Induction Time Of Hydrate Formation Research Articles

Thermodynamic and Kinetic Promoters for Gas Hydrate Technological Applications

In recent years, there has been growing interest in gas hydrates as technological applications, such as for energy (methane and hydrogen) storage and transportation, separation (gas and desalination), and carbon capture. However, there are several challenges that deter large-scale applications and commercialization of these hydrate-based technologies. One of the main challenges is the long induction time and slow growth of hydrate particles, which can increase the overall operating costs of these technologies. It has been reported that the addition of additives (known as hydrate promoters) can help improve the nucleation and growth rate of hydrates. In general, there are two types of hydrate promoters: thermodynamic hydrate promoters and kinetic hydrate promoters. Thermodynamic hydrate promoters shift the hydrate equilibrium curve to milder conditions (i.e., lower pressures and higher temperatures), while kinetic hydrate promoters reduce the induction time for hydrate formation and increase the growth rate. In this review, we provide a comprehensive review of the two types of hydrate promoters (thermodynamic and kinetic) and their effects on hydrate phase equilibria, induction time, and growth rate.

Investigation on Hydrate Formation and Growth Characteristics in Dissolved Asphaltene-Containing Water-In-Oil Emulsion.

Clarifying the effect of asphaltene on hydrate formation and growth is of great significance to the operation safety in deepwater petroleum fields. To investigate the influence of low-concentration dissolved asphaltenes on the formation kinetics and growth process of hydrates in water-in-oil emulsions, experiments with asphaltene concentrations ranging from 50 to 1000 ppm were carried out using a high-pressure visual reactor. At a low concentration, the adsorption of asphaltene monomers on the oil-water interface or nanoaggregates in the bulk barely affected the nucleation of hydrate and the induction time of hydrate formation. However, it would hinder the microscopic mass transfer process and heat transfer process between gas molecules and then mitigate the initial rate of hydrate formation. Therefore, the dissolved asphaltenes could not be used as antiagglomerants (AAs) to efficiently inhibit the aggregation of hydrate particles at low concentrations under our experimental conditions, causing extensive hydrate agglomeration and deposition in the reactor.

An Experimental Study on the Formation of Natural Gas Hydrate With Thermodynamic Inhibitors

Gas hydrates formed in the conditions of high pressure and low temperature in deep sea and in the process of oil and gas transportation, natural gas hydrate (NGH), will seriously affect the safety of drilling and completion operations and marine equipment and threaten the safety of drilling platform. How to prevent the hydrate formation in the process of oil and gas production and transportation has become an urgent problem for the oil and gas industry. For this reason, in view of the formation of NGH in the process of drilling and producing marine NGH, the phase equilibrium calculation research of NGH formation was carried out, the mathematical model of gas hydrate formation phase equilibrium condition was established, and the experimental research on NGH formation was carried out through adding different thermodynamic inhibitors. The experimental phenomena show that, first, the stirring speed has little effect on the inhibition of hydrate formation. Second, when the pressure is 10 MPa and the volume concentration of inhibitor is 1, 3, 5, and 7%, the supercooling degree of hydrate formation is 1.81, 8.89, 11.09, and 9.39°C, respectively. Third, when the volume concentration of inhibitor is 1, 3, 5, and 7%, the induction time of hydrate formation is 10328, 14231, 19576, and 24900 s, respectively. As the polymer molecules in the inhibitor reduce the activity of water in the system and fill the cavity structure of the hydrate, they reduce the generation conditions of NGH and break the original phase equilibrium conditions when NGH is generated, thus forming NGH at a lower temperature or higher pressure.

Organics-Coated Nanoclays Further Promote Hydrate Formation Kinetics.

A deeper understanding of the kinetics of CO2 hydrate formation in the complicated natural environment is required for its enhanced sequestration. Here we found that the organics-coated nanoclays enriched in the natural sediments could contribute to a 92% decline of the induction time of hydrate formation. This can be ascribed to the negative charges carried by the organics and the resulting ordered arrangement of the surrounding water molecules. It was, for the first time, proposed that the abundant functional groups from the coating organics could function as a protecting crust enabling the system more resistant to the acidification potentially upon the CO2 sequestration; besides, the negative charges could help prevent the deposition of the nanoclays via interparticle repulsive forces. These would consequently secure their sustainable promoting effect on hydrate formation. The findings suggest the deposits of gas hydrate a kinetically promising geological setting for the CO2 sequestration via forming hydrates.

Insights into kinetic inhibition effects of MEG, PVP, and L-tyrosine aqueous solutions on natural gas hydrate formation

It is necessary to understand all the prerequisites, which result in gas hydrate formation for safe design and control of a variety of processes in petroleum industry. Thermodynamic hydrate inhibitors (THIs) are normally used to preclude gas hydrate formation by shifting hydrate stability region to lower temperatures and higher pressures. Sometimes, it is difficult to avoid hydrate formation and hydrates will form anyway. In this situation, kinetic hydrate inhibitors (KHIs) can be used to postpone formation of gas hydrates by retarding hydrate nucleation and growth rate. In this study, two kinetic parameters including natural gas hydrate formation induction time and the rate of gas consumption were experimentally investigated in the presence of monoethylene glycol (MEG), L-tyrosine, and polyvinylpyrrolidone (PVP) at various concentrations in aqueous solutions. Since hydrate formation is a stochastic phenomenon, the repeatability of each kinetic parameter was evaluated several times and the average values for the hydrate formation induction times and the rates of gas consumption are reported. The results indicate that from the view point of hydrate formation induction time, 2 wt% PVP and 20 wt% MEG aqueous solutions have the highest values and are the best choices. It is also interpreted from the results that from the view point of the rate of gas consumption, 20 wt% MEG aqueous solution yields the lowest value and is the best choice. Finally, it is concluded that the combination of PVP and MEG in an aqueous solution has a simultaneous synergistic impact on natural gas hydrate formation induction time and the rate of gas consumption. Furthermore, a semi-empirical model based on chemical kinetic theory is applied to evaluate the hydrate formation induction time data. A good agreement between the experimental and calculated hydrate formation induction time data is observed.

Effect of a weak electric field on THF hydrate formation: Induction time and morphology

The kinetics of bulk hydrate formation is of crucial importance in the application of hydrate-based technique involving energy storage, desalination and flow assurance. Various procedures have been found to significantly impact the kinetics of hydrate formation; yet with few studies touching the effects of a weak electric field. A voltage across the solution could likely affect the activity and orientation of the molecules inside, thereby playing a potential role in the hydrate nucleation, crystal growth and even diffusion of water and guest molecules. In this study, the effect of a weak electric field on the induction time, bulk surface characteristics and growth rate of THF (tetrahydrofuran) hydrate were investigated by controlling the voltage across the two electrodes placed on the two sides of the reactor. The results showed that an increasing voltage intensity could result in a longer induction time of hydrate formation. The memory effect was fading at an increasing voltage intensity, indicating that the relic components helping the fast formation could be destroyed by the electric field. The following formation under the electric field can be identified by a neat zigzag surface of hydrate generated from the periphery of the reactor. The formation rate of THF hydrate was found to increase with a rising voltage intensity during the hydrate growth period. The results could be of help in the application of hydrate-based techniques in industries where a fast and successive hydrate growth is expected.

A comparison of kinetics and thermodynamics of methane hydrate formation & dissociation in surfactant and solid dispersed emulsion

In the process of pipeline transportation, due to the internal high pressure and low temperature environment, hydrate particles tend to agglomerate and lead to blockage. The interfacial structure of Pickering emulsion can inhibit the combination of particles. Therefore, the formation and dissociation of hydrate in emulsion dispersed by surfactant and solid were studied. In addition, the pressure temperature equilibrium behavior of the reaction process has been studied extensively. Furthermore, the mechanism of interfacial interaction between the two in emulsion was also studied. The concentrations of Tween 20 and Cellulose Nanocrystals(CNCs) are 0.1░wt%, 0.3░wt% and 1░wt%. Compared with Tween 20, the presence of CNCs prolonged the induction time of hydrate formation and increased the final residual pressure in the formation stage. At the same time, the results show that the amount of methane needed for hydrate formation in CNCs is higher. After studying the decomposition enthalpy, it was found that as the concentration increases, T20░system moves towards low pressure and high temperature. However, due to the high viscosity of CNC system, the heat absorbed by hydrate is difficult to overflow, which shows that it moves towards high pressure and low temperature. Further the formation mechanism of hydrate and the molar consumption of methane gas were studied.

Experimental study and kinetic modeling of R410a hydrate formation in presence of SDS, tween 20, and graphene oxide nanosheets with application in cold storage

Abstract Gas hydrates, or clathrate hydrates, can be used as a suitable cold/cool storage media, due to their large phase change enthalpy. In recent decades, cold production through gas hydrates as a novel and cost-effective method has motivated researchers. Refrigerants have the potential to be used in hydrate-based cold storage systems, because they can form hydrates at moderate pressures and temperatures. Hence, in this work, the kinetics of R410a (50 wt% difluoromethane + 50 wt% 1,1,1,2,2-pentafluoroethane) hydrate formation in the presence of different concentrations of SDS, tween 20, and graphene oxide (GO) was investigated. The experiments were carried out in a 300 cm3 reactor/cell at the initial pressure and temperature of 1 MPa and 279.65 K, respectively. According to the results, at all concentrations of the additives, except tween 20 at a concentration of 1000 ppm, the hydrate formation induction time decreases, compared to pure water. Furthermore, the promotion effects of SDS and GO on the quantity and rate of gas uptake, and the apparent rate constant were observed at the initial minutes of the hydrate growth process. The measured storage capacity and water to hydrate conversion show that the used additives do not change the abovementioned parameters, noticeably.

Hydrate formation in oil–water systems: Investigations of the influences of water cut and anti-agglomerant

To investigate the characteristics of hydrate formation in oil–water systems, a high-pressure cell equipped with visual windows was used where a series of hydrate formation experiments were performed from natural gas + diesel oil + water systems at different water cuts and anti-agglomerant concentrations. According to the temperature and pressure profiles in test experiments, the processes of hydrate formation under two kinds of experimental procedures were analyzed first. Then, based on the experimental phenomena observed through the visual windows, the influences of water cut and anti-agglomerant on the places of hydrate formation and distribution, hydrate morphologies and hydrate morphological evolvements were investigated. Hydrate agglomeration, hydrate deposition and hydrate film growth on the wall were observed in experiments. Furthermore, three different mechanisms for hydrate film growth on the wall were identified. In addition, the influences of water cut and anti-agglomerant on the induction time of hydrate formation were also studied.

Study on the Optimization of Hydrate Management Strategies in Deepwater Gas Well Testing Operations

Abstract Low temperature and high pressure conditions favor the formation of gas clathrate hydrates which is undesirable during oil and gas industries operation. The management of hydrate formation and plugging risk is essential for the flow assurance in the oil and gas production. This study aims to show how hydrate management in the deepwater gas well testing operations in the South China Sea can be optimized. To prevent the plugging of hydrate, three hydrate management strategies are investigated. The first method, injecting thermodynamic hydrate inhibitor (THI) is the most commonly used method to prevent hydrate formation. THI tracking is utilized to obtain the distribution of mono ethylene glycol (MEG) along the pipeline. The optimal dosage of MEG is calculated through further analysis. The second method, hydrate slurry flow technology is applied to the gas well. Pressure drop ratio (PDR) is defined to denote the hydrate blockage risk margin. The third method is the kinetic hydrate inhibitor (KHI) injection. The delayed effect of KHI on the hydrate formation induction time ensures that hydrates do not form in the pipe. This method is effective in reducing the injection amount of inhibitor. The problems of the three hydrate management strategies which should be paid attention to in industrial application are analyzed. This work promotes the understanding of hydrate management strategies and provides guidance for hydrate management optimization in oil and gas industry.

Benefits of Low-Dosage Hydrate Inhibitors

This article, written by JPT Technology Editor Chris Carpenter, contains highlights of paper OTC 28905, “Advances in LHDIs and Applications,” by Y.D. Chin and A. Srivastava, Subsea Engineering Technologies, prepared for the 2018 Offshore Technology Conference, Houston, 30 April–3 May. The paper has not been peer reviewed. Copyright 2018 Offshore Technology Conference. Reproduced by permission. This paper summarizes historical advancements in low-dosage hydrate inhibitors (LDHIs) over the past 2 decades, discusses their advantages and limitations, and their selection criteria. Historically, hydrate risk has been managed by keeping fluids warm, removing water, or injecting thermodynamic hydrate inhibitors (THIs), commonly methanol (MeOH) or monoethylene glycol (MEG). THIs require high dosage rates; therefore, that technique can pose limitations to production systems in the form of supply, storage, and umbilical-injection constraints. Additionally, high dosages of MeOH can cause crude contamination for downstream refineries. LDHIs continue to offer significant efficiency and cost benefits over other techniques. Introduction THIs have long been used by the industry because of their ability to shift the hydrate-equilibrium curve toward higher pressures and lower temperatures by changing the activity of water molecules. MeOH and MEG have proved the most popular types of THI because of their low cost and widespread availability. Though THIs are low-cost, the volume requirement per barrel offsets the cost benefit. A group of chemicals developed later, LDHIs, differ from THIs because they do not shift the hydrate curve; rather, they interfere with the process of hydrate formation through different mechanisms. The dosage requirement of these inhibitors is much lower than that required for THIs. LDHIs include two categories, kinetic hydrate inhibitors (KHIs) and antiagglomerants (AAs). KHIs increase the induction time for hydrate formation by interfering with the nucleation process or the crystal-growth process. Special surfactants disperse hydrate particles as they form, reducing the tendency of hydrates to stick to the pipe’s inner surface, reducing the chance of plug formation. AAs modify the agglomeration of hydrate particles, decreasing hydrate-crystal size by affecting hydrate morphology. This leads to a hydrate slurry flow, which decreases the chance of pipeline blockage. Inhibition mechanisms of both KHIs and AAs are discussed in detail in the complete paper, as is the historical development of these LDHIs. LDHI Applications Performance Parameters. The two primary parameters for LDHI performance measurement include the following: Hold Time. This is defined as the time between when a rapidly cooled fluid is at a constant temperature below the hydrate-equilibrium temperature and when hydrates first appear. For KHIs, the hold time decreases steeply with the increase in subcooling. Dosage Rates. To establish actual dosage rates for a LDHI in a specific fluid, technical-feasibility testing would be required with the actual LDHI and fluid under actual pressure and temperature conditions. An approximate range of expected LDHI dosage rates can be given as examples as follows. Gas System. For a gas system operating with condensed water, the dosage-rate guideline is 5 gal LDHI/bbl of condensed water. Breakthrough of formation water with a saline content of at least 3 wt% would reduce the rate to between 0.5 and 1.0 gal LDHI/bbl of formation water, although it should be recognized that this would be a different LDHI from the one used with condensed water.

Experimental study on the correlation between rapid formation of gas hydrate and diffusion of guest molecules

The major technical issues in the energy and gas storage systems through gas hydrates include shortening the induction time for rapid hydrate formation, and increasing the quantity with simple and economical methods. The Normal temperature-Snap cold Model (NSM) has advantage on the amount of gas hydrates formation within a given time compared to that in the Low-temperature Subcooling Model (LSM). With the subcooling temperature range of 1.0–3.0 °C, a series of experiments based on HCFC-141b (R141b) aqueous solution with 0.25 (wt%) mass % of Sodium Dodecyl Sulfate (SDS) and 800r/min (rpm) agitation are carried out under the conditions of NSM and LSM. The time-temperature diagrams obtained during hydrate formation reveal that though the induction time for hydrate formation increases with temperature increasing under both conditions, the formation rate of hydrate shows an opposite trend with temperature. Furthermore, experiments on electrical conductivity and microstructure under NSM condition show that the uniformity of R141b droplets in aqueous solution decreases remarkably as time increases, and the hydrate formation first occurs at 1.0 °C when uniformity is relatively high.

Study of different models of prediction of the simple gas hydrates formation induction time and effect of different equations of state on them

Gas hydrates are crystals, similar to ice. In these crystals, no chemical bond is created between the water molecules (host) and the trapped gas molecules (guest). Gas hydrates are generally encountered in gas transportation pipelines and the industries related to natural gas. Gas hydrates block the path of transmission pipelines and process equipment, which in turn result in partial damage or destruction of the pipeline. For preventing these events, it is necessary and vital to predict the hydrate induction time. To tackle this important issue, this research aims at predicting different models of induction time for hydrate formation of simple gases. Moreover in the current study, these models are evaluated and compared based on the available experimental data in the literature. Additionally, the influence of different equations of state on the aforementioned models are investigated. The models of Natarajan et al., modified Natarajan, Kashchiev and Firoozabadi and Rasoulzadeh and Javanmardi were utilized to predict the induction time of hydrate formation of simple gases including methane and ethane. The results revealed that the models by Rasoulzadeh and Javanmardi, and modified Natarajan yielded the most accurate results. Furthermore, the results showed that various equations of states resulted in similar results, therefore, specified equation of state does not have a great influence on predicting the induction time of hydrate formation.

Study of Selected Factors Influencing Carbon Dioxide Separation from Simulated Biogas by Hydrate Formation

CH4 concentration and CO2 separation from biogas (CH4/CO2) by an one-stage hydrate formation was supposed to be a prospective and economical practicable technology compared with traditional gas separation methods. We investigated the influence of 1-butyl-3-methylimidazolium hexafluorophosphate ([BMIM] PF6) on simulated biogas (64.0 mol %CH4/CO2) hydrate separation in this work. The thermodynamic promoter TBAB was combined with [BMIM] PF6 to investigate binary gas hydrate formation and separation efficiency. Different parameters which affected hydrate formation were investigated. The concentration of [BMIM] PF6 was 1000/2000/3000 ppm, and the optimized concentration of TBAB was 4 wt %. With respect to the hydrate gas separation results, the addition of TBAB can decrease CH4/CO2 hydrate formation pressure greatly and the hydrate formation induction time. CH4 in the remaining gas can be increased from 64.0 to 79.90 mol %, and CH4 recovery can arrive at 95.83%. Meanwhile, the addition of [BMIM] PF6 could increase the CO2 mole friction in hydrate from 36.0 to 58.63 mol %. So it was demonstrated that the combination of TBAB + [BMIM] PF6 would have a great application prospect on biogas purification technology.

State of the art and kinetics of refrigerant hydrate formation

This study aims to introduce suitable hydrate forming-refrigerants well-suited for air-conditioning systems through a kinetic study. The formation of clathrate hydrates is a time-consuming process. Hence, in an air-conditioning system, which uses refrigerant hydrate as a media for storage of cold energy, the knowledge of the hydrate formation rate, is crucial. In this experimental study, the rate of hydrate formation of four refrigerant blends, including R404A, R406A, R408A and R427A have been investigated. The induction time for hydrate formation, apparent rate constant of the hydrate reaction, water to hydrate conversion during hydrate growth, storage capacity, and the rate of hydrate formation of these refrigerants at various pressures and temperatures have been obtained using a kinetic model. The effect of sodium dodecyl sulfate (SDS) on the hydrate nucleation rate was also investigated. This study also aims to prepare a review on gas hydrates applications and characteristics in the power generation systems and cold storage applications including air conditioning systems. The advantages and disadvantages of this compound over traditional storage media and phase change materials (PCMs) including water, ice, salt hydrates, eutectic salts, paraffin waxes and fatty acids, slurries and phase changed emulsions have been reviewed.

INFLUENCE OF THE TIME STORAGE OF ICE POWDER ON KINETICS OF FORMATION AND GROWTH OF FREON-12 GAS HYDRATE

The article explores the influence a storage time on the samples of pure ice powder and mod-ified ice powder with polyvinylpyrrolidone on process formation and growth of the gas hydrate by used P-V-T measurements. It has been established that increased storage time of the pure ice powder leads to a decrease the rate of growth of gas hydrate. Fresh modified ice powder has induction time of hydrate formation which increased in a polyvinylpyrrolidone concentration. At long-term storage of modified ice powder with a polyvinylpyrrolidone concentration less 0,3 % the induction time don’t registrate and growth rate of gas hydrate likes zero. In the samples of modified ice powder with a polyvinylpyrrolidone concentration more 0,75 % after 10 days a storage were retained growth rate of gas hydrate likes fresh modified ice powder. There is no induction effect.

Experimental Analysis on the Probability Density Distribution of Methane Hydrate Induction Times in Porous Media

AbstractHydrate‐based natural‐gas transport and storage have been proposed and developed because of the high safety and low cost, and hydrate reformation is a serious barrier for high‐efficiency natural‐gas hydrate exploitation. The hydrate formation induction time is a crucial kinetic parameter for both of the two fields. To clarify the hydrate formation and/or reformation induction characteristics, the effects of sub‐cooling, particle size, initial water saturation and memory effect on the stochastic induction time patterns are experimentally investigated. In total, 22 cases were performed, and each case was repeated in 20–30 runs under identical conditions. The experimental results show that the distribution of CH4 hydrate induction times can be properly fitted to a lognormal distribution function. Larger sub‐cooling leads to shorter induction time and more repeatable experimental results. It is also found that shorter induction time and repeatable results can be obtained with bigger particle size. The experimental results show that 70% water saturation can be considered a critical value for hydrate formation. Memory effect of water is existed in the experiments, which can help reducing the induction time and its stochastic nature. It can be considered that the memory effect on the induction time is dominant compared with the other factors (sub‐cooling, particle size and initial water saturation).

Effect of hydrophilic silica nanoparticles on hydrate formation: Insight from the experimental study

Abstract Invasion of drilling fluid into natural gas hydrate deposits during drilling might damage the reservoir, induce hydrate dissociation and then cause wellbore instability and distortion of the data from well logging. Adding nanoparticles into drilling fluid is an effective method in reducing the invasion of drilling fluid and enhancing borehole stability. However, the addition of nanoparticles might also introduce hydrate formation risk in borehole because they can act as the “seeds” for hydrate nucleation. This paper presents an experimental study of the effect of hydrophilic silica nanoparticle on gas hydrate formation in a dynamic methane/liquid-water system. In the experiment, the ultrapure water with and without 1.0 wt%–6.0 wt% concentrations of silica nanoparticles, grain sizes of 20 and 50 nm, were pressurized by methane gas under varied conditions of temperature and pressure. The induction time, the gas consumption, and the average rate of gas consumption in the system were measured and compared to those in ultrapure water. The results show that a concentration of 4.0 wt% hydrophilic SiO2 particles with a grain size of 50 nm has a relatively strong inhibition effect on hydrate formation when the initial experimental condition is 5.0 °C and 5.0 MPa. Compared to ultrapure water, the hydrophilic nano-SiO2 fluid increases the induction time for hydrate formation by 194% and decreases the amount and average rate of hydrate formation by 10% and 17%, respectively. This inhibition effect may be attributed to the hydrophilicity, amount and aggregation of silica nanoparticle according to the results of water activity and zeta potential measurements. Our work also elucidates hydrophilic, instead of hydrophobic, nanoparticles can be added to the drilling fluid to maintain wellbore stability and to protect the hydrate reservoir from drilling mud damage, because they exhibit certain degree of hydrate inhibition which can reduce the risk of hydrate reformation and aggregation during gas hydrate or deep water drilling if their concentration can be controlled properly.

Prediction of induction time for methane hydrate formation in the presence or absence of THF in flow loop system by Natarajan model

The induction time is a time interval to detect the initial hydrate formation, which is counted from the moment when the stirrer is turned on until the first detection of hydrate formation. The main objective of the present work is to predict and measure the induction time of methane hydrate formation in the presence or absence of tetrahydrofuran (THF) as promoter in the flow loop system. A laboratory flow mini-loop apparatus was set up to measure the induction time of methane hydrate formation. The induction time is predicted using developed Kashchiev and Firoozabadi model and modified model of Natarajan for a flow loop system. Furthermore, the effects of volumetric flow rate of the fluid on the induction time were investigated. The results of the models were compared with experimental data. They show that the induction time of hydrate formation in the presence of THF is very short at high pressure and high volumetric flow rate of the fluid. It decreases with increasing pressure and liquid volumetric flow rate. It is also shown that the modified Natarajan model is more accurate than the Kashchiev and Firoozabadi ones in prediction of the induction time.

Thermodynamics and kinetics of methane hydrate formation and dissociation in presence of calcium carbonate

Huge amount of gas hydrate deposits are identified in deep marine sediments, which may be considered as a future source of energy. Since carbonate is one of the major components of marine sediments, in the present study attention has been given to characterize methane hydrate formation and dissociation in presence of calcium carbonate. Experiments were performed with 0%, 2%, 4%, 6% and 10% by weight of calcium carbonate in distilled water. Extensive investigations have been done on pressure-temperature equilibrium behavior of hydrate formation and dissociation at varying concentrations of calcium carbonate. Hydrate formation rate was found to vary with concentration of calcium carbonate as the solubility of calcium carbonate in water is controlled by the presence of simultaneous chemical equilibria involving a high number of species like Ca2+, CO32−, HCO3−, CO2, etc. Induction time for hydrate formation has also been measured at different concentrations of carbonate. Nucleation point for the hydrate formation was observed to be slightly higher at higher concentration of calcium carbonate due to increased heat absorption. Dissociation enthalpy of hydrates was calculated by using Clausius-Clapeyron at different measured conditions. Moles consumption of methane gas during hydrate formation at different concentrations of carbonate was measured using real gas equation and found to be minimum at 10 wt%.