Showing papers on "Brine published in 2015"
TL;DR: In this paper, the separation efficiency of a nanofiltration membrane was investigated and the relationship between the rejection rates of magnesium and lithium was established, and the extractions of lithium from salt lake brines were also evaluated.
Abstract: Owing to the high ratio of Mg 2+ to Li + in most of the salt lake brines in China, it is difficult to extract lithium. Therefore, the separation efficiency of a nanofiltration membrane was investigated in this study. Operating conditions such as operating pressure, inflow water temperature, pH, and Mg 2+ /Li + ratio were investigated. Relationship between the rejection rates of magnesium and lithium was established. Moreover, the extractions of lithium from salt lake brines were also evaluated. The results indicate that the separation of magnesium and lithium was highly dependent on the Mg 2+ /Li + ratio, operating pressure, and pH. When the Mg 2+ /Li + ratio was 2+ /Li + ratio. The permeate flux of membrane for the East Taijiner brine was higher than that for the West Taijiner brine.
152 citations
TL;DR: An electrochemical lithium recovery method based on a λ-MnO2/activated carbon hybrid supercapacitor system that has high selectivity and long-term stability, with its performance being retained even after repetitive captures and releases of lithium ions is reported.
143 citations
TL;DR: In this article, a comprehensive model for the RED process using sea or brackish water and concentrated brine as feed solutions is proposed, which reliably describes the physical phenomena involved in the process and provides information for optimal equipment design.
Abstract: Reverse electrodialysis (SGP-RE or RED) represents a viable technology for the conversion of the salinity gradient power into electric power. A comprehensive model is proposed for the RED process using sea or brackish water and concentrated brine as feed solutions. The goals were (i) reliably describing the physical phenomena involved in the process and (ii) providing information for optimal equipment design. For such purposes, the model has been developed at two different scales of description: a lower scale for the repeating unit of the system (cell pair), and a higher scale for the entire equipment (stack). The model was implemented in a process simulator, validated against original experimental information and then used to investigate the influence of the main operating factors and on power output. Feed solutions of different salinities were also tested. A good matching was found between predictions and experiments for a wide range of inlet concentrations, flow rates and feed temperatures. Optimal feed conditions, for the adopted system geometry and membranes, have been found employing brackish water (0.08–0.1 M NaCl) as dilute and brine (4.5–5 M NaCl) as concentrate to generate the highest power density at 40 °C temperature. The model can be used to explore the full potential of the RED technology, especially for any investigation regarding the future scale-up of the process.
132 citations
TL;DR: In this paper, the synergistic effect of 1,3-bis(dodecyldimethylammonium chloride)-2-propanol and a Gemini surfactant for mild steel in H 2 S and CO 2 saturated brine solution was investigated by using polarization test and XPS.
125 citations
TL;DR: In this paper, Li + exchange capacity and stability of anode-cathode distance, electrolyte temperature, surface density of active substrate and electrolysis time were optimized for brine extraction by membrane electrolysis.
112 citations
TL;DR: In contrast to conventional hydrothermal systems or enhanced geothermal systems, CO 2 Plume Geothermal (CPG) systems generate electricity by using CO 2 that has been geothermally heated due to sequestration in a sedimentary basin this article.
109 citations
TL;DR: In this paper, a technique to optimise thermal efficiency using brine recycling during direct contact membrane distillation (DCMD) of seawater was investigated, and the results showed that in the optimal water recovery range of 20 to 60% facilitated by brini recycling, the specific thermal energy consumption of the process could be reduced by more than half.
103 citations
TL;DR: In this paper, the authors systematically assess the efficiency of chemical cleaning and report a simple but elegant approach to control scaling during membrane distillation (MD) of brine from reverse osmosis (RO) treatment of coal seam gas (CSG) produced water.
97 citations
TL;DR: In this article, the predictive model based on least square support vector machine (LSSVM) was used to estimate the amount of dissolved calcium carbonate concentration in oil field brines.
91 citations
TL;DR: In this paper, the synergistic behavior that occurs when three different cationic inhibitors for clay swelling were associated with brines containing NaCl and KCl was evaluated and the results showed different efficiencies, in other words, inhibitors mixed with brine were more effective than the inhibitors alone.
91 citations
TL;DR: In this paper, a two-step base-catalysed sol-gel method using tetraethyl orthosilicate TEOS as the silica precursor and triblock copolymer of Pluronic® P123 as the templating agent was used to synthesize template silica membranes for water desalination for brackish (03,wt), sea water (35,wt%), and brine (75,wt%) NaCl solutions at temperatures range from 22 to 60°C
TL;DR: In this article, the authors investigated the scale reduction and cleaning techniques for direct contact membrane distillation (DCMD) during processing of seawater reverse osmosis (SWRO) brine at feed and distillate temperature of 50°C and 25°C, respectively.
TL;DR: In this article, the authors focused on the direct contact membrane distillation (DCMD) capability to treat hyper-saline solution and the governing operative model for mass transfer was investigated.
TL;DR: In this paper, a mass balance calculation is used to estimate the amount of brine salt in the flowback of a Marcellus well, assuming that 2% by volume of the shale initially contains water as capillary-bound or free Appalachian brine, and the remaining water imbibes into the shale.
Abstract: Between 2005 and 2014 in Pennsylvania, about 4000 Marcellus wells were drilled horizontally and hydraulically fractured for natural gas. During the flowback period after hydrofracturing, 2 to (7 to ) of brine returned to the surface from each horizontal well. This Na-Ca-Cl brine also contains minor radioactive elements, organic compounds, and metals such as Ba and Sr, and cannot by law be discharged untreated into surface waters. The salts increase in concentration to () in later flowback. To develop economic methods of brine disposal, the provenance of brine salts must be understood. Flowback volume generally corresponds to ∼10% to 20% of the injected water. Apparently, the remaining water imbibes into the shale. A mass balance calculation can explain all the salt in the flowback if 2% by volume of the shale initially contains water as capillary-bound or free Appalachian brine. In that case, only 0.1%–0.2% of the brine salt in the shale accessed by one well need be mobilized. Changing salt concentration in flowback can be explained using a model that describes diffusion of salt from brine into millimeter-wide hydrofractures spaced 1 per m (0.3 per ft) that are initially filled by dilute injection water. Although the production lifetimes of Marcellus wells remain unknown, the model predicts that brines will be produced and reach 80% of concentration of initial brines after ∼1 yr. Better understanding of this diffusion could (1) provide better long-term planning for brine disposal; and (2) constrain how the hydrofractures interact with the low-permeability shale matrix.
TL;DR: Results showed that non-supported membranes generally have a higher overall mass transfer coefficient but porosity seems to be the most important parameter controlling membrane flux and thermal efficiency.
TL;DR: In this paper, a two-layer corrugated composite flat sheet polyvinylidenefluoride (PVDF) membrane was fabricated, characterized and tested in a lab-scale direct contact membrane distillation (DCMD) system for improved flux stabilization.
TL;DR: In this article, a nonionic surfactant with a high degree of ethoxylation resulted in a high cloud point temperature of 83 °C even in 90 g/L NaCl brine.
Abstract: The utilization of nonionic surfactants for stabilization of CO2 foams has been limited by low aqueous solubilities at elevated temperatures and salinities. In this work, a nonionic surfactant C12–14(EO)22 with a high degree of ethoxylation resulted in a high cloud point temperature of 83 °C even in 90 g/L NaCl brine. Despite the relatively high hydrophilic–CO2-philic balance, the surfactant adsorption at the C–W interface lowered the interfacial tension to ∼7 mN/m at a CO2 density of ∼0.85 g/mL, as determined with captive bubble tensiometry. The adsorption was sufficient to stabilize a CO2-in-water (C/W) foam with an apparent viscosity of ∼7 cP at 80 °C, essentially up to the cloud point temperature, in the presence of 90 g/L NaCl brine in a 30 darcy sand pack. In a 1.2 darcy glass bead pack, the apparent viscosity of the foam in the presence of 0.8% total dissolved solids (TDS) brine reached the highest viscosity of ∼350 cP at 60% foam quality (volume percent CO2) at a low superficial velocity of 6 ft/d...
TL;DR: In this paper, the effects of four anti-scaling and five cleaning agents on calcium sulfate scaling in direct contact membrane distillation (DCMD) process were investigated and discussed.
TL;DR: In this article, the authors investigated the utilization of ionic liquids (ILs), known as environment friendly salt with good solubility, thermal stability and effective surface activity, as an alternative to conventional organic surfactants in enhanced oil recovery process.
Abstract: Substantial amount of crude oil remains in the reservoir after primary and secondary production. Chemical flooding is one of the enhanced oil recovery (EOR) methods; however, chemicals (i.e., Surfactant) used are sensitive to the harsh environment characterizing the local reservoirs. The current study aimed at investigating the utilization of ionic liquids (ILs), known as environment friendly salt with good solubility, thermal stability and effective surface activity, as an alternative to conventional organic surfactants in enhanced oil recovery process. In this work, screening tests of nine ILs were performed. These ILs were diluted in different brine solutions of different salt compositions at 10 % (w/w) salinity and their solubility, thermal stability and surface activity in presence of Saudi medium crude oil were tested. Tetra alkyl ammonium sulfate known as Ammoeng 102 was found to be the ionic liquid of choice. Further investigations on Ammoeng 102 solutions at 10 and 20 % (w/w) salinity were conducted and IFT measurements indicate enhanced surface activity of Ammoeng 102 with increasing solution salinity. Effects of pressure and temperature on interfacial tension (IFT) were also tested and the results indicate minor effects. Adsorption test indicates high Ammoeng 102 adsorption tendency with more adsorption for higher salinity solution. Different flooding scenarios were conducted in sandstone rock samples to investigate the effectiveness of Ammoeng 102 IL as an EOR chemical. The findings indicate promising results for ionic solution flooding in secondary mode at irreducible water saturation (S
wirr). Ultimate recovery obtained is higher than that obtained with combined secondary brine flooding followed by tertiary ionic solution flooding at residual oil saturation (S
or). Injection of slug of ionic solution in secondary mode provides lower recovery compared to that recovered with continuous ionic solution injection in the same mode. Rock water content affects recovery efficiency indicating higher oil recovery for secondary brine and tertiary ionic solution flooding at low S
wirr. Contact angle and relative permeability measurements demonstrate the role of wettability alteration behind the extra oil recovery which is very much affected by ionic liquid concentration that can be altered by dilution with formation and injected brines.
TL;DR: In this paper, the authors reported a method to improve the power generation using brines discharged from two different membrane-based desalination processes, and they modified a RED model proposed by Veerman and co-workers, and this modified model was in agreement with experimental results.
TL;DR: In this paper, a hollow fiber membrane module was tested at various air and brine flow rates and temperatures, and a model based on heat and mass transport was developed to predict permeate production rates.
TL;DR: In this article, the major geochemical characteristics of Red Sea brine are summarized for 11 brine-filled deeps located along the central graben axis between 19°N and 27°N.
Abstract: The major geochemical characteristics of Red Sea brine are summarized for 11 brine-filled deeps located along the central graben axis between 19°N and 27°N. The major element composition of the different brine pools is mainly controlled by variable mixing situations of halite-saturated solution (evaporite dissolution) with Red Sea deep water. The brine chemistry is also influenced by hydrothermal water/rock interaction, whereas magmatic and sedimentary rock reactions can be distinguished by boron, lithium, and magnesium/calcium chemistry. Moreover, hydrocarbon chemistry (concentrations and δ 13 C data) of brine indicates variable injection of light hydrocarbons from organic source rocks and strong secondary (bacterial or thermogenic) degradation processes. A simple statistical cluster analysis approach was selected to look for similarities in brine chemistry and to classify the various brine pools, as the measured chemical brine compositions show remarkably strong concentration variations for some elements. The cluster analysis indicates two main classes of brine. Type I brine chemistry (Oceanographer and Kebrit Deeps) is controlled by evaporite dissolution and contributions from sediment alteration. The Type II brine (Suakin, Port Sudan, Erba, Albatross, Discovery, Atlantis II, Nereus, Shaban, and Conrad Deeps) is influenced by variable contributions from volcanic/ magmatic rock alteration. The chemical brine classification can be correlated with the sedimentary and tectonic setting of the related depressions. Type I brine-filled deeps are located slightly off-axis from the central Red Sea graben. A typical " collapse structure formation " which has been defined for the Kebrit Deep by evaluating seismic and geomorphological data probably corresponds to our Type I brine. Type II brine located in depressions in the northern Red Sea (i.e., Conrad and Shaban Deeps) could be correlated to " volcanic intrusion-/extrusion-related " deep formation. The chemical indications for hydrothermal influence on Conrad and Shaban Deep brine can be related to brines from the multi-deeps region in the central Red Sea, where volcanic/magmatic fluid/rock interaction is most obvious. The strongest hydrothermal influence is observed in Atlantis II brine (central multi-deeps region), which is also the hottest Red Sea brine body in 2011 (*68.2 °C).
TL;DR: In the case of flotation of potash ores in seawater, molybdenite is strongly depressed by the Mg2+ hydrolysis products when pH is raised to depress pyrite as discussed by the authors.
TL;DR: In this paper, the Pitzer thermodynamic model for solid-liquid equilibria in the quinary system LiCl−NaCl−KCl−SrCl2−H2O at 298.15 K was constructed by selecting the proper parameters for the subsystems in the literature.
Abstract: In this study, the Pitzer thermodynamic model for solid-liquid equilibria in the quinary system LiCl–NaCl–KCl–SrCl2–H2O at 298.15 K was constructed by selecting the proper parameters for the subsystems in the literature. The solubility data of the systems NaCl–SrCl2–H2O, KCl–SrCl2–H2O, LiCl–SrCl2–H2O, and NaCl–KCl–SrCl2–H2O were used to evaluate the model. Good agreement between the experimental and calculated solubilities shows that the model is reliable. The Pitzer model for the quinary system at 298.15 K was then used to calculate the component solubilities and conduct computer simulation of isothermal evaporation of the mother liquor for the oilfield brine from Nanyishan district in the Qaidam Basin. The evaporation-crystallization path and sequence of salt precipitation, change in concentration and precipitation of lithium, sodium, potassium, and strontium, and water activities during the evaporation process were demonstrated. The salts precipitated from the brine in the order : KCl, NaCl, SrCl2∙6H2O, SrCl2∙2H2O, and LiCl∙H2O. The entire evaporation process may be divided into six stages. In each stage the variation trends for the relationships between ion concentrations or water activities and the evaporation ratio are different. This result of the simulation of brines can be used as a theoretical reference for comprehensive exploitation and utilization of this type ofmore » brine resources.« less
TL;DR: In this paper, a hybrid system that integrates a multi-stage vacuum membrane distillation (MVMD) with pressure-retarded osmosis (PRO) is introduced, which employs a recycling flow scheme (MVDM-R) for continuous production of both distillate water and highly concentrated brine.
TL;DR: In this article, an unconventional method, called the potentiometric titration, was used to obtain the solubility of CO2 in distilled water and NaCl brine.
Abstract: The solubility of CO2 in brine is one of the trapping mechanisms by which the CO2 is sequestrated in aquifers. In this research, an unconventional method, called the potentiometric titration, was used to obtain the solubility of CO2 in distilled water and NaCl brine. The solubility data for the low salinity range are scarce in the literature. Thus, in this research, the CO2 solubility was obtained in NaCl brines of low salinity (0–15 000 ppm) at temperatures between 60 °C and 100 °C and pressures up to 25 MPa. Moreover, the salting-out effect was estimated using the Setchenov’s constant as a measure of reduction in solubility when salt is added to the solution. The solubility points obtained by the potentiometric titration method demonstrated very good consistency with those obtained by the previous methods.
TL;DR: In this article, an anionic sulfonate and an amphoteric acetate surfactant were selected to achieve good thermal and chemical stability, and to minimize adsorption to sandstone reservoirs in the harsh high-salinity high-temperature brine.
Abstract: The sweep efficiency of CO2 enhanced oil recovery can be improved by forming viscous CO2-in-water (C/W) foams that increase the viscosity of CO2. The goal of this study is to identify CO2-soluble ionic surfactants that stabilize C/W foams at elevated temperatures up to 120 °C in the presence of a high salinity brine using aqueous phase stability, static and dynamic adsorption, CO2 solubility, interfacial tension, foam bubble size, and foam viscosity measurements. An anionic sulfonate surfactant and an amphoteric acetate surfactant were selected to achieve good thermal and chemical stability, and to minimize adsorption to sandstone reservoirs in the harsh high-salinity high-temperature brine. The strong solvation of the surfactant head by the brine phase and surfactant tail by CO2 allows efficient reduction of the C/W interfacial tension, and the formation of viscous C/W foams at high salinity and high temperature. Furthermore, the effect of temperature and methane dilution of CO2 on foam viscosity was eva...
TL;DR: The previously developed model (PSUCO2) was extended to calculate CO2 solubility in aqueous mixed-salt solution by using the additivity rule of the Setschenow coefficients of the individual ions (Na, Ca, Ca(2+), Mg, K, Cl, and SO4(2-)).
Abstract: CO2 solubility data in the natural formation brine, synthetic formation brine, and synthetic NaCl+CaCl2 brine were collected at the pressures from 100 to 200 bar, temperatures from 323 to 423 K. Experimental results demonstrate that the CO2 solubility in the synthetic formation brines can be reliably represented by that in the synthetic NaCl+CaCl2 brines. We extended our previously developed model (PSUCO2) to calculate CO2 solubility in aqueous mixed-salt solution by using the additivity rule of the Setschenow coefficients of the individual ions (Na(+), Ca(2+), Mg(2+), K(+), Cl(-), and SO4(2-)). Comparisons with previously published models against the experimental data reveal a clear improvement of the proposed PSUCO2 model. Additionally, the path of the maximum gradient of the CO2 solubility contours divides the P-T diagram into two distinct regions: in Region I, the CO2 solubility in the aqueous phase decreases monotonically in response to increased temperature; in region II, the behavior of the CO2 solubility is the opposite of that in Region I as the temperature increases.
TL;DR: In this article, the preparation, characterisation and testing of TiO2 membranes dip-coated on commercial Ot-Al2O3 tubes for desalination is presented.