1. Introduction
Hydrogen (H
2) is an important natural gas because it is light, storable, and reactive [
1]. H
2 is considered the best energy carrier for the efficient storage of renewable primary energy sources such as solar and wind energy [
2]. On the one hand, the combustion of H
2 does not emit pollutants and greenhouse gases; the only combustion product is H
2O; on the other hand, H
2 has a high calorific value of ~140 MJ/kg [
3]. H
2 is potentially suitable for large-scale geological storage in porous formations, saline aquifers, caverns, or depleted oil and gas reservoirs, all of which can provide significant storage capacity [
4,
5,
6]. To assess the stability and safety of the long-term operation of hydrogen storage reservoirs and the efficiency of energy storage, one should study the solubility and volumetric properties of H
2 in gas−liquid systems for the migration of fluids and the alteration of minerals induced during storage [
7]. Moreover, H
2 is abundantly present in nature. Hydrogen production can be divided into inorganic and organic geneses. Inorganic hydrogen is usually produced via earth degassing, water–rock reactions, and water radiolysis [
8,
9,
10], whereas organic hydrogen is primarily produced via biogenesis and the thermal decomposition of organic matter [
11,
12]. Natural hydrogen is abundant in the formation areas of terrestrial volcanic rocks, large fault basins, marine serpentinized areas, and hydrothermal vents [
9,
13,
14]. Hydrogen can be utilized as an electron donor in the reactions of photoautotrophic, photoheterotrophic, chemoautotrophic, and chemoheterotrophic organisms [
15]. Most typically, autotrophic hydrogen bacteria consume hydrogen to produce life-sustaining methane, which explains the abundance of hydrogen-consuming organisms in submarine hydrothermal vents [
16,
17,
18]. In studies on hydrogen-related biological activities or physicochemical processes, the hydrogen supply rate and hydrogen concentration in fluids must be determined. Moreover, H
2 solubility in a fluid largely determines the hydrogen transport rate and hydrogen concentration in the dissolved state.
Experiments using various solutions have yielded a large amount of H
2 solubility data at various temperatures and pressures. Additionally, H
2 solubility data have been accumulating since 1855. Using the pure physical absorption method, Bunsen [
19] measured the absorption coefficients of H
2 in pure water at various temperatures (277.15–296.75 K) and atmospheric pressure. However, because H
2 shows low solubility in water at atmospheric pressure and the experimental conditions were limited, the measurement results were very similar. Using the same method, Wiebe and Gaddy [
20] measured the absorption coefficients of hydrogen in pure water over a wide temperature range (273.15–373.15 K) and different pressures (25–1000 atm). They treated nitrogen impurities in the hydrogen so that gas composition was close to pure hydrogen and the influence of the water-vapor partial pressure on solubility was corrected. Chabab et al. [
21] employed the static analysis method to measure H
2 solubility in pure water and aqueous NaCl solutions (1, 3, and 5 mol/kg) at different temperatures (323.18–372.76 K) and pressures (28.623–229.720 bar).
A model based on experimental data can be used to predict H
2 solubility in an unmeasured system. Jauregui-Haza et al. [
22] studied H
2 solubility in water and organic solvents such as octene, toluene, and nonanal. They applied regular solution theory using the polar solvent factor correction method reported by Lemcoff [
23]. Moreover, they derived the Henry constant of H
2 at temperatures of 353, 363, and 373 K. The H
2 solubility error in the aforementioned solvents was ~2.6%; however, the model was only applicable to pure aqueous solutions and the Henry constant of H
2 was not determined in aqueous NaCl solutions. Li et al. [
7] considered the system pressure, temperature, and formation fluid salinity in an H
2 solubility model. Their model reproduced all available experimental data and accurately predicted H
2 solubility in formation fluids under a range of typical geological hydrogen storage conditions (273–373 K, 1–500 bar, and 0–5 mol/kg NaCl). Within or close to the experimental data uncertainty, H
2 solubility was predicted with a maximum relative error of 5% in pure water; however, the error increased to 15% in brine. Chabab et al. [
21] estimated the H
2 solubility using a fast method based on a Setschenow-type relation [
24], which predicted H
2 solubility in pure water and aqueous NaCl solutions with average deviations of 0.5% and 2%, respectively. This model was adapted to the temperature and pressure ranges of 273.15–373.15 K and 1–203 bar, respectively, in pure water, and 323.15–373.15 K and 10–230 bar, respectively, in aqueous NaCl solutions. However, in aqueous NaCl, the lower bound of this model was 323.15 K, which is unsuitable for studying H
2 solubility in nature. Torín-Ollarves and Trusler [
25] proposed a simple model based on an analysis method for predicting H
2 solubility in aqueous solutions at temperatures and pressures of 273.15–423.15 K and 1–1010 bar, respectively. For reasons that defy a logical explanation, the prediction results of this model quite differed from those reported by Chabab et al. [
21].
Duan et al. [
26] established a solubility model of methane gas in aqueous solutions. Their model applies a specific theory of particle interactions for the liquid phase and a high-precision equation of state for the vapor phase. The methane solubility in both pure water and aqueous NaCl solutions was predicted for the temperature range of 273.15–523.15 K and the pressure range of 0–1600 bar. The error between the calculated and experimental data was ~7%. The parameters in this model were fitted to the experimental data and represented the interactions between substances. The values of different parameters were closely related, suggesting that the model is applicable to complex brines (e.g., CaCl
2, KCl, and seawater) using the approximation principle. The calculated results were consistent with the experimental data. Later, the solubilities of N
2, CO
2, C
2H
6, and O
2 in pure water to aqueous NaCl solutions were calculated using this model [
27,
28,
29,
30,
31] and were also consistent with the experimental data. In conclusion, this model was widely applicable and can accurately calculate gas solubility in pure water and was easily employed in multiple ionic systems. Herein, we establish H
2 solubility models for the H
2 + H
2O system and the H
2 + H
2O + NaCl system, as well as for other ionized water systems that are applicable to a wide range of temperatures, pressures, and salinities. The gas-phase chemical potential of hydrogen was computed using the equation of state proposed by Peng and Robinson [
32], whereas the liquid-phase chemical potential of hydrogen was defined using the theory of liquid electrolyte solutions proposed by Pitzer [
33]. The relevant parameters of this model were fitted to as many experimental data as possible. During comparison with experimental data, the model achieved high accuracy, thus providing a foundation for related marine geochemistry research.
2. H2 Solubility Model
H
2 solubility in aqueous solutions was determined based on the balance between the chemical potentials of H
2 in the liquid and vapor phases. The potential can be expressed in terms of fugacity in the vapor phase (Equation (1)) and activity in the liquid phase (Equation (2)):
where
and
represent the standard chemical potentials of H
2 in liquid and vapor phases, respectively. Here,
denotes the chemical potential in a hypothetical ideal solution of unit molality [
34], and
denotes the chemical potential when the pressure of a hypothetical ideal gas is set to 1 bar.
At phase equilibrium
, subsequently, we obtain Equation (3).
In parameterization, reference value
can be set to 0 for convenience as only the difference between
and
is important. Since the vapor phase has low water content, the fugacity coefficient of H
2 in gaseous mixtures is approximate to that of pure H
2 in the studied region. Therefore,
can be approximated from the equation of state of pure H
2 (refer to
Appendix A) [
32]. The mole fraction
. of H
2 in the gas is calculated as follows.
If the partial pressure
of water in the vapor phase is approximated as the saturated pressure of pure water [
26,
28,
29,
30,
31],
and
will contain errors of up to 5%. However, these errors can be largely canceled by parameterization. Herein, the mole fraction
of water in the vapor phase is estimated using the following semiempirical equation:
where
represents the mole fraction of H
2O in the liquid phase, which is approximated as 1 and 1–2
in the H
2 + H
2O and H
2 + H
2O + NaCl systems, respectively, when dissolved hydrogen is neglected. The saturation pressure
(in bar) of water was calculated using an empirical equation (refer to
Appendix B). The molar volume
of water in the liquid phase was approximated to the saturated liquid-phase volume of water and was calculated using the equation proposed by Sun et al. [
35]. The fugacity coefficient
of water was calculated using the following equation, which is obtained by fitting the methane–water experimental data [
30].
The values of
are listed in
Table 1. The water content in the vapor phase can be calculated accurately using Equations (5) and (6). The results for different temperatures are plotted in
Figure 1.
is expressed as a virial expansion of excess Gibbs energy [
33]:
where
and
represent the second-order and third-order interaction parameters, respectively. The subscripts
c and
a denote cations and anions, respectively. Substituting Equation (7) into Equation (3) yields the following.
Following Pitzer et al. [
36], we selected the following equation for the
T–
P dependences of
,
, and
.
The basis of our model parameterization consists of Equations (8) and (9).