Towards zero carbon dioxide concentration in sweet natural gas product from amine sweetening plant

Abstract This work presents a two-step method to reduce CO2 concentration of sweet natural gas product from amine sweetening plant via amine blending (Step 1) followed by minor process modification (Step 2). In Step 1, an industrial natural gas sweetening plant was simulated using Aspen HYSYS and the simulation results were validated against the plant data. Afterwards, different blends of methyl diethanolamine and monoethanolamine (MDEA-MEA) and methyl diethanolamine and diethanolamine (MDEA-DEA) were investigated. Then the optimum amine blend of 28 wt.% MDEA and 10 wt.% MEA was reported. The optimum amine blend achieved a significant reduction in CO2 concentration of sweet natural gas of 99.9% compared to the base case (plant data). In Step 2, two types of amine stream splits, i.e., lean amine stream split and semi-lean amine stream split were studied. The study covered split stream amount, absorber recycle stage, and regenerator stage withdrawal. Both types of stream splits attained a significant reduction in CO2 concentration of sweet natural gas product and amine circulation rate compared to Step 1. However, the semi-lean amine stream split was superior to lean amine split with 69.1% and 63.6% reduction in CO2 concentration of sweet natural gas and lean amine circulation rate, respectively.

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Single-Solution-Based Vortex Search Strategy for Optimal Design of Offshore and Onshore Natural Gas Liquefaction Processes

Energies ◽

10.3390/en13071732 ◽

2020 ◽

Vol 13 (7) ◽

pp. 1732 ◽

Cited By ~ 5

Author(s):

Muhammad Abdul Qyyum ◽

Muhammad Yasin ◽

Alam Nawaz ◽

Tianbiao He ◽

Wahid Ali ◽

...

Keyword(s):

Energy Efficiency ◽

Energy Consumption ◽

Optimal Design ◽

Natural Gas ◽

Point Of View ◽

Base Case ◽

Aspen Hysys ◽

Design Variables ◽

Single Solution ◽

Natural Gas Liquefaction

Propane-Precooled Mixed Refrigerant (C3MR) and Single Mixed Refrigerant (SMR) processes are considered as optimal choices for onshore and offshore natural gas liquefaction, respectively. However, from thermodynamics point of view, these processes are still far away from their maximum achievable energy efficiency due to nonoptimal execution of the design variables. Therefore, Liquefied Natural Gas (LNG) production is considered as one of the energy-intensive cryogenic industries. In this context, this study examines a single-solution-based Vortex Search (VS) approach to find the optimal design variables corresponding to minimal energy consumption for LNG processes, i.e., C3MR and SMR. The LNG processes are simulated using Aspen Hysys and then linked with VS algorithm, which is coded in MATLAB. The results indicated that the SMR process is a potential process for offshore sites that can liquefy natural gas with 16.1% less energy consumption compared with the published base case. Whereas, for onshore LNG production, the energy consumption for the C3MR process is reduced up to 27.8% when compared with the previously published base case. The optimal designs of the SMR and C3MR processes are also found via distinctive well-established optimization approaches (i.e., genetic algorithm and particle swarm optimization) and their performance is compared with that of the VS methodology. The authors believe this work will greatly help the process engineers overcome the challenges relating to the energy efficiency of LNG industry, as well as other mixed refrigerant-based cryogenic processes.

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Sensitivity analysis and optimization of the utility consumption of natural gas liquids (NGLs) process in the Siri Island Gas

Chemical Product and Process Modeling ◽

10.1515/cppm-2020-0042 ◽

2020 ◽

Vol 0 (0) ◽

Author(s):

Nilufar Kharaghani ◽

Marzyeh Lotfi ◽

Mani Safamirzaei ◽

Niloufar Fatourehchi

Keyword(s):

Sensitivity Analysis ◽

Economic Evaluation ◽

Heat Exchanger ◽

Natural Gas ◽

Gas Separation ◽

Feed Stream ◽

Aspen Hysys ◽

Simulation Results ◽

Feed Tray ◽

Propane Butane

AbstractIn this study, the simulation of the natural gas liquids (NGLs) of Siri Island unit was carried out using Aspen Hysys software. Energy and economic evaluation of these towers were evaluated with Aspen Energy Analyses and Aspen Economic Evaluation, respectively. The effect of various parameters such as the use of heat exchanger instead of a cooler, feed tray changes and the mixing of two feed streams together were investigated to increase the efficiency of hydrocarbons - (Ethane, Propane, Butane, and Pentane) separation, utility consumption and costs. The simulation results showed that the input feed stream from the 10-tray using - mixing of two input 207 and 208 streams, which improves the efficiency of hydrocarbons gas separation and utility consumption compared to other parameters.

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Simulation and Optimization of the Utilization of Triethylene Glycol in a Natural Gas Dehydration Process

Chemical Product and Process Modeling ◽

10.1515/cppm-2017-0017 ◽

2017 ◽

Vol 12 (4) ◽

Cited By ~ 1

Author(s):

Zykamilia Kamin ◽

Awang Bono ◽

Lek Yan Leong

Keyword(s):

Natural Gas ◽

Water Concentration ◽

Triethylene Glycol ◽

Circulation Rate ◽

Processing Plant ◽

Dehydration Process ◽

Simulation And Optimization ◽

Aspen Hysys ◽

Natural Gas Dehydration ◽

Formation Of Hydrates

AbstractThe dehydration unit of a plant that processes natural gas uses triethylene glycol (TEG) as an absorbent to remove water from the gas to prevent blockages in pipes due to the formation of hydrates. Although TEG is recyclable, it is usually lost in the system due to vaporization and carryover, which results in economic issues. Therefore, it is necessary to optimize the dehydration process to achieve the allowable water concentration in the gas, to minimize the use of energy, and to minimize the loss of TEG. Experimental set was designed using Design Expert software by utilising data from Farashband gas processing plant, Iran and subsequently, fed to ASPEN HYSYS to construct and simulate the dehydration process. The chosen affecting parameters to the process were the (1) lean glycol circulation rate, (2) the temperature of the reboiler, and (3) the number of trays in the contactor column. Whereas, the response parameters included the (1) amount of glycol that was lost, (2) the reboiler duty, (3) the concentration of water in the dry gas, and the (4) temperature at which the hydrate formed. Then, these data were optimized using the response surface methodology (RSM). The results indicated that the optimum conditions within the experimental range conducted in this study of process parameters chosen, of the lean glycol circulation rate, the temperature of the reboiler, and the number of trays in the glycol contactor column for the gas dehydration process for the plant were 3944 kg/hr, 180 °C, and three trays, respectively.

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Carbon Dioxide Capturing from Natural Gas using Di-glycol Amine and Piperazine – A New Solvent Mixture

International Journal of Recent Technology and Engineering - 2 ◽

10.35940/ijrte.d4221.118419 ◽

2019 ◽

Vol 8 (4) ◽

pp. 11378-11383

Keyword(s):

Carbon Dioxide ◽

Natural Gas ◽

Solvent Mixture ◽

Absorption Efficiency ◽

Circulation Rate ◽

Gas Temperature ◽

Aspen Hysys ◽

Temperature Ranges ◽

Co2 Level

The effect of adding Piperazine to di-glycol amine (DGA) to reduce the CO2 content in natural gas from 10% to 1% by mole was studied. Aspen HYSYS was used to simulate the process. Different concentrations of DGA (45, 50 and 55%) and Piperazine (3, 5, 7, 9 and 11%) were investigated. The effect of circulation rates variation from 1000 kgmol/hr. to 5000 kgmol/hr. were examined. Moreover, temperature ranges from 38 oC to 80 oC and pressure ranges from 45 kg/cm2 to 80 kg/cm2 were studied for 55% DGA without and with the addition of Piperazine. It was found that adding 9% Piperazine to 55% DGA achieved the best absorption efficiency. By using Piperazine, the circulation rate required to reach the 1% CO2 level was reduced to 3250 kgmol/hr. The amount of captured CO2 was found to increase with the decrease in the lean gas temperature and the increase in absorber pressure.

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Techno Commercial Analysis of Liquefied Petroleum Gas Recovery From Natural Gas Using Aspen HYSYS

Frontiers in Energy Research ◽

10.3389/fenrg.2021.785827 ◽

2021 ◽

Vol 9 ◽

Author(s):

Usman Ali ◽

Muhammad Zafar ◽

Ashfaq Ahmed ◽

Hafiz Kamran Zaman ◽

Abdul Razzaq ◽

...

Keyword(s):

Natural Gas ◽

Case Studies ◽

Research Work ◽

Process Efficiency ◽

Base Case ◽

Liquefied Petroleum Gas ◽

Gas Recovery ◽

Aspen Hysys ◽

Process Energy

Liquefied petroleum gas is an alternative, relatively clean and a supreme source of energy, which is being used as a key component in the global energy supply. The international trade agreements and the chemical and non-chemical demand of liquefied petroleum gas with the increase in the world’s population have brought its production from the processing of natural gas to the limelight. During its processing, a variety of different components are extracted from it, including methane and ethane which remains in the bulk as natural gas. The objective of this research work is to find the capability of investigating the liquefied petroleum gas recovery performance to make the process economical by saving the processing cost and energy. The novelty of this work is to deal with the design and simulation of a liquefied petroleum gas plant using Aspen HYSYS. To make this process energy efficient and economical, different schemes of process alternatives were applied by reducing the sizes of the exchanger and other pieces of equipment. Three cases are studied in which feed is precooled by rerouting the stream and/or by repositioning of the chiller for the recovery of liquefied petroleum gas from natural gas by analyzing their cost and process parameters. The modelling and simulation base case and three different case studies are realized in Aspen HYSYS. It has been observed that case study 2 results in about 10% increase in LPG production where the chiller is repositioned in the separation section of the LPG production flowsheet. Case study 3 shows a maximum decrease in hot side utilities in the flowsheet of about 20% while 10 and 14% decreases are observed for case studies 1 and 2, respectively. Furthermore, economic analysis indicates about 18 and 22% in the capital cost for case studies 2 and 3, respectively, due to the lower size of process units. The outcome of this investigation is to present plenty of suggestions to improve the process efficiency and minimize the requirement to over design the plant components.

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Computer simulation to evaluate the economics of landfill gas recovery

Water Science & Technology ◽

10.2166/wst.1998.0139 ◽

1998 ◽

Vol 38 (2) ◽

pp. 201-208

Author(s):

M. W. Milke

Keyword(s):

Computer Simulation ◽

Computer Program ◽

Landfill Gas ◽

Base Case ◽

Simulation Tool ◽

Hypothetical Case ◽

Gas Recovery ◽

Fixed Set ◽

Key Variables ◽

Simulation Results

A need exists for tools to improve evaluations of the economics of landfill gas recovery. A computer simulation tool is presented. It uses a spreadsheet computer program to calculate the economics for a fixed set of inputs, and a simulation program to consider variations in the inputs. The method calculates the methane generated each year, and estimates the costs and incomes associated with the recovery and sale of the gas. Base case results are presented for a city of 500,000. An uncertainty analysis for a hypothetical case is presented. The simulation results can help an analyst see the key variables affecting the economics of a project.

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A Numerical Study on the Combustion Process and Emission Characteristics of a Natural Gas-Diesel Dual-Fuel Marine Engine at Full Load

Energies ◽

10.3390/en14051342 ◽

2021 ◽

Vol 14 (5) ◽

pp. 1342

Author(s):

Van Chien Pham ◽

Jae-Hyuk Choi ◽

Beom-Seok Rho ◽

Jun-Soo Kim ◽

Kyunam Park ◽

...

Keyword(s):

Natural Gas ◽

Combustion Process ◽

Simulation Software ◽

Dual Fuel ◽

Injection Timing ◽

Emission Characteristics ◽

Cylinder Pressure ◽

Marine Engine ◽

Full Load ◽

Simulation Results

This paper presents research on the combustion and emission characteristics of a four-stroke Natural gas–Diesel dual-fuel marine engine at full load. The AVL FIRE R2018a (AVL List GmbH, Graz, Austria) simulation software was used to conduct three-dimensional simulations of the combustion process and emission formations inside the engine cylinder in both diesel and dual-fuel mode to analyze the in-cylinder pressure, temperature, and emission characteristics. The simulation results were then compared and showed a good agreement with the measured values reported in the engine’s shop test technical data. The simulation results showed reductions in the in-cylinder pressure and temperature peaks by 1.7% and 6.75%, while NO, soot, CO, and CO2 emissions were reduced up to 96%, 96%, 86%, and 15.9%, respectively, in the dual-fuel mode in comparison with the diesel mode. The results also show better and more uniform combustion at the late stage of the combustions inside the cylinder when operating the engine in the dual-fuel mode. Analyzing the emission characteristics and the engine performance when the injection timing varies shows that, operating the engine in the dual-fuel mode with an injection timing of 12 crank angle degrees before the top dead center is the best solution to reduce emissions while keeping the optimal engine power.

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Solar Integrated Anaerobic Digester: Energy Savings and Economics

Energies ◽

10.3390/en13174292 ◽

2020 ◽

Vol 13 (17) ◽

pp. 4292

Author(s):

Lidia Lombardi ◽

Barbara Mendecka ◽

Simone Fabrizi

Keyword(s):

Anaerobic Digestion ◽

Natural Gas ◽

Economic Analysis ◽

Thermal Energy ◽

Economic Feasibility ◽

Solar Thermal ◽

Base Case ◽

Economic Sustainability ◽

Solar Thermal Energy ◽

Solar Integration

Industrial anaerobic digestion requires low temperature thermal energy to heat the feedstock and maintain temperature conditions inside the reactor. In some cases, the thermal requirements are satisfied by burning part of the produced biogas in devoted boilers. However, part of the biogas can be saved by integrating thermal solar energy into the anaerobic digestion plant. We study the possibility of integrating solar thermal energy in biowaste mesophilic/thermophilic anaerobic digestion, with the aim of reducing the amount of biogas burnt for internal heating and increasing the amount of biogas, further upgraded to biomethane and injected into the natural gas grid. With respect to previously available studies that evaluated the possibility of integrating solar thermal energy in anaerobic digestion, we introduce the topic of economic sustainability by performing a preliminary and simplified economic analysis of the solar system, based only on the additional costs/revenues. The case of Italian economic incentives for biomethane injection into the natural gas grid—that are particularly favourable—is considered as reference case. The amount of saved biogas/biomethane, on an annual basis, is about 4–55% of the heat required by the gas boiler in the base case, without solar integration, depending on the different considered variables (mesophilic/thermophilic, solar field area, storage time, latitude, type of collector). Results of the economic analysis show that the economic sustainability can be reached only for some of the analysed conditions, using the less expensive collector, even if its efficiency allows lower biomethane savings. Future reduction of solar collector costs might improve the economic feasibility. However, when the payback time is calculated, excluding the Italian incentives and considering selling the biomethane at the natural gas price, its value is always higher than 10 years. Therefore, incentives mechanism is of great importance to support the economic sustainability of solar integration in biowaste anaerobic digestion producing biomethane.

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COMPARISON OF GAZKONDNAFTA AND HYSYS SOFTWARE SYSTEMS IN THE FIELD OF COMPUTER MODELING OF OIL AND GAS TECHNOLOGIES

Energy Technologies & Resource Saving ◽

10.33070/etars.3.2021.01 ◽

2021 ◽

pp. 4-22

Author(s):

O.V. Kalashnikov ◽

S.V. Budniak ◽

Yu.V. Ivanov ◽

Yu.M. Belyansky ◽

N.O. Aptulina ◽

...

Keyword(s):

Natural Gas ◽

Thermodynamic Properties ◽

Aqueous Solutions ◽

Computer Modeling ◽

Oil And Gas ◽

Software Systems ◽

Program System ◽

Aspen Hysys ◽

Treatment Processes ◽

Liquid Phases

The experimental and calculated according to program systems GasCondOil, Aspen-HYSYS and PRO-II compositions of the gas — liquid phases (hydrocarbon and aqueous solutions) and their thermodynamic properties are compared, as well as the accuracy of technological calculations of field pipelines and natural gas and oil treatment processes. It is shown that some of the field technological processes, calculated by the program system GasCondOil, are not modeled on Aspen-HYSYS. Bibl. 16, Fig. 9, Tab. 15.

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Modeling Condensate Banking Mitigation by Enhanced Gas Recovery Methods

10.2523/iptc-21491-ms ◽

2021 ◽

Author(s):

Adel Mohsin ◽

Abdul Salam Abd ◽

Ahmad Abushaikha

Keyword(s):

Natural Gas ◽

Finite Difference ◽

Positive Impact ◽

Enhanced Recovery ◽

Gas Production ◽

Dew Point ◽

Productivity Index ◽

Base Case ◽

Enhanced Gas Recovery ◽

Gas Recovery

Abstract Condensate banking in natural gas reservoirs can hinder the productivity of production wells dramatically due to the multiphase flow behaviour around the wellbore. This phenomenon takes place when the reservoir pressure drops below the dew point pressure. In this work, we model this occurrence and investigate how the injection of CO2 can enhance the well productivity using novel discretization and linearization schemes such as mimetic finite difference and operator-based linearization from an in-house built compositional reservoir simulator. The injection of CO2 as an enhanced recovery technique is chosen to assess its value as a potential remedy to reduce carbon emissions associated with natural gas production. First, we model a base case with a single producer where we show the deposition of condensate banking around the well and the decline of pressure and production with time. In another case, we inject CO2 into the reservoir as an enhanced gas recovery mechanism. In both cases, we use fully tensor permeability and unstructured tetrahedral grids using mimetic finite difference (MFD) method. The results of the simulation show that the gas and condensate production rates drop after a certain production plateau, specifically the drop in the condensate rate by up to 46%. The introduction of a CO2 injector yields a positive impact on the productivity and pressure decline of the well, delaying the plateau by up to 1.5 years. It also improves the productivity index by above 35% on both the gas and condensate performance, thus reducing production rate loss on both gas and condensate by over 8% and the pressure, while in terms of pressure and drawdown, an improvement of 2.9 to 19.6% is observed per year.

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