Petroleum and Gas Field Processing

Abdel-Aal, Hussein K.; Aggour, Mohamed A.; Fahim, Mohamed A.

doi:10.1201/9780429258497

Cited by 51 publications

(26 citation statements)

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“…Such water-in-oil (w/o) emulsions are frequently formed and stabilized during oil production (e.g., as a result of high-pressure drops through choke valves and pumps) and are usually already present when the produced fluids reach the primary gas–water–oil separation vessel. The resulting operational problems are numerous and include − enhanced corrosion from dissolved salts in the water phase, flow assurance concerns and/or hydrate formation, and difficulty meeting crude oil product specifications. The emulsions typically consist of micrometer-scale water droplets stabilized in a continuous oil phase.…”

Section: Introductionmentioning

confidence: 99%

“…Problematic w/o emulsions are particularly acute for older, more marginal oilfields, which are typically characterized by higher water cuts, silt, and asphaltene content . Surface-active species in crude oil, such as asphaltenes, resins, wax, naphthenic acids, and fine particles, are known to contribute to the stability of oilfield emulsions. ,, Particularly for the case of formation water, these emulsions are in practice characterized by a range of droplet (water) phase salinities. While a significant amount of literature focuses on the effect of various potential surface agents on oilfield emulsion stability, the focus of the work presented here will be on the effects of salinity on this emulsion stability.…”

Section: Introductionmentioning

confidence: 99%

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Quantifying the Effect of Salinity on Oilfield Water-in-Oil Emulsion Stability

et al. 2018

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The effect of salinity on water-in-oil emulsions was systematically studied using a combination of nuclear magnetic resonance (NMR) pulsed field gradient (PFG) measurements of emulsion droplet size distribution complemented by interfacial tension measurements using the pendant drop method. Long-term emulsion stability over periods of up to 5 days was found to increase with salinity; this was shown to be independent of whether a monovalent (NaCl) or divalent (CaCl2) salt was used. The methodology was applied to water-in-oil emulsions formulated with crude oil, paraffin oil, xylene, crude oil with reduced asphaltene content, and crude oil with reduced organic acid content as the continuous phase, respectively. In all cases, emulsion stability increased consistently with aqueous phase salinity, with no discernible difference between the continuous oil phases with respect to the extent of this stabilization. The enhanced stability could thus not be attributed to differences in density, interfacial tension, or dielectric permittivity. This leaves a potential increased surface accumulation of stabilizing surface-active species driven by increasing salinity as the most plausible explanation for the observations reported here.

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Section: Introductionmentioning

confidence: 99%

Section: Introductionmentioning

confidence: 99%

Quantifying the Effect of Salinity on Oilfield Water-in-Oil Emulsion Stability

et al. 2018

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“…According to Fahim et al, the inlet temperature of the oil is usually kept between 50 and 55 °C in the desalting process, as a way to reduce oil viscosity and, consequently, increase the settling rate, and this temperature is normally enhancing along the process. At the same time, the operational pressure is maintained between 3 and 18 bar to keep the oil as a liquid phase . On the basis of this information, the experimental variables (conditions) were selected and are shown in Table .…”

Section: Experimental Sectionmentioning

confidence: 99%

Study of Asphaltene Precipitation in Crude Oils at Desalter Conditions by Near-Infrared Spectroscopy

et al. 2017

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The asphaltene precipitation and deposition cause severe operational, economic, and environmental problems to the petroleum industry in all of its streams, such as pipe clogging, emulsion stabilization, and incrustation in separators. It is induced by temperature, pressure, and composition changes at crude oil production and refinement. The crude oil incompatibility is the main reason for asphaltene precipitation at refinery plants. Although it has been the subject of studies for the last 50 years, there is still a lack of robust and reliable tools that can detect and monitor the asphaltene precipitation online. In this scenario, the present work aims to use near-infrared spectroscopy to analyze the oil compatibility regarding asphaltene stability as well as to study the influences of pressure, temperature, and composition variation at desalter conditions. For this, a near-infrared spectrometer equipped with a transflectance probe connected to a variable volume high-pressure cell was used. The results showed that the temperature, pressure, and rate of flocculant agent addition on the crude oil presented a small influence on the asphaltene precipitation onset at the experimental range studied. The interaction among the compounds in oil blends was the only factor that changed the asphaltene stability level.

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“…The velocity of the gas in the separator must not exceed the settling velocity. A liquid droplet size of 125 μm is assumed to be the cut off target for separation . The separator length ( L sep ) is computed by assuming a slenderness ratio of 3 (the ratio of the separator length to its diameter) .…”

Section: Process Description and Optimization Problemmentioning

confidence: 99%

“…A liquid droplet size of 125 μm is assumed to be the cut off target for separation . The separator length ( L sep ) is computed by assuming a slenderness ratio of 3 (the ratio of the separator length to its diameter) . The separator is a pressure vessel, therefore its cost is based upon its weight.…”

Section: Process Description and Optimization Problemmentioning

confidence: 99%

Optimization of Adsorption-Based Natural Gas Dryers

Wahedi¹,

Rabie²,

Shaiba

et al. 2016

Ind. Eng. Chem. Res.

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Common approaches in designing natural gas dryers are based on empirical algebraic correlations and design heuristics. Such approaches fail to capture the process physics and are generally not optimal. In this work a new method for the design of natural gas dryers is presented. The method formulates a mixed integer nonlinear programming (MINLP) problem where the objective is to minimize the net present value of ensued costs (NPVC) of the drying system throughout its lifetime, while meeting all process constraints. Two process schemes based on common industrial conditions are considered, which differ in the source of the regeneration gas. Both schemes are shown to attain an optimal NPVC in the range of 4.5 to 5.4 $/MMSCF. When compared to conventional methods, this represents a reduction in the range of 17- 37%. The cost savings are primarily achieved from the optimization of the adsorption time, regeneration time, and the regeneration gas flow rate, thus illustrating the advantages of the proposed optimal design.

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Petroleum and Gas Field Processing

Cited by 51 publications

References 0 publications

Quantifying the Effect of Salinity on Oilfield Water-in-Oil Emulsion Stability

Quantifying the Effect of Salinity on Oilfield Water-in-Oil Emulsion Stability

Study of Asphaltene Precipitation in Crude Oils at Desalter Conditions by Near-Infrared Spectroscopy

Optimization of Adsorption-Based Natural Gas Dryers

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