Correlations for physical properties of petroleum reservoir brines

Numbere, D.T.; Brigham, W.E.; Standing, M.B.

doi:10.2172/6733264

Cited by 16 publications

(7 citation statements)

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“…Figures and show the influence of the salinity (viscosity) on the liquid film velocity in different flow patterns. The brine water viscosity varied with salinity, as shown in eq and Table . For the droplet mode, the salinity (viscosity) had almost no influence on the change in the film velocity in the impact and nonimpact zones, the local maximum velocity in the impact zone, and the moment when the maximum velocity as salinity increased from 0 to 17%.…”

Section: Results and Discussionmentioning

confidence: 98%

Motion Evolution Mechanism of Falling Film over Horizontal Tube at Low-Spray Density

Zheng

Zhao

Wang

et al. 2022

Ind. Eng. Chem. Res.

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Horizontal falling film absorber has been widely applied in petroleum, chemical industry, and toxic gas disposal due to its advantages of large fluctuation of gas–liquid interface, accurately controlled interface, easy separation of gas–liquid interface, and low-pressure drop. The study of the velocity evolution of the liquid film at low-spray density is essential to understand the micro-mass transfer mechanism of the reactor and strengthen the absorption. The present study first deciphered the subregion features of the falling film motion over a horizontal tube with varied flow patterns and the parameters, such as spray density, spray height, and salinity that affects the velocity distribution of the falling film at low-spray density for the superhydrophilic surface, were also investigated using the modified PIV method. The result indicated that the velocity distribution of the film renders a typical subregion effect, i.e., nonimpact zone and impact zone for droplet mode, while, for jet mode, the film between the adjacent columns exists in the form of mutual repetition, and the velocity of the film will be slightly higher than that of the body motion region at the interaction ring. It was also found that the spray density and spray height had a positive effect on the average velocity of falling film over the horizontal tube for droplet mode and jet mode. However, for the droplet mode, the spray density increases the velocity of the film by increasing the frequency of the droplet impact. In addition, the average velocity of the film decreases with the increase in the salinity (viscosity).

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Section: Results and Discussionmentioning

confidence: 98%

Motion Evolution Mechanism of Falling Film over Horizontal Tube at Low-Spray Density

Zheng

Zhao

Wang

et al. 2022

Ind. Eng. Chem. Res.

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“…The salinity and temperature dependence of the ED and TE coupling coefficients for pure exclusion and pure diffusion cases are given by (Revil, 1999;Jackson et al, 2012a;Leinov and Jackson, 2014;Jackson, 2015) 𝐶 where subscripts 𝑒𝑑 and 𝑒𝑒 refers to pure diffusion and pure exclusion cases, respectively. 𝑡 𝑁𝑎 is the macroscopic Hittorf transport number for the Na ions, noting that this approach assumes charge transport is dominated by Na + and Clions arising from the dissociation of NaCl, which is a reasonable assumption for subsurface reservoirs (Numbere et al, 1977;Angelis, 2005). Experimentally measured data on shales, sandstones and carbonate rock samples lie between the pure exclusion and diffusion limits for both the ED and TE potentials (Figure C.1c,d).…”

Section: Appendix Cmentioning

confidence: 96%

Numerical modelling of self-potential in subsurface reservoirs

Alarouj

Ijioma

Graham

et al. 2021

Computers & Geosciences

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“…Some required parameters of the scaling equations were not reported in the references. Some non-reported parameters such as crude oil and brine viscosities and the crude oil-imbibing brine IFT were estimated using generally accepted correlations which were developed based on experimental data (Abooali et al 2019;Glaso, 1980;Numbere et al 1977) published in the literature with acceptable minor errors (correlations are explained in Appendix 1). However, the other non-reported data such as core dimensions and crude oil total acid number (TAN) cannot be estimated.…”

Section: Spontaneous Imbibition Tests Data Acquisitionmentioning

confidence: 99%

“…where temperature (T) and dead oil viscosity (µ od ) are in degrees Fahrenheit (℉) and centipoises (cp), respectively (Glaso, 1980). Numbere et al's correlation is used to estimate brines' viscosities (Numbere et al 1977):…”

Section: Appendixmentioning

confidence: 99%

Towards prediction of oil recovery by spontaneous imbibition of modified salinity brine into limestone rocks: A scaling study

Bassir

Behbahani

Shahbazi

et al. 2022

J Petrol Explor Prod Technol

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Spontaneous imbibition is a key mechanism of oil recovery in naturally fractured reservoirs. Many enhanced oil recovery techniques, such as modified salinity brine injection, have been suggested to improve spontaneous imbibition efficiency. To predict oil recovery by spontaneous imbibition process, scaling equations have been developed in the literature where almost none of them include the effect of two critical aspects. One aspect is the different ionic composition of injecting brine from connate brine. Another aspect is the effect of combination/interaction of a lower salinity imbibing (injecting) brine with connate brine. This research takes into account these two aspects to propose a new empirical scaling equation to scale oil recovery by modified salinity imbibing brines in limestone rocks. For this purpose, the results of available 59 tests from 14 references performed on various limestone rock samples collected from different formations and regions were used. The tests had been performed at high temperatures and on aged cores, which makes the proposed scaling equation more realistic and applicable to reservoir conditions. For the first time, the imbibing and connate brines ionic strengths are included in the equation due to the mechanism of the modified salinity brine injection method. In addition, the scaled spontaneous imbibition recovery data by the new equation was matched using two mathematical expressions based on the Aronofsky model and Fries and Dreyer model which can be used to derive transfer functions for simulation of spontaneous imbibition oil recovery by modified salinity brine injection in fractured limestone reservoirs.

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Correlations for physical properties of petroleum reservoir brines

Cited by 16 publications

References 0 publications

Motion Evolution Mechanism of Falling Film over Horizontal Tube at Low-Spray Density

Motion Evolution Mechanism of Falling Film over Horizontal Tube at Low-Spray Density

Numerical modelling of self-potential in subsurface reservoirs

Towards prediction of oil recovery by spontaneous imbibition of modified salinity brine into limestone rocks: A scaling study

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