Relevant bibliographies by topics / Water saturation

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Academic literature on the topic 'Water saturation'

Author: Grafiati
Published: 4 June 2021
Last updated: 3 February 2022

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Journal articles on the topic "Water saturation"

1

Knight, Rosemary, Jack Dvorkin, and Amos Nur. "Acoustic signatures of partial saturation." GEOPHYSICS 63, no. 1 (January 1998): 132–38. http://dx.doi.org/10.1190/1.1444305.

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The relationship between elastic wave velocities and water saturation in a water/gas reservoir depends strongly on whether saturation is heterogeneous (patchy) or homogeneous. Heterogeneity in saturation may result from lithologic heterogeneity because under conditions of capillary equilibrium, different lithologies within a reservoir can have different saturations, depending on their porosities and permeabilities. We investigate this phenomenon by generating models of a reservoir in which we control the distribution of lithologic units and theoretically determine the corresponding velocity‐saturation relationship. We assume a state of capillary equilibrium in the reservoir and determine the saturation level of each region within the reservoir from the corresponding capillary pressure curve for the lithologic unit at that location. The velocities we calculate for these models show that saturation heterogeneity, caused by lithologic variation, can lead to a distinct dependence of velocity on saturation. In a water‐gas saturated reservoir, a patchy distribution of the different lithologic units is found to cause P-wave velocity to exhibit a noticeable and almost continuous velocity variation across the entire saturation range. This is in distinct contrast to the response of a homogeneous reservoir where there is only a large change in velocity at water saturations close to 100%.
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Graue, Arne, Martin A. Fernø, Robert W. Moe, Bernard A. Baldwin, and Riley Needham. "Water Mixing During Waterflood Oil Recovery: The Effect of Initial Water Saturation." SPE Journal 17, no. 01 (November 30, 2011): 43–52. http://dx.doi.org/10.2118/149577-pa.

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Summary This work studies the mixing of injected water and in-situ water during waterfloods and demonstrates that the mixing process is sensitive to the initial water saturation. The results illustrate differences between a waterflooded zone and a preflooded zone during, for example, water-based EOR displacement processes. The mixing of in-situ, or connate, water and injected water during laboratory waterfloods in a strongly water-wet chalk core sample was determined at different initial water saturations. Dynamic 1D fluid-saturation profiles were determined with nuclear-tracer imaging (NTI) during waterfloods, distinguishing between the oil phase, connate water, and injected water. The mixing of connate and injected water during waterfloods, with the presence of an oil phase, resulted in a displacement of all connate water from the core plug. During displacement, connate water banked in front of the injecting water, separating (or partially separating) the injected water from the mobile oil phase. This may impact the ability of chemicals dissolved in the injected water to contact the oil during secondary recovery and EOR processes. The effect of the connate-water-bank separation was sensitive to the initial water saturation (Swi). The time difference between breakthrough of connate water and breakthrough of injected water at the outlet showed a linear correlation to the initial water saturation Swi. The results obtained in chalk confirmed earlier findings in sandpacks (Brown 1957) and thus demonstrated the generality in the results.
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Lekia, S. D. L., and R. D. Evans. "A Water-Gas Relative Permeability Relationship for Tight Gas Sand Reservoirs." Journal of Energy Resources Technology 112, no. 4 (December 1, 1990): 239–45. http://dx.doi.org/10.1115/1.2905766.

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This paper presents a new approach for the analyses of laboratory-derived capillary pressure data for tight gas sands. The method uses the fact that a log-log plot of capillary pressure against water saturation is a straight line to derive new expressions for both wetting and nonwetting phase relative permeabilities. The new relative permeability equations are explicit functions of water saturation and the slope of the log-log straight line of capillary pressure plotted against water saturation. Relative permeabilities determined with the new expressions have been successfully used in simulation studies of naturally fractured tight gas sands where those determined with Corey-type expressions which are functions of reduced water saturation have failed. A dependence trend is observed between capillary pressure and gas permeability data from some of the tight gas sands of the North American Continent. The trend suggests that the lower the gas permeability, the higher the capillary pressure values at the same wetting phase saturation—especially for saturations less than 60 percent.
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Li, Kewen, Kevin Chow, and Roland N. Horne. "Influence of Initial Water Saturation on Recovery by Spontaneous Imbibition in Gas/Water/Rock Systems and the Calculation of Relative Permeability." SPE Reservoir Evaluation & Engineering 9, no. 04 (August 1, 2006): 295–301. http://dx.doi.org/10.2118/99329-pa.

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Summary It has been a challenge to understand why recovery by spontaneous imbibition could both increase and decrease with initial water saturation. To this end, mathematical models were developed with porosity, permeability, viscosity, relative permeability, capillary pressure, and initial water saturation included. These equations foresee that recovery and imbibition rate can increase, remain unchanged, or decrease with an increase in initial water saturation, depending on rock properties, the quantity of residual gas saturation, the range of initial water saturation, and the units used in the definitions of gas recovery and imbibition rate. The theoretical predictions were verified experimentally by conducting spontaneous water imbibition at five different initial water saturations, ranging from 0 to approximately 50%. The effects of initial water saturation on residual saturation, relative permeability, capillary pressure, imbibition rate, and recovery in gas/water/rock systems by cocurrent spontaneous imbibition were investigated both theoretically and experimentally. Water-phase relative permeabilities and capillary pressures were calculated with the experimental data of spontaneous imbibition. Experimental results in different rocks were compared. Introduction Spontaneous water imbibition is an important mechanism during water injection. Prediction of recovery and imbibition rate by spontaneous water imbibition is essential to evaluate the feasibility and the performance of water injection. For example, is water injection effective in the case of high initial water saturation in reservoirs? Answers to such a question may be found by investigating the effect of initial water saturation on spontaneous water imbibition. It has been observed experimentally that initial water saturation affects recovery and production rate significantly (Blair 1964; Zhou et al. 2000; Viksund et al. 1998; Cil et al. 1998; Tong et al. 2001; Li and Firoozabadi 2000; Akin et al. 2000). However, the experimental observations from different authors (Zhou et al. 2000; Cil et al. 1998; Li and Firoozabadi 2000; Akin et al. 2000) are not consistent. On the other hand, few studies have investigated the effect of initial water saturation on recovery and imbibition rate theoretically, especially in gas reservoirs. Using numerical-simulation techniques, Blair (1964) found that the quantity and the rate of oil produced after a given period of imbibition increased with a decrease in initial water saturation for countercurrent spontaneous imbibition. Zhou et al. (2000) found that both imbibition rate and final oil recovery in terms of oil originally in place (OOIP) increased with an increase in initial water saturation, whereas oil recovery by waterflooding decreased. Viksund et al. (1998) found that the final oil recovery (OOIP) by spontaneous water imbibition in Berea sandstone showed little variation with a change in initial water saturation from 0 to approximately 30%. For the chalk samples tested by Viksund et al. (1998), the imbibition rate first increased with an increase in initial water saturation and then decreased slightly as initial water saturation increased above 34%.Cil et al. (1998) reported that the oil recovery (in terms of recoverable oil reserves) for zero and 20% initial water saturation showed insignificant differences in behavior. However, the oil recovery for initial water saturation above 20% increased with an increase in initial water saturation. Li and Firoozabadi (2000) found that the final gas recovery in the units of gas originally in place (GOIP) by spontaneous imbibition decreased with an increase in initial water saturation in both gas/oil/rock and gas/water/rock systems. The imbibition rate (GOIP/min) increased with an increase in initial water saturation at early time but decreased at later time. Akin et al. (2000) found that the residual oil saturation was unaffected significantly by initial water saturation. In this study, equations, derived theoretically, were used to study the effect of initial water saturation on gas recovery and imbibition rate. The equations correlate recovery, imbibition rate, initial water saturation, rock/fluid properties, and other parameters. Experiments of spontaneous water imbibition in gas-saturated rocks were conducted to confirm the theoretical predictions. The effect of rock properties on gas recovery and imbibition rate was also studied. An X-ray CT scanner was used to monitor the distribution of the initial water saturation to confirm that the initial distribution of the water saturation was uniform. In this study, we only focused on cocurrent spontaneous imbibition. It was assumed that there were no chemical reactions or mass transfer between gas and liquid.
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Johnson, Raymond H., and Eileen P. Poeter. "Iterative use of the Bruggeman-Hanai-Sen mixing model to determine water saturations in sand." GEOPHYSICS 70, no. 5 (September 2005): K33—K38. http://dx.doi.org/10.1190/1.2049348.

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The accuracy of the Bruggeman-Hanai-Sen (BHS) mixing model has been previously demonstrated for two-material mixtures during BHS model development. Using permittivities determined from modeling ground-penetrating radar (GPR) data, the BHS model has been iteratively applied to three-material mixtures of water, sand, and a dense, nonaqueous-phase liquid (DNAPL). However, the accuracy of this application has not been verified. A 10-cm air-line system driven by a network analyzer is used to measure bulk permittivitities when the water saturations in a sand are varied (frequency range of 20 to 200 MHz). Through iterative use of the BHS mixing model, the measured permittivities are used to calculate water saturations, which are compared to known saturation values. An iterative BHS mixing model for an air/water/sand system must consider which two-material end member (air/sand or water/sand) represents the matrix term in the original two-material BHS model. An air/sand matrix provides the best accuracy for low water saturations, and a water/sand matrix provides the best accuracy for high water saturations; thus, a new weighted model is developed. For a given porosity and a measured bulk permittivity, water saturation is most accurately determined by proportionally weighting the water saturation values determined using air/sand as the matrix and water/sand as the matrix in the BHS model.
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Tao, Wei-Kuo, Joanne Simpson, and Michael McCumber. "An Ice-Water Saturation Adjustment." Monthly Weather Review 117, no. 1 (January 1989): 231–35. http://dx.doi.org/10.1175/1520-0493(1989)117<0231:aiwsa>2.0.co;2.

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Alharthi, A., and J. Lange. "Soil water saturation: Dielectric determination." Water Resources Research 23, no. 4 (April 1987): 591–95. http://dx.doi.org/10.1029/wr023i004p00591.

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Meng, Mianmo, Yinghao Shen, Hongkui Ge, Xiaosong Xu, and Yang Wu. "The Effect of Fracturing Fluid Saturation on Natural Gas Flow Behavior in Tight Reservoirs." Energies 13, no. 20 (October 12, 2020): 5278. http://dx.doi.org/10.3390/en13205278.

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Hydraulic fracturing becomes an essential method to develop tight gas. Under high injection pressure, fracturing fluid entering into the formation will reduce the flow channel. To investigate the influence of water saturation on gas flow behavior, this study conducted the gas relative permeability with water saturation and the flow rate with the pressure gradient at different water saturations. As the two dominant tight gas-bearing intervals, the Upper Paleozoic Taiyuan and Shihezi Formations deposited in Ordos Basin were selected because they are the target layers for holding vast tight gas. Median pore radius in the Taiyuan Formation is higher than the one in the Shihezi Formation, while the most probable seepage pore radius in the Taiyuan Formation is lower than the one in the Shihezi Formation. The average irreducible water saturation is 54.4% in the Taiyuan Formation and 61.6% in the Shihezi Formation, which indicates that the Taiyuan Formation has more movable water. The average critical gas saturation is 80.4% and 69.9% in these two formations, respectively, which indicates that the Shihezi Formation has more movable gas. Both critical gas saturation and irreducible water saturation have a negative relationship with porosity as well as permeability. At the same water saturation, the threshold gradient pressure of the Taiyuan Formation is higher than the one in the Shihezi Formation, which means that water saturation has a great influence on the Taiyuan Formation. Overall, compared with the Shihezi Formation, the Taiyuan Formation has a higher median pore size and movable water saturation, but water saturation has more influence on its gas flow capacity. Our research is conducive to understanding the effect of fracturing fluid filtration on the production of natural gas from tight reservoirs.
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Carpenter, Chris. "Reconciling Log-Derived Water-Saturation and Saturation-Height Function Results." Journal of Petroleum Technology 68, no. 08 (August 1, 2016): 65–66. http://dx.doi.org/10.2118/0816-0065-jpt.

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Namdar Zanganeh, M., S. I. I. Kam, T. C. C. LaForce, and W. R. R. Rossen. "The Method of Characteristics Applied to Oil Displacement by Foam." SPE Journal 16, no. 01 (August 19, 2010): 8–23. http://dx.doi.org/10.2118/121580-pa.

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Summary Solutions obtained by the method of characteristics (MOC) provide key insights into complex foam enhanced-oil-recovery (EOR) displacements and the simulators that represent them. Most applications of the MOC to foam have excluded oil. We extend the MOC to foam flow with oil, where foam is weakened or destroyed by oil saturations above a critical oil saturation and/or weakened or destroyed at low water saturations, as seen in experiments and represented in foam simulators. Simulators account for the effects of oil and capillary pressure on foam using algorithms that bring foam strength to zero as a function of oil or water saturation, respectively. Different simulators use different algorithms to accomplish this. We examine SAG (surfactant-alternating-gas) and continuous foam-flood (coinjection of gas and surfactant solution) processes in one dimension, using both the MOC and numerical simulation. We find that the way simulators express the negative effect of oil or water saturation on foam can have a large effect on the calculated nature of the displacement. For instance, for gas injection in a SAG process, if foam collapses at the injection point because of infinite capillary pressure, foam has almost no effect on the displacement in the cases examined here. On the other hand, if foam maintains finite strength at the injection point in the gas-injection cycle of a SAG process, displacement leads to implied success in several cases. However, successful mobility control is always possible with continuous foam flood if the initial oil saturation in the reservoir is below the critical oil saturation above which foam collapses. The resulting displacements can be complex. One may observe, for instance, foam propagation predicted at residual water saturation, with zero flow of water. In other cases, the displacement jumps in a shock past the entire range of conditions in which foam forms. We examine the sensitivity of the displacement to initial oil and water saturations in the reservoir, the foam quality, the functional forms used to express foam sensitivity to oil and water saturations, and linear and nonlinear relative permeability models.
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Dissertations / Theses on the topic "Water saturation"

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Steyn, G. F., and C. Vermeulen. "Saturation conditions in elongated single-cavity boiling water targets." Helmholtz-Zentrum Dresden - Rossendorf, 2015. http://nbn-resolving.de/urn:nbn:de:bsz:d120-qucosa-165869.

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Introduction It is shown that a very simple model reproduces the pressure versus beam current characteristics of elongated single-cavity boiling water targets for 18F production surprisingly well. By fitting the model calculations to measured data, values for a single free parameter, namely an overall heat-transfer coefficient, have been extracted for several IBA Nirta H218O targets. IBA recently released details on their new Nirta targets that have a conical shape, which constitutes an improvement over the original Nirta targets that have a cylindrical shape [1,2]. These shapes are shown schematically in FIGURE 1. A study by Alvord et al. [3] pointed out that elevated pressures and temperatures in excess of the saturation conditions may exist in a water target during bombardment. However, as long as the rate of condensation matches the rate of vaporization, the bulk of the system should remain at saturation conditions. Superheated regions are therefore likely to form but also likely to disappear rapidly, typically on the scale of a few milliseconds. Even though the boiling process is generally quite complex, enhanced by radiation-induced nucleation, the presence of fast mixing mechanisms in the water volume justifies some simplifications to be made. Materials and Methods The simplified model assumes that the bulk of the target water has a constant temperature, which is the same as the inner wall temperature of the cavity, Tw. A second simplification is to neglect the temperature difference across the target chamber wall, which is only justified if the wall is thin. The boiling is not explicitly taken into consideration, including the rather complex boiling behaviour at the Havar window, except to acknowledge that it is the main mixing mechanism. Large temperature gradients can briefly exist in the water medium but they also rapidly disappear. A further assumption is that a single, overall convective heat-transfer coefficient can be applied, which is constant over the entire water-cooled surface. As the wall thickness is neglected, the heat-transfer surface is assumed to be the inner surface of the cavity, excluding the surface of the Havar window. One can then write down an energy balance between the beam heating and the convection cooling (Newton’s law of cooling), where Ib is the beam intensity, ΔE is the energy windows of the target (taken as 18 MeV), h is the convective heat-transfer coefficient, A is the inner cavity surface through which the heat has to be transferred from the target-water volume to the cooling water, and T0 is the cooling-water temperature. The saturated vapour pressure of water versus temperature is a characteristic curve, given by the steam tables [4]. Assuming the bulk of the system at saturation conditions, one gets from (1) and (2). The function f is represented by a polynomial. The only unknown in Equation (3) is the overall convective heat-transfer coefficient h. Our approach was to adjust h until a good fit with a set of measured data was obtained. It also has to be mentioned that subtle differences in the physical properties between 18O-water and natural water have been neglected. All in all, quite a few assumptions and simplifications are made in deriving Equation (3) and the system is, admittedly, much more complex. Nevertheless, the results obtained by applying Equation (3) are rather interesting. Results and Conclusion Measured data and corresponding calculations are shown in FIGURE 2 for three different conical targets and one cylindrical target. The extracted convective heat-transfer coefficients are pre-sented in TABLE 1 for the four cavities. As can be seen in FIGURE 2, while there are some differences between the data and calculated curves, especially towards lower beam currents, the overall agreement is remarkably good. It is possible that the better agreement towards higher beam intensities is related to more ebullient boiling and more rapid mixing, i.e. closer to the conditions that the model assumes. The values obtained for the overall convective heat-transfer coefficient are also remarkably similar. This tells us that, by and large, all the cavities perform in a similar way and the performance in terms of maximum operational beam current depends largely on the available surface to effectively remove the heat from. The values of h increase marginally if a smaller value is adopted for the cooling water. Note that the choice of T0 = 30 ᵒC used to obtain the results in TABLE 1 is typical for the room temperature closed-loop cooling system used at iThemba LABS, once it has stabilized under operational conditions. A study by Buckley [5] on a quite different target design reports a value of h = 0.49 W cm−2 ᵒC−1, which is reassuringly similar. That study describes a cylindrical target cavity with a volume of 0.9 cm3, 8 mm deep, cooled with 25 ᵒC water from the back, operated with a 15 MeV proton beam with an intensity of 30 µA. The Nb Nirta targets are typically filled with 18O-water to about 60% of the cavity volume (see refs. [1,2] for the recommended values). The elongated shape, in combination with the ebullient properties of the boiling water, prevents burn-through. All the targets deliver the expected saturation yield. The targets are self-regulating ─ no external gas pressure is required. While the thermosyphon targets seemingly take advantage of a superior concept, we are now questioning whether this is really so in practice? It is not clear to us that the much more complex thermosyphon targets deliver any operational and/or performance advantages compared to the simple elegance of these elongated, single-cavity boiling target designs.
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Mulyadi, Henny. "Determination of residual gas saturation and gas-water relative permeability in water-driven gas reservoirs." Curtin University of Technology, Department of Petroleum Engineering, 2002. http://espace.library.curtin.edu.au:80/R/?func=dbin-jump-full&object_id=12957.

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The research on Determination of Residual Gas Saturation and Gas-Water Relative Permeability in Water-Driven Gas Reservoirs is divided into four stages: literature research, core-flooding experiments, development and application of a new technique for reservoir simulation. Overall, all stages have been completed successfully with several breakthroughs in the areas of Special Core Analysis (SCAL), reservoir engineering and reservoir simulation technology.Initially, a literature research was conducted to survey all available core analysis techniques and their individual characteristics. The survey revealed that there are several core analysis techniques for measuring residual gas saturation (Sgr) and hence, the lack of a commonly agreed method for measuring Sgr. The often-used core analysis techniques are steady-state displacement, co-current imbibition, centrifuge and counter-current imbibition. In this research, all centrifuge tests were performed with a decane-brine system to investigate the possibility of replacing gas with a 'model fluid' to minimise errors due to gas compressibility. Furthermore, Sgr is a function of testing temperature and pressure, types of fluid, wettability, viscosity, flow rate and overburden pressure. Consequently, large uncertainties are associated with measured Sgr and the recoverable gas reserves for water-driven gas reservoirs.Due to the lack of a common method for measuring Sgr, the first important step is to clarify which is the most representative core analysis technique for measuring Sgr. In Stage 2 of the research, core analysis experiments were performed with uniform fluids and ambient temperature. In the core flooding experiments, four different sets of core plugs from various gas reservoirs were selected to cover a wide range of permeability and porosity. Finally, all measured Sgr from the various common core analysis techniques ++
were compared.The evidence suggested that steady-state displacement and co-current imbibition tests are the most representative techniques for reservoir application. Steady-state displacement also yields the complete relative permeability (RP) data but it requires long stabilisation times and is costly.In the third stage, a new technique was successfully developed for determining both Sgr and gas-water RP data. The new method consists of an initial co-current imbibition experiment followed by the newly developed correlation (Mulyadi, Amin and Kennaird correlation). Co-current imbibition is used to measure the end-point data, for example, initial water saturation (Swi) and Sgr. The MAK correlation was developed to extend the co-current imbibition test by generating gas-water relative permeability data. Unlike previous correlations, MAK correlation is unique because it incorporates and exhibits the formation properties, reservoir conditions and fluid properties (for example, permeability, porosity, interfacial tension and gas density) to generate the RP curves. The accuracy and applicability of MAK correlations were investigated with several sets of gas-water RP data measured by steady-state displacement tests for various gas reservoirs in Australia, New Zealand, South-East Asia and U.S.A. The MAK correlation proved superior to previously developed correlations to demonstrate its robustness.The purpose of the final stage was to aggressively pursue the possibility of advancing the application of the new technique beyond special core analysis (SCAL). As MAK correlation is successful in describing gas water RP in a core plug scale, it is possible to extend its application to describe the overall reservoir flow behaviour. This investigation was achieved by implementing MAK correlation into a 3-D reservoir simulator (MoReS) and performing simulations on a producing ++
field.The simulation studies were divided into two categories: pre and post upscaled application.The case studies were performed on two X gas-condensate fields: X1 (post upscaled) and X2 (pre upscaled) fields. Since MAK correlation was developed for gas-water systems, several modifications were required to account for the effect of the additional phase (oil) on gas and water RP in gas-condensate systems. In this case, oil RP data was generated by Corey's equations. Five different case studies were performed to investigate the individual and combination effect of implementing MAK correlation, alternative Swi and Sgr correlations and refining porosity and permeability clustering. Moreover, MAK correlation has proven to be effective as an approximation technique for cell by cell simulation to advance reservoir simulation technology.
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Anderson, Jesse Charles. "The Intrinsic Variability in the Water Vapor Saturation Ratio Due to Turbulence." Thesis, Michigan Technological University, 2018. http://pqdtopen.proquest.com/#viewpdf?dispub=10684480.

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The water vapor concentration plays an important role for many atmospheric processes. The mean concentration is key to understand water vapor's effect on the climate as a greenhouse gas. The fluctuations about the mean are important to understand heat fluxes between Earth's surface and the boundary layer. These fluctuations are linked to turbulence that is present in the boundary layer. Turbulent conditions are simulated in Michigan Tech’s multiphase, turbulent reaction chamber, the Π chamber. Measurements for temperature and water vapor concentration were recorded under forced Rayleigh- Bénard convection at several turbulent intensities. These were used to calculate the saturation ratio, often referred to as the relative humidity. The fluctuations in the water vapor concentration were found to be the more important than the temperature for the variability of the saturation ratio. The fluctuations in the saturation ratio result in some cloud droplets experiencing a higher supersaturation than other cloud droplets, causing those "lucky" droplets to grow at a faster rate than other droplets. This difference in growth rates could contribute to a broadening of the size distribution of cloud droplets, resulting in the enhancement of collision-coalescence. These fluctuations become more pronounced with more intense turbulence.

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Li, Liqing. "Water saturation and air/water interfacial area measurements by partitioning gas tracers in the vadose zone and landfills." Access to citation, abstract and download form provided by ProQuest Information and Learning Company; downloadable PDF file, 176 p, 2008. http://proquest.umi.com/pqdweb?did=1464133931&sid=30&Fmt=2&clientId=8331&RQT=309&VName=PQD.

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Dalkhaa, Chantsalmaa. "Study Of Modeling Of Water Saturation In Archie And Non-archie Porous Media." Master's thesis, METU, 2005. http://etd.lib.metu.edu.tr/upload/12606350/index.pdf.

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The aim of this thesis is to study water saturation models available in the literature and to apply a proper one to a real field case. Archie equation is the most well-known water saturation model. However, it is formulated on some assumptions and is applicable to only clean sands. Archie equation cannot be used for shaly formation. There are many shaly water saturation models that account for shale effect for water saturation estimation. In this study, 3 wells, namely Well-01, Well-02 and Well-03 are studied. These wells lie in a fractured carbonate reservoir located in Southeastern part of Turkey. From well log recordings, the production formation is seen almost clean. In other words, the shale amount of the formation is so small that it can be neglected. Thus, to calculate the water saturation in those wells, the well-known Archie water saturation equation is used. Since the formation is fractured carbonate, the cementation factor (m ) and saturation exponent (n ) of conventional value of 2 each cannot be used for the water saturation calculation. Instead, these parameters are obtained from generalized crossplot of log-derived porosity and resistivity technique. Finally, each well is divided into zones using porosity data. Zonation is conducted based on statistical method, ANOVA (analysis of variance). Well-01 and Well-02 are both divided into two zones. On the other hand, the statistical method was initially divided Well-03 into three zones. However, Well-03 is better described as a whole zone, depending on the geological analysis and engineering judgment. After the zonation, the zones are correlated from well to well. The water saturations in significantly correlated zones are examined. Also, using the same statistical method, the water saturation zones are identified. However, these zones do not coincide with the porosity zones. This difference is attributed to pore size distribution and wettability which affect saturation distribution.
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Hoang, Ngoc Lan. "Etudes des propriétés hydromécaniques d’un sable limoneux : de la saturation partielle à la saturation complète." Thesis, Lyon, 2017. http://www.theses.fr/2017LYSET005/document.

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Cette thèse concerne la caractérisation expérimentale d’un sable limoneux provenant du barrage de Livet – Gavet (38) dans le cadre du projet ANR TerreDurable avec plusieurs objectifs : 1- Caractériser au travers d’essais de laboratoire le comportement hydromécanique d’un sable fin limoneux (sol A1 dans la classification GTR) en fonction de son état de saturation. Lors de cette étude, un accent particulier est porté sur la caractérisation de ce comportement dans le domaine proche de la saturation. 2- Interpréter le comportement hydrique du matériau sur chemin de drainage – imbibition en relation avec l’analyse de sa microstructure. 3- Fournir d’un point de vue général une base de données et d’analyses exhaustive permettant le développement et la calibration de modèles de comportement des sols fins proches de la saturation, en particulier en considérant des chemins de chargement hydromécanique complexes. Pour l’ensemble de cette étude, le matériau est considéré sous deux états : soit à l’état de pâte (matériau normalement consolidé) préparée à une teneur en eau proche de la limite de liquidité, soit sous forme compactée (matériau sur-consolidé) à différentes énergies de compactage et différentes teneurs en eau initiales
This thesis concerns the experimental characterization of a silty sand from the Livet - Gavet dam (38) as part of the ANR TerreDurable project, for following objectives: 1- Through laboratory tests, characterize the hydro-mechanical behaviour of a fine silty sand (Type A1 in the GTR classification) according to its saturation state. In this study, particular emphasis is placed on the characterization of this behaviour in the near-saturated domain. 2- Interpret the water behaviour of material on the drainage - imbibition cycles, in relation to the analysis of its microstructure. 3- From a general point of view, provide a comprehensive database and analysis allowing the development and calibration of models of near-saturated fine soil's behaviour, in particular, by considering complex hydro-mechanical loading paths. For all tests in this study, the material is considered in two states: either in the state of paste (normally consolidated material) prepared at water content close to the limit of liquidity, or in compacted state (over consolidated material) at different compaction energies and different initial water contents
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Kamgang, Thierry T. "Petro physical evaluation of four wells within Cretaceous gas-bearing sandstone reservoirs, In block 4 and 5 orange basin, South Africa." University of the Western Cape, 2013. http://hdl.handle.net/11394/4259.

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Masters of Science
Petrophysical evaluation of four wells within Cretaceous gas-bearing sandstone reservoirs in blocks 4 and 5 Orange Basin, South Africa. Thierry Kamgang The present research work evaluates the petrophysical characteristics of the Cretaceous gasbearing sandstone units within Blocks 4 and 5 offshore South Africa. Data used to carry out this study include: wireline logs (LAS format), base maps, well completion reports, petrography reports, conventional core analysis report and tabulated interpretative age reports from four wells (O-A1, A-N1, P-A1 and P-F1). The zones of interest range between 1410.0m-4100.3m depending on the position of the wells. The research work is carried out in two phases: The first phase corresponds to the interpretation of reservoir lithologies based on wireline logs. This consists of evaluating the type of rocks (clean or tight sandstones) forming the reservoir intervals and their distribution in order to quantify gross zones, by relating the behavior of wireline logs signature based on horizontal routine. Extensively, a vertical routine is used to estimate their distribution by correlating the gamma-ray logs of the corresponding wells, but also to identify their depositional environments (shallow to deep marine).Sedlog software is used to digitize the results. The second phase is conducted with the help of Interactive Petrophysics (version 4) software, and results to the evaluation of eight petrophysical parameters range as follow: effective porosity (4.3% - 25.4%), bulk volume of water (2.7% – 31.8%), irreducible water saturation (0.2%-8.8%), hydrocarbon saturation (9.9% - 43.9%), predicted permeability (0.09mD – 1.60mD), volume of shale (8.4% - 33.6%), porosity (5.5% - 26.2%) and water saturation (56.1% - ii 90.1%). Three predefined petrophysical properties (volume of shale, porosity and water saturation)are used for reservoir characterization. The volume of shale is estimated in all the wells using corrected Steiber method. The porosity is determined from the density logs using the appropriate equations in wells O-A1 and P-A1, while sonic model is applied in well A-N1 and neutron-density relationship in well P-F1. Formation water resistivity (Rw) is determined through the following equation: Rw = (Rmf × Rt) / Rxo, and water saturation is calculated based on Simandoux relation. Furthermore, a predicted permeability function is obtained from the crossplot of core porosity against core permeability, and it results match best with the core permeability of well O-A1. This equation is used to predict the permeability in the other wells. The results obtained reveal that average volumes of shale decrease from the west of the field towards the east; while average porosities and water saturations increase from the south-west through the east despite the decreasing average water saturation in well P-A1. A corroboration of reference physical properties selected for reservoir characterization, with predefined cut-off values result to no net pay zones identified within the reservoir intervals studied. Consequently, it is suggested that further exploration prospects should be done between well O-A1 and A-N1.
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Altayeb, Abdalmajid I. H. "Comprehensive fluid saturation study for the Fula North field Muglad Basin, Sudan." University of the Western Cape, 2016. http://hdl.handle.net/11394/5442.

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>Magister Scientiae - MSc
This study has been conducted to accurately determine fluid saturation within Fula sub-basin reservoirs which is located at the Southern part of the Republic of Sudan. The area is regarded as Shaly Sand Reservoirs. Four deferent shaly sand lithofacies (A, B, C, D) have been identified. Using method based on the Artificial Neural Networks (ANN), the core surrounding facies, within Fula reservoirs were identified. An average shale volume of 0.126 within the studied reservoirs was determined using gamma ray and resistivity logs. While average porosity of 26.7% within the reservoirs was determined using density log and the average core grain density. An average water resistivity of 0.8 Ohm-m was estimated using Pickett plot method. While formation temperature was estimated using the gradient that constrained between surface and bottom hole temperature. Water saturation was determined using Archie model and four shaly sand empirical models, the calculation was constrained within each facies zone to specify a model for each facies, and another approach was used to obtain the water saturation based on Artificial Neural Networks. The net pay was identified for each reservoir by applying cut-offs on permeability 5 mD, porosity 16%, shale volume 0.33, and water saturation 0.65. The gross thickness of the reservoirs ranges from 7.62m to 19.85m and net pay intervals from 4.877m to 19.202m. The study succeeded in establishing water saturation model for the Fula sub-basin based on neural networking which was very consistent with the core data, and hence has been used for net pay determination.
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Rosén, Tomas. "Determination of water saturation dependent gas transport properties of PEFC gas diffusion layers via the Lattice Boltzmann method." Thesis, KTH, Mekanik, 2011. http://urn.kb.se/resolve?urn=urn:nbn:se:kth:diva-41814.

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Dahlbäck, Per. "Modeling a novel sorption dehumidication method : super saturation of water vapour in a closed volume using the finite volume method." Thesis, Uppsala universitet, Avdelningen för beräkningsvetenskap, 2013. http://urn.kb.se/resolve?urn=urn:nbn:se:uu:diva-208511.

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This thesis develops and evaluates a method to simulate energy consumption and water production for a novel sorption dehumidication pro-cess. The system consists of a chamber comprising a hygroscopic materialand a heating device. The process consists of an adsorption phase anda regeneration phase. For both the regeneration phase and the adsorp-tion phase the model considers the heat distribution by thermal diusionand convection and the water transport by diusion and convection. Forthe regeneration phase the radiation is also considered since the radia-tive power increases with temperature to the power of four. Further, amodel for the condensation process is implemented and a model for thecondensation is suggested. To model the properties of the hygroscopicmaterials, the adsorption curves for SiO2 and AlO2 are investigated. Themodel were evaluated by comparing the simulated values with experimen-tal measurements.The results from the the simulation of the regeneration phase showsa good agreement with experimental data for the power and the energyconsumption even though the simulated values are a bit underestimated,about 10%. The water production is simulated to be about 25% higherthan the measured values. This discrepancy could be explained by aleakage of water vapour that was found in the experimental set up, whichis not considered in the model. This could also explain the underestimatedenergy consumption since the condensation energy in the system is toogreat. To improve the accuracy for the model the water leakage wouldneed to be implemented. The overestimation of water seemed to be thesame for the measurements from the same apparatus.For the adsorption phase a developed model, from an article for ad-sorption in silica, was implemented and tuned for the specic system. Thesimulations are in good agreement with the measurements but could betested further for more certainty.
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Books on the topic "Water saturation"

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Justić, Dubravko. Long-term trends of oxygen saturation in the northern Adriatic Sea =: Dugoročni trendovi zasićenja kisikom sjevernog Jadrana. Zagreb: Jugoslavenska akademija znanosti i umjetnosti, 1987.

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Dat, James Frederick. Growth, water relations and nutrient uptake of bean seedlings under different air saturation vapour pressure deficit and nutrition regimes. Ottawa: National Library of Canada, 1994.

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Jue, Melody, and Rafico Ruiz, eds. Saturation. Duke University Press, 2021. http://dx.doi.org/10.1215/9781478013044.

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Bringing together media studies and environmental humanities, the contributors to Saturation develop saturation as a heuristic to analyze phenomena in which the elements involved are difficult or impossible to separate. In ordinary language, saturation describes the condition of being thoroughly soaked, while in chemistry it is the threshold at which something can be maximally dissolved or absorbed in a solution. Contributors to this collection expand notions of saturation beyond water to consider saturation in sound, infrastructure, media, Big Data, capitalism, and visual culture. Essays include analyses of the thresholds of HIV detectability in bloodwork, militarism's saturation of oceans, and the deleterious effects of the saturation of cellphone and wi-fi signals into the human body. By channeling saturation to explore the relationship between media, the environment, technology, capital, and the legacies of settler colonialism, Saturation illuminates how elements, the natural world, and anthropogenic infrastructures, politics, and processes exist in and through each other. Contributors. Marija Cetinić, Jeff Diamanti, Bishnupriya Ghosh, Lisa Yin Han, Stefan Helmreich, Mél Hogan, Melody Jue, Rahul Mukherjee, Max Ritts, Rafico Ruiz, Bhaskar Sarkar, John Shiga, Avery Slater, Janet Walker, Joanna Zylinska
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Supersaturated electrolyte solutions: Theory and experiment. [Washington, DC: National Aeronautics and Space Administration, 1995.

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E, Singley J., and Water Engineering Research Laboratory, eds. Corrosion and calcium carbonate saturation index in water distribution systems. Cincinnati, OH: U.S. Environmental Protection Agency, Water Engineering Research Laboratory, 1985.

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Rutherford, John H. The measurement of partial water saturation in basalt rock using ultrasonics. 1993.

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Dunlop, Storm. 4. Water in the atmosphere. Oxford University Press, 2017. http://dx.doi.org/10.1093/actrade/9780199571314.003.0004.

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Among the planets in the Solar System, Earth is unique in possessing large quantities of water, and water’s properties are highly significant in determining weather. This is because water readily exists in three different phases (ice, liquid water, and water vapour) at temperatures frequently encountered on Earth. ‘Water in the atmosphere’ explains humidity and saturation: the number of molecules of water vapour in the air is determined solely by temperature. Unstable conditions lead to the formation of cumuliform clouds and precipitation is created by either glaciation or coalescence. There are three groups of clouds—cumuliform, stratiform, and cirriform—with ten types of cloud identified based on their altitude and structure.
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Rayment, George E., and David J. Lyons. Soil Chemical Methods - Australasia. CSIRO Publishing, 2010. http://dx.doi.org/10.1071/9780643101364.

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Soil Chemical Methods – Australasia describes over 200 laboratory and field chemical tests relevant to Australasia and beyond. The information and methodology provided across 20 chapters is comprehensive, systematic, uniquely coded, up-to-date and designed to promote chemical measurement quality. There is guidance on the choice and application of analytical methods from soil sampling through to the reporting of results. In many cases, optional analytical ‘finishes’ are provided, such as flow-injection analysis, electro-chemistry, multiple flame technologies, and alternatives to chemical testing offered by near-range and mid-range infrared diffuse reflectance spectroscopy. The book supersedes and updates the soil chemical testing section of the 1992 Australian Laboratory Handbook of Soil and Water Chemical Methods of Rayment and Higginson, while retaining method codes and other strengths of that Handbook. Chapters cover soil sampling, sample preparation and moisture content; electrical conductivity and redox potential; soil pH; chloride; carbon; nitrogen; phosphorus; sulphur; gypsum; micronutrients; extractable iron, aluminium and silicon; saturation extracts; ion-exchange properties; lime requirements; total miscellaneous elements; miscellaneous extractable elements; alkaline earth carbonates and acid sulfate soils. In addition, there are informative Appendices, including information on the accuracy and precision of selected methods. This book targets practising analysts, laboratory managers, students, academics, researchers, consultants and advisors involved in the analysis, use and management of soils for fertility assessments, land use surveys, environmental studies and for natural resource management.
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Staitieh, Bashar S., and Greg S. Martin. Therapeutic goals of fluid resuscitation. Oxford University Press, 2016. http://dx.doi.org/10.1093/med/9780199600830.003.0070.

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Optimizing tissue perfusion by administering intravenous fluids presents a special challenge to the intensive care unit (ICU) clinician. Recent studies have drastically altered how we assess a patient’s fluid responsiveness, particularly with regard to upstream surrogates of tissue perfusion. Central venous pressure and pulmonary capillary wedge pressure have been found to be inaccurate markers of fluid responsiveness and have given way to methods such as cardiac output as assessed by echocardiography and the various forms of arterial waveform analysis. These newer techniques, such as stroke volume variation, systolic pressure variation, and pulse pressure variation, have been found to better delineate which patients will respond to a fluid challenge with an increase in cardiac output, and which will not. In addition, traditional methods of assessing the consequences of excessive fluid administration, such as pulmonary oedema and the non-anion gap acidosis of saline administration, have given way to more sophisticated measurements of extravascular lung water, now available at the bedside. Downstream markers of tissue perfusion, such as base deficit, central venous oxygen saturations, and lactic acid, continue to be useful in particular clinical settings, but are all relatively non-specific markers, and are therefore difficult to use as resuscitation targets for ICU patients in general. Finally, recent data on septic shock and ARDS have demonstrated the importance of conservative fluid strategies, while data in surgical populations have emphasized the need for judicious fluid administration and attention to the balance of blood products used in resuscitation efforts.
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Book chapters on the topic "Water saturation"

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Etnyre, Lee M. "Formation Factor and Water Saturation." In Finding Oil and Gas from Well Logs, 49–89. Boston, MA: Springer US, 1989. http://dx.doi.org/10.1007/978-1-4757-5230-4_3.

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Ma, Y. Z. "Water Saturation Modeling and Rock Typing." In Quantitative Geosciences: Data Analytics, Geostatistics, Reservoir Characterization and Modeling, 517–37. Cham: Springer International Publishing, 2019. http://dx.doi.org/10.1007/978-3-030-17860-4_21.

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Wagner, Wolfgang, and Alfred Kruse. "Saturation State (Pressure Table)." In Properties of Water and Steam / Zustandsgrößen von Wasser und Wasserdampf, 121–28. Berlin, Heidelberg: Springer Berlin Heidelberg, 1998. http://dx.doi.org/10.1007/978-3-662-03529-0_10.

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Wagner, Wolfgang, and Alfred Kruse. "Saturation State (Temperature Table)." In Properties of Water and Steam / Zustandsgrößen von Wasser und Wasserdampf, 103–20. Berlin, Heidelberg: Springer Berlin Heidelberg, 1998. http://dx.doi.org/10.1007/978-3-662-03529-0_9.

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Wagner, Wolfgang, and Alfred Kruse. "Refractive Index (Including Saturation State)." In Properties of Water and Steam / Zustandsgrößen von Wasser und Wasserdampf, 349–54. Berlin, Heidelberg: Springer Berlin Heidelberg, 1998. http://dx.doi.org/10.1007/978-3-662-03529-0_18.

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Kobranova, V. N. "Oil and Gas Saturation. Chemically Bound Water." In Petrophysics / ПЕТРОФИЗИКА, 65–70. Berlin, Heidelberg: Springer Berlin Heidelberg, 1989. http://dx.doi.org/10.1007/978-3-662-09244-6_6.

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Kwaad, F. J. P. M. "Saturation Overland Flow on Loess Soils in the Netherlands." In Modelling Soil Erosion by Water, 225–35. Berlin, Heidelberg: Springer Berlin Heidelberg, 1998. http://dx.doi.org/10.1007/978-3-642-58913-3_17.

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Liu, Zaobao, Jianfu Shao, and Ying Xu. "Water Saturation Induced Strength Degradation of Callovo-Oxfordian Claystone." In Springer Series in Geomechanics and Geoengineering, 11–17. Cham: Springer International Publishing, 2017. http://dx.doi.org/10.1007/978-3-319-56397-8_2.

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Kuchuk-Katalan, Itzhak, Zvika Asaf, Eylam Ran, Dimitry Naroditsky, and Felix Aizik. "The Influence of Water Saturation in Soil on Blast Effect." In 28th International Symposium on Shock Waves, 81–86. Berlin, Heidelberg: Springer Berlin Heidelberg, 2012. http://dx.doi.org/10.1007/978-3-642-25688-2_12.

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Li, Ya, Ji-ping Wang, Jing-zhe Guo, and Te-bo Yang. "Irreducible Water Saturation Calculation Method Research Based on Fractal Theory." In Springer Series in Geomechanics and Geoengineering, 1869–77. Singapore: Springer Singapore, 2021. http://dx.doi.org/10.1007/978-981-16-0761-5_177.

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Conference papers on the topic "Water saturation"

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Alfosail, K. A., and A. U. Alkaabi. "Water Saturation in Shaly Formation." In Middle East Oil Show and Conference. Society of Petroleum Engineers, 1997. http://dx.doi.org/10.2118/37746-ms.

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Li, Kewen, Kevin Chow, and Roland N. Horne. "Effect of Initial Water Saturation on Spontaneous Water Imbibition." In SPE Western Regional/AAPG Pacific Section Joint Meeting. Society of Petroleum Engineers, 2002. http://dx.doi.org/10.2118/76727-ms.

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Crotti, Marcelo Alejandro. "Water Saturation in Tight Gas Reservoirs." In Latin American & Caribbean Petroleum Engineering Conference. Society of Petroleum Engineers, 2007. http://dx.doi.org/10.2118/107145-ms.

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Ravi, Vivek R., Safdar Ali, Timothy Dash, Mansoor Ali, Brian Chin, and Ricardo Hartanto. "Water Saturation in Unconventionals: Myth Busted." In Unconventional Resources Technology Conference. Tulsa, OK, USA: American Association of Petroleum Geologists, 2020. http://dx.doi.org/10.15530/urtec-2020-3002.

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Valenti, Nick P., R. M. Valenti, and L. F. Koederitz. "A Unified Theory on Residual Oil Saturation and Irreducible Water Saturation." In SPE Annual Technical Conference and Exhibition. Society of Petroleum Engineers, 2002. http://dx.doi.org/10.2118/77545-ms.

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Glotov, Anton Vasilievich. "Residual Water Content and Water Saturation of Bazhenov Formation Cores." In SPE Symposium: Petrophysics XXI. Core, Well Logging, and Well Testing. SPE, 2021. http://dx.doi.org/10.2118/208418-ms.

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Abstract The article presents a new method of determining the residual water content and water saturation of the Bazhenov rocks formation (unconventional reservoir), which is contingent on the synchronous thermal analysis integrated with gas FT-IR spectroscopy and mass spectroscopy. The studies were executed on extensive factual core material. The combination of thermal and spectrometric methods for the identification of gases which are released during heating of core samples facilitated to analyze the dynamics of water release and proposed methods of its separation accordingly by the degrees of connectivity.
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Al-Khaldi, Nasser Ali, Raphael A. Khamatdinov, Mohammed Helayel Al-Otaibi, Rabei Khalid Abdelrahim, and Mohamed Tahar Bouaouaja. "Water Saturation Modeling in Khafji Carbonate Reservoir." In Abu Dhabi International Petroleum Conference and Exhibition. Society of Petroleum Engineers, 2012. http://dx.doi.org/10.2118/161427-ms.

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Dash, Timothy, Safdar Ali, Mansoor Ali, Brian Chin, Ashish Mathur, Ricardo Hartanto, and Vivek Ravi. "WATER SATURATION IN UNCONVENTIONALS: THE REAL STORY." In 2020 SPWLA 61st Annual Online Symposium. Society of Petrophysicists and Well Log Analysts, 2020. http://dx.doi.org/10.30632/spwla-5042.

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Stalheim, S. O., and R. Kleven. "Estimation of Water Saturation from Tracer Data." In IOR 2005 - 13th European Symposium on Improved Oil Recovery. European Association of Geoscientists & Engineers, 2005. http://dx.doi.org/10.3997/2214-4609-pdb.12.c08.

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Malureanu, I. "Determination Of Water Saturation For Anisotropic Formations." In 4th Congress of the Balkan Geophysical Society. European Association of Geoscientists & Engineers, 2005. http://dx.doi.org/10.3997/2214-4609-pdb.26.o16-03.

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Reports on the topic "Water saturation"

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Michael Batzle. Seismic Evaluation of Hydrocarbon Saturation in Deep-Water Reservoirs. Office of Scientific and Technical Information (OSTI), April 2006. http://dx.doi.org/10.2172/898116.

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Michael Batzle, D-h Han, R. Gibson, and Huw James. SEISMIC EVALUATION OF HYDROCARBON SATURATION IN DEEP-WATER RESERVOIRS. Office of Scientific and Technical Information (OSTI), January 2005. http://dx.doi.org/10.2172/836821.

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Michael Batzle, D-h Han, R. Gibson, and Huw James. Seismic Evaluation of Hydrocarbon Saturation in Deep-Water Reservoirs. Office of Scientific and Technical Information (OSTI), January 2006. http://dx.doi.org/10.2172/876008.

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Michael Batzle, D-h Han, R. Gibson, and Huw James. SEISMIC EVALUATION OF HYDROCARBON SATURATION IN DEEP-WATER RESERVOIRS. Office of Scientific and Technical Information (OSTI), August 2005. http://dx.doi.org/10.2172/842825.

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Michael Batzle, D-h Han, R. Gibson, and Huw James. Seismic Evaluation of Hydorcarbon Saturation in Deep-Water Reservoirs. Office of Scientific and Technical Information (OSTI), October 2005. http://dx.doi.org/10.2172/859278.

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M. Batzle, D-h Han, R. Gibson, and O. Djordjevic. SEISMIC EVALUATION OF HYDROCARBON SATURATION IN DEEP-WATER RESERVOIRS. Office of Scientific and Technical Information (OSTI), March 2003. http://dx.doi.org/10.2172/816390.

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Zhang, Z. F. Soil Water Retention and Relative Permeability for Full Range of Saturation. Office of Scientific and Technical Information (OSTI), September 2010. http://dx.doi.org/10.2172/1001513.

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Belen, Rodolfo P. ,. Jr. Inferring immobile and in-situ water saturation from laboratory and field measurements. US: Stanford University, Stanford, CA, June 2000. http://dx.doi.org/10.2172/896518.

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Petersen, Kyle, Hugh M. Dainer, Andreas Fahlman, and Richard T. Mahon. Accelerated Decompression from Saturation at 132 Feet of Sea Water With Isobaric oxygenation at 60 Feet of Sea Water. Fort Belvoir, VA: Defense Technical Information Center, February 2009. http://dx.doi.org/10.21236/ada495419.

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Roberts, J. J., E. Carlberg, and W. Lin. Electrical properties of tuff from the ESF as a function of water saturation and temperature. Office of Scientific and Technical Information (OSTI), January 1998. http://dx.doi.org/10.2172/652973.

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