance ◽  
Oil Saturation ◽  
Residual Oil Saturation ◽  
Polymer Transport ◽  
Residual Resistance Factor

Abstract Polymer transport and retention affect oil recovery and economic feasibility of EOR processes. Most studies on polymer transport have focused on sandstones with permeabilities (k) higher than 200 mD. A limited number of studies were conducted in carbonates with k less than 100 mD and very few in the presence of residual oil. In this work, transport of four polymers with different molecular weights (MW) and functional groups are studied in Edwards Yellow outcrop cores (k<50 mD) with and without residual oil saturation (Sor). The retention of polymers was estimated by both the material balance method and the double-bank method. The polymer concentration was measured by both the total organic carbon (TOC) analyzer and the capillary tube rheology. Partially hydrolyzed acrylamide (HPAM) polymers exhibited high retention (> 150 μg/g), inaccessible pore volume (IPV) greater than 7%, and high residual resistance factor (>9). A sulfonated polyacrylamide (AN132), showed low retentions (< 20 μg/g) and low IPV. The residual resistance factor (RRF) of AN132 in the water-saturated rock was less than 2, indicating little blocking of pore throats in these tight rocks. The retention and RRF of the AN132 polymer increased in the presence of residual oil saturation due to partial blocking of the smaller pore throats available for polymer propagation in an oil-wet core.

scholarly journals Modeling of Chemical Water Shut off Treatments

2019 ◽  
Vol 2 (1) ◽  
Keyword(s):  
Polymer Concentration ◽  
High Water ◽  
Resistance Factor ◽  
Real Field ◽  
Water Production ◽  
Polymer Gel ◽  
Core Flooding ◽  
Great Chance ◽  
Residual Resistance ◽  
Residual Resistance Factor

Water production is one of the major problems that been encountered in the oil industry, which may cause corrosion of tubular, fine migration and acceleration of well abandonment. More than $40 billion is spent yearly dealing with unwanted water, so a treatment should be implemented to reduce high water production. Many papers investigated and focused their researches on how to reduce water cut percentage. Mechanical and chemical treatments are suggested, chemical treatment represented in polymer-gel with cross linker solution proved optimistic results. Gel can solve many types of water production problems rather than other chemical or other mechanical treatments. In this paper a model was constructed to determine the applicability of gels in reducing water permeability. The model included equations predicted using statistical software (SPSS) that determines the water residual resistance factor (Frrw) and the oil residual resistance factor (Frro) by inserting polymer concentration then determine the optimum concentration which gives the most desired results. A real field data was obtained from Z field (well X, well Y, and Well Z) and gel applicability in permeability reduction had been tested, then an optimistic result obtained. The outcomes of this study investigate that there is a great chance to apply polymer-gel as water shut-off technique. For future work a full core-flooding study must be constructed to obtain more set of data and improvement of the equations accuracy

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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