Construction of synthetic capillary pressure curves from the joint use of NMR log data and conventional well logs

Eslami, Maede; Kadkhodaie, Ali; Sharghi, Yousef; Golsanami, Naser

doi:10.1016/j.petrol.2013.10.010

Cited by 53 publications

(16 citation statements)

References 7 publications

Supporting

Mentioning

Contrasting

Order By: Relevance

“…Talabi et al (2009) probed the pore characteristics of deformed chalk by NMR relaxation. Eslami et al (2013) were able to construct synthetic capillary pressure curves based on the combined use of NMR log data and conventional well logs. Because ultra-low permeability sandstone reservoir is influenced by cementing and diagenesis, fluid storage in ultra-low permeability sandstone is different from that in normal reservoir due to the complexity of pore throat structures Gao et al, 2008).…”

Section: Introductionmentioning

confidence: 99%

Determination of movable fluid percentage and movable fluid porosity in ultra-low permeability sandstone using nuclear magnetic resonance (NMR) technique

Gao

2015

Journal of Petroleum Science and Engineering

197

100

View full text Add to dashboard Cite

Section: Introductionmentioning

confidence: 99%

Determination of movable fluid percentage and movable fluid porosity in ultra-low permeability sandstone using nuclear magnetic resonance (NMR) technique

Gao

2015

Journal of Petroleum Science and Engineering

197

100

View full text Add to dashboard Cite

“…Meanwhile, variation in T 2 4 obtained from NMR reflects the fluid distribution in pore throats [6][7][8] . Many scholars that there exists a positive correlation between T 2 value and the radius of pore throat many sandstones and some carbonate 9,10 . According to mercury intrusion data, T 2 can be converted into pore throat radius, such that the fluids distribution in different pore throat can be obtained 11,12 .…”

Section: Introductionmentioning

confidence: 99%

“… illustrate the process for obtaining the constant C for Core sample #2 10. log r and the relative cumulative distribution of pore throat radius obtained from mercury injection tests.…”

mentioning

confidence: 99%

Impact of Secondary and Tertiary Floods on Microscopic Residual Oil Distribution in Medium-to-High Permeability Cores with NMR Technique

et al. 2015

View full text Add to dashboard Cite

In order to explore the impact of various flood schemes and pore throat heterogeneity on oil recovery efficiency in porous media, coreflood experiments and nuclear magnetic resonance (NMR) tests are conducted to quantitatively determine the initial oil distribution and the residual oil distribution in medium-to-high permeability cores subjected to these various flood schemes. Multiple experimental runs are conducted with 4 field core samples to cover the various flood schemes: the secondary water flood, CO 2 -foam flood, and water-alternating-CO 2 flood (WAG). Experimental results show that, relatively speaking, at the initial oil saturation condition, the moderate pore throats contain the highest amount of oil. Water flood recovery degree is higher from larger pore throats (average recovery degree of 98.57%) than that from moderate pore throats (average recovery degree of 78.29%). The water flood efficiency in different cores is found to be dependent of the degree of heterogeneity in pore throat distribution. After water flood, the residual oil is mainly located in smaller pore throats. CO 2 -foam flood shows a good performance in tapping the residual oil contained in smaller pore throats, while the WAG can recover more oil from larger pore throats. Furthermore, it is found that the combination of CO 2 -foam flood and WAG provides the highest recovery efficiency since it is effective in reducing the oil saturation in pore throats with varied sizes. Based on this investigation on the residual oil saturation in pore throats subjected to secondary and tertiary floods, it is possible to design an optimum flood scheme which suits the microscope pore throat characteristics for a given reservoir.

show abstract

“…Furthermore, the mercury used is toxic as a heavy metal and its use has been restricted due to its environmental unfriendliness (Mcnutt, 2013). In view of experimental inconvenience, many indirect methods are currently being attempted to establish or calculate the CPC (Al Ibrahim et al, 2012;Bultreys et al, 2016;Eslami et al, 2013;Shikhov & Arns, 2015;Valvatne & Blunt, 2004;Xiao et al, 2016). Nondestructive NMR testing in the last decade has been widely used to construct the CPC for pore structure estimation, but other pore structure parameters need to be combined with the NMR method (Minagawa et al, 2008;Stingaciu et al, 2010;Wang et al, 2018).…”

Section: Introductionmentioning

confidence: 99%

Capillary Pressure Curve Determination Based on a 2‐D Cross‐Section Analysis Via Fractal Geometry: A Bridge Between 2‐D and 3‐D Pore Structure of Porous Media

Chen

Yao

Luo³

et al. 2019

JGR Solid Earth

View full text Add to dashboard Cite

Pore structure is a crucial attribute in characterizing fluid flow through porous media. However, direct experimental measurements or numerical reconstructions are commonly expensive and not environmentally friendly, with great uncertainty caused by the complex nature of porous media. In this study, we demonstrate that one special bridge function, which is a function of the apparent length and tortuosity fractal dimension, can characterize the relationship of pore structures between two dimensions (2‐D) and three dimensions (3‐D), and it can serve as a conversion bridge of the radius to determine the capillary pressure curve (CPC). We compare estimations by the proposed method with experimental results obtained by mercury intrusion porosimetry in six typical natural sandstones with varying porosities and permeabilities. The result shows that cross sections of the global pore structure, such as thin section, electronic probe, and microcomputed tomography slices, give a reliable estimation of the CPC using the bridge function in porous media with a medium porosity. However, in unconventional porous media with a relatively low porosity (~10%) or extra high porosity (~30%), due to the empirical nature of the equation widely used to calculate the tortuosity fractal dimension, the necessary modification is necessary to obtain the CPC when applying the bridge function in such porous media. This insight can significantly simplify the procedure for obtaining the petrophysical properties of a porous medium, which may shed light on the inherent differences and correlations between the 2‐D and 3‐D pore structures of porous media.

show abstract

Construction of synthetic capillary pressure curves from the joint use of NMR log data and conventional well logs

Cited by 53 publications

References 7 publications

Determination of movable fluid percentage and movable fluid porosity in ultra-low permeability sandstone using nuclear magnetic resonance (NMR) technique

Determination of movable fluid percentage and movable fluid porosity in ultra-low permeability sandstone using nuclear magnetic resonance (NMR) technique

Impact of Secondary and Tertiary Floods on Microscopic Residual Oil Distribution in Medium-to-High Permeability Cores with NMR Technique

Capillary Pressure Curve Determination Based on a 2‐D Cross‐Section Analysis Via Fractal Geometry: A Bridge Between 2‐D and 3‐D Pore Structure of Porous Media

Contact Info

Product

Resources

About