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![T2sec –T1/T2 Method [modified after 32].](profile/Ilham-El-Monier/publication/295085244/figure/fig7/AS:330890136834057@1455901764762/T2sec-T1-T2-Method-modified-after-32.png)
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![Fig. 4. Mineralogy of the gas shale plays in the United States [25].](profile/Ilham-El-Monier/publication/295085244/figure/fig11/AS:669640992772104@1536666262281/Mineralogy-of-the-gas-shale-plays-in-the-United-States-25_Q320.jpg)
![Fig. 5. T 1-T 2 diagnostic map [Modified after 6].](profile/Ilham-El-Monier/publication/295085244/figure/fig12/AS:669640992751620@1536666262306/T-1-T-2-diagnostic-map-Modified-after-6_Q320.jpg)
![Fig. 6. T 2sec eT 1 /T 2 method [modified after 7].](profile/Ilham-El-Monier/publication/295085244/figure/fig13/AS:669640992780293@1536666262330/T-2sec-eT-1-T-2-method-modified-after-7_Q320.jpg)
The development of shale reservoirs has brought a paradigm shift in the worldwide energy equation. This entails developing robust techniques to properly evaluate and unlock the potential of those reservoirs. The application of Nuclear Magnetic Resonance techniques in fluid typing and properties estimation is well-developed in conventional reservoir...
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![Fig. 4. Mineralogy of the gas shale plays in the United States [25].](profile/Petroleum-Swpu/publication/304750412/figure/fig2/AS:379950780698625@1467598733925/Mineralogy-of-the-gas-shale-plays-in-the-United-States-25_Q320.jpg)
![Fig. 6. D-T 2 method in conventional and unconventional reservoirs [5].](profile/Petroleum-Swpu/publication/304750412/figure/fig5/AS:379950784892929@1467598734144/D-T-2-method-in-conventional-and-unconventional-reservoirs-5_Q320.jpg)
![Fig. 7. T 2sec eT 1 /T 2 method [modified after 7].](profile/Petroleum-Swpu/publication/304750412/figure/fig3/AS:379950780698626@1467598733976/T-2sec-eT-1-T-2-method-modified-after-7_Q320.jpg)
The development of shale reservoirs has brought a paradigm shift in the worldwide energy equation. This entails developing robust techniques to properly evaluate and unlock the potential of those reservoirs. The application of Nuclear Magnetic Resonance techniques in fluid typing and properties estimation is well-developed in conventional reservoir...
Citations
... Besides, clay minerals have a tendency to block accessible pores when water-based fluids are injected [46]. On the other hand, minerals containing paramagnetic ions, such as iron and manganese, can shift nuclear magnetic resonance (NMR) signals from their original positions [47]. These potential hazards highlight the importance of understanding the mineral compositions of core samples before conducting experiments. ...
... The T 1 -T 2 Spectrum is a two-dimensional NMR technique that has gained widespread use due to the limitations of T 2 spectrum in differentiating various hydrogen-bearing components [47]. The Bloembergen-Purcell-Pound (BPP) theory describes the longitudinal and transverse relaxation times, T 1 and T 2 , respectively, as expressed in equations [119]: ...
... The velocity-porosity relationship of rocks is a crucial factor in understanding their porosity origin, which can be primary or secondary, depending on the deposition process, fracturing, or maturityinduced porosity Mehana and El-monier, 2016;Reed, 2017). The heterogeneity of pore distribution leads to a scattered velocityporosity evolution path, making it challenging to predict the elastic behavior of rocks accurately . ...
The middle Bakken (MB) is a major unconventional oil producing formation in the U.S. with an enormous contribution of upper (UB) and lower (LB) Bakken members, source rocks. The three Bakken members form a crucial petroleum system in the
Williston, where UB and LB, the target of this study, have similar lithologies, composed of siliceous, pyritic black shale, and middle Bakken (MB) which is a calcareous siltstone and fine-grained sandstone. Shales are characterized by their anisotropic nature due to layering. Therefore, isotropic modeling can lead to errors in stiffness estimations. The main objective of this study was to develop anisotropic rock physics modeling of the Bakken formation to assess the elastic behavior and determine the key parameters controlling the velocity dispersion with respect to layering. Maturity effect was also investigated by including kerogen content into the system via solid substitution modeling. Laboratory data was scattered against the
lab-scale rock physics templates to capture the dominant pores morphology with respect to beddings in the Bakken shale. Furthermore, this study captured the implications of different pore structures on controlling the degree of anisotropy in the medium. The results showed that UB and LB shales exhibit large anisotropy due to high presence of clay minerals, and fractures.
... 50,51 A SPEC-RC035 NMR analyzer was used for performing 2D NMR analysis. 52,53 The equipment was operated at a frequency of 15 MHz, magnetic field strength of 0.35 T, and room temperature of 25°C. 54,55 The 2D NMR of the as-received sample, the washed oil, and the saturated oil sample was tested. ...
The oil mobility in unconventional tight/shale oil reservoirs is complex because of high heterogeneity in matrix pore structure and connectivity. Thus, it is difficult to evaluate hydrocarbon exploration potential precisely. In this study, multistep temperature pyrolysis (MTP) Rock-Eval as well as 1D (dimensional) and 2D nuclear magnetic resonance (NMR) techniques were employed to systematically characterize the oil mobility in lacustrine fine-grained sedimentary rocks from the Lucaogou Formation in the Jimusar Sag, Junggar Basin, NW China. The results show that, the Lucaogou Formation fine-grained sedimentary rocks can be subdivided into six types of lithofacies. With increase of organic matter richness, the content of adsorbed oil increase, while the content of movable oil increase first and tend to be stabilized (when total organic carbon (TOC) > 4%). This is because when TOC is low, the fine-grained sedimentary rocks need to self-adsorb before oil production; when TOC increase further, the generated oil will break through the absorption limit, and charges into the adjacent reservoirs, therefore the movable oil ceases to increase. Permeability is found to have a greater impact on movable fluid saturation than that of porosity. Meanwhile, good throat radius and pore connectivity are conducive to oil flow. As movable oil is more sensitive to throats rather than pores. Furthermore, higher content of brittle minerals is not necessarily favorable for oil flow; alternatively, more clay minerals are easy to from cements causing pores blockage, which will essentially hinder oil mobility. Overall, the organic matter content, reservoir pore structure, and rock mineral composition are the main factors affecting tight/shale oil mobility. Based on the above research, a conceptual model of oil mobility in different lithofacies reservoirs is established. These results have a reference significance for evaluating oil recoverability in fine-grained sedimentary rocks.
... Moreover, organic-rich shales are even more complicated as the effect of organic matter should be taken into consideration during the rock physics workflow, which requires the determination of total organic carbon (TOC) and kerogen volume (Passey et al., 1990), clay lenticular texture that is different from the rounded grain shape (Carcione et al., 2011), in addition to the maturity-induced porosity development (Alfred and Vernik, 2012). These characteristics require further consideration during modeling (Vernik and Milovac, 2011;Mehana and El-monier, 2016). ...
... Nuclear magnetic resonance (NMR) technology, as a nondestructive testing technique, has been widely used in the field of unconventional oil and gas in recent years, such as the fluid distribution characteristics (Mehana and El-Monier, 2016;Lawal et al., 2020;Liu et al., 2020), pore structure (Zhao et al., 2011;Li et al., 2018;Zhang J. et al., 2019;Zhang Q. et al., 2019;Liu et al., 2020;Ma et al., 2020;Wang et al., 2020), seepage characteristics (Sun et al., 2018a;Liu et al., 2020;Wang et al., 2020) and wettability (Sun et al., 2018b;Liu et al., 2020;Mao et al., 2020), etc. NMR technology has unique advantages in characterizing the micro-structural pore features and fluid mobility of reservoirs. Peng et al. (2018) classified the pores of clastic tuffs into micro-pore, small pore, medium pore, and large pore based on the boundary of 30 ms, 90 ms, and 200 ms. ...
The fluid mobility characteristics in the pores with various apertures for tight-sandstone would finally determine the fluid mobility and production of tight oil and gas reservoirs. In this study, the tight-sandstone core samples collected from Middle Jurassic Xishanyao Formation in Santanghu Basin were launched the fluid mobility measurements under various centrifugal speeds. With the NMR fractal theory pore classification method, the various types of pores in the tight-sandstone core samples were classified, and the fluid mobility in different types of pores were also investigated. The results show that the tights-sandstone core samples were significantly influenced by compaction, and the core samples are relatively dense, the mineral intergranular solution pores and colloidal intergranular pores are the main storage spaces. With a constant increase of the centrifugal speed, the fluid mobility increases continuously, and the fluid mobility for CTOS-19 features stronger than that of CTOS-7, which is related to the complexity of pore structure in tight-sandstone sample. Compared with the pore aperture in CTOS-19, the pore aperture in CTOS-7 is smaller, and the connectivity between the smaller and larger pores is poorer, leading to the poorer fluid mobility. Besides, the NMR fractal theory pore classification method also shows that the COTS-7 features more pore types than COTS-19, five and four types respectively. The type P2 and P3 pores are dominant in COTS-7 and CTOS-19 core samples, and the connectivity between type P2 and P3 pores contributes dominantly to the fluid mobility. With the NMR fractal theory pore classification method, the complexity of the distribution of fluid and fluid mobility in tight reservoirs could be studied quantitatively, and the results can efficiently guide the development of residual oil and gas in tight oil reservoirs.
... Shale rocks have been extensively studied for their T 1 -T 2 relaxation correlation response [18][19][20][27][28][29]. Overlap of shale signal species have been reported on the T 1 -T 2 relaxation correlation plot. ...
Kerogen assessment is essential to evaluation of shale reservoir quality. Routine analysis techniques are sample destructive and time-consuming. ¹H magnetic resonance (MR) methods offer a fast, robust, and non-destructive alternative. However, kerogen MR signal detection and quantification is challenging due to its short signal lifetime and requires new MR methods. In this work, the T1-T2* relaxation correlation method was investigated for assessment of kerogen in shales. Step pyrolysis experiments were conducted coupled with MR T1-T2* relaxation correlation measurements and thermogravimetric analysis (TGA). The results show that the short relaxation lifetime signal observed in the shale samples was dominated by the kerogen species. The shale signal was resolved in the T1-T2* relaxation correlation measurement that was calibrated to report kerogen, oil, and water ¹H content of the shale samples. Kerogen ¹H content was then used to evaluate the hydrocarbon generation potential of kerogen. An elemental balance analysis was conducted to estimate the kerogen chemical evolution in the Van Krevelen diagram. The results proved that a simple FID measurement was adequate to resolve and quantify the kerogen signal component in shales.
... Model Oriented Evaluation (MOE): Assess the total porosity of NMR, assign fluid components and their attributes to each fluid point on the map, create regions with fluid spots automatically using contour lines and the total Sw is computed by combining the Sw from each separate component. As illustrated below: Generic fluid distribution and typing in unconventional reservoir(Mehana and El-Monier, 2016) ...
Water saturation is the most significant characteristic for reservoir characterization in order to assess oil reserves; this paper reviewed the concepts and applications of both classic and new approaches to determine water saturation. so, this work guides the reader to realize and distinguish between various strategies to obtain an appropriate water saturation value from electrical logging in both resistivity and dielectric has been studied, and the most well-known models in clean and shaly formation have been demonstrated. The Nuclear Magnetic Resonance in conventional and nonconventional reservoirs has been reviewed and understood as the major feature of this approach to estimate Water Saturation based on T2 distribution. Artificial intelligence has recently been used to predict water saturation and other parameters in the reservoir characterization process using seismic data, so the main idea of this technique and a list of the author's researchers have been reviewed. In this review article, the reference approach using core analysis by distillation-extraction and retorting techniques have been explained, as well as the saturation-height method, which is based on the capillary pressure concept and wettability. Finally, alternative experimental approaches based on scanning are expressed in this manner.
... Generic fluid distribution and typing in unconventional reservoir(Mehana and El-monier, 2016) Model oriented evaluation of T1T2 map. Comp1 and Comp2 are interpreted as water spot(Rojas et al., 2018) 13 ...
... It is well known that the pore size distribution controls the transport behavior of fluids through pores [11]. The pore fluids are usually classified into two, namely, movable and bound fluids, and bound fluids are further classified as capillarybound and clay-bound fluids [12,13]. In a generally accepted definition of sandstones or carbonate rocks, the clay-bound porosity is not part of the effective porosity and is the difference between the total porosity and effective porosity [14]. ...
The Triassic Zhangjiatan shale in the Ordos basin, recognized as one of most promising shale oil and gas resources in China, is one example of medium-low-maturity lacustrine shale reservoirs wherein the pore network has been proven to be different from those of both conventional and high-maturity marine shale reservoirs. Here, we examine the quantitative characterization of pore size and movable fluid distribution of the Zhangjiatan shale reservoir. Eight shale core plugs were measured in a series of nuclear magnetic resonance (NMR) experiments to determine the pore structure and pore fluid transport during the processes of centrifuging and heating. The complete pore size distribution was obtained from the T 2 spectrum by integrating NMR, high-pressure mercury intrusion, and nitrogen gas adsorption. The results show that the movable fluid saturation of Zhangjiatan shale is 19.47–33.02% and the capillary-bound fluid saturation is 14.53–27.62%, whereas the unrecoverable fluid saturation was 43.51–65.26%. The movable fluids are mainly detected in macropores and mesopores with a minimum pore size of 50.5–121.2 nm, while capillary-bound fluids are mainly found in small pores and some mesopores with a minimum size of 25.8–67.5 nm. Almost all unrecoverable fluids are in micropores and small pores. In contrast to high-maturity shale reservoirs, the Zhangjiatan shale shows a poor correlation between total organic carbon content and unrecoverable fluid saturation but a good correlation between clay minerals and unrecoverable fluid saturation, showing that most micropores are associated with clay minerals and the organic matter pores are less developed. This study provides an accurate determination of the pore size distribution and pore fluid typing of Zhangjiatan shale, which is of great significance for the development of high-quality but medium-low-maturity shale reservoirs in China.
... In the reservoir, the shale is a heterogeneous sedimentary rock containing variable content of clay minerals (illite, kaolinite, chlorite and montmorillonite) and organic matter (Brock J, 1986;Mehana M and El-monier I, 2016). It was found that the shale present in the reservoir formation has severe effects on reservoir petrophysical properties and thereby reduces the effectiveness and total porosity and permeability of the reservoir (Kamel MH and Mohamed MM, 2006;Ruhovets N and Fertl WH, 1982). ...
This study focused on the quantitative analysis of the petrophysical parameters in characterizing the reservoir properties of the Srikail gas field using multi-scale wireline logs. Petrophysical parameters (shale volume, porosity, water saturation and hydrocarbon saturation) were estimated from the combination of gamma ray log, resistivity log, density log and neutron log for three hydrocarbon (gas)-bearing zones at well#3. At the first time, log records at 0.1 m and 0.2 m intervals were read for this study. Result showed the average shale volume is 21.07%, 53.67% and 51.71% for zone-1, zone-2 and zone-3, respectively. For these zones, the estimated average porosity was 35.89%, 29.83% and 28.76%, respectively. The average water saturation of 31.54%, 16.83% and 23.39% and average hydrocarbon saturation of 68.46%, 83.17% and 76.61% were calculated for zone-1, zone-2 and zone-3, respectively. Thus zone-2 is regarded the most productive zone of well#3. It was found that the values of some parameters (porosity, hydrocarbon saturation and permeability) are higher than the existing results. Therefore, this study confirmed that the log reading at minute/close interval provides better quantitive values of the reservoir’s petrophysical properties. It is expected that this result will contribute to the national gas field development program in future.©2022 China Geology Editorial Office.
