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Development Design of Amine Sweetening Unit Plant of Natural Gas

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2022, International Journal for Research in Applied Science and Engineering Technology

https://doi.org/10.22214/IJRASET.2022.46548
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9 pages

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Related papers

Performance analysis of natural gas sweetening unit with amine solution and blends
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In this study, raw natural gas data from Uch gas field located in Dera-Bugti of Balochistan, Pakistan is simulated for performance analysis over amine absorber unit in Aspen HYSYS V9.0. The primary amine, MDEA was selected to remove bulk CO2 and reduce H2S to ppm level, where secondary amines, MEA, DEA and Sulfolane were selected to observe CO2 levels in sweet gas. The primary amine in isolation and blend with secondary amine was simulated and analysed over absorber performance. The absorber performance is reported as CO2, H2S and water content in sweet gas, hydrocarbons in rich amine and its temperature. MDEA in isolation resulted in minimum 14.13 and 12.78 mol% CO2 in sweet gas and rich amine temperature of 81.11oC and 82.13 o C with 24 and 30-Trays, respectively at 2500 m 3 /h of lean amine recirculation rate. Among the tested blends, MDEA/MEA, MDEA/Sulfolane showed no significant improvement on absorber performance compared to isolated MDEA. However, MDEA/DEA blends indicated that CO2 in sweet gas can be reduced to 12.07, 3.41, 1.85 mol% with rich amine temperature of 89.05, 111.72 and 124.80oC, respectively. The lowest CO2 detected of 1.85 mol% was achieved with 40 mol% MDEA and 15 mol% DEA blend at 2500 m 3 /h recirculation rate and rich amine temperature of 124.80oC. The results indicated that MDEA/DEA blend has the potential to attain CO2 of less than 2 mol%. The higher rich amine temperature raise concern that can be resolved by using heat stabilized salt.

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Selection of optimal operating parameters of amine-sweetening systems for natural gas with the spraying solution circulating in a closed loop
Hafiz Ahmad

Chemical and Petroleum Engineering, 2004

The dynamics of impurity accumulation in the circulation loop of a cleaning system is analyzed with respect to the following parameters: total impurity concentration per 1 m3 of sweetened natural gas, and the overall operating efficiency of sequentially installed types of equipment. Results of calculations are presented in the form of curves of impurity concentration in the circulation loop versus the operating time of the plant and the volley ejection of contaminants.

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Simulation and Optimization of the Acid Gas Absorption Process by an Aqueous Diethanolamine Solution in a Natural Gas Sweetening Unit
Reza Mosayebi Behbahani

ACS Omega

The presence of carbon dioxide in natural gases can lower the quality of natural gas and can cause CO 2 freezing problems. Therefore, using reliable techniques for the reduction and elimination of carbon dioxide from natural gases is necessary. The aqueous diethanol amine (DEA) solution's ability to simultaneously absorb H 2 S and CO 2 from sour natural gases makes it possible to use this solution in the natural gas sweetening process. The goal of this work was to determine the maximum amount of the removed CO 2 by an aqueous DEA solution in one of the gas sweetening plants of the National Iranian South Oilfields Company (NISOC). For this purpose, based on the obtained designed experiment results using the L9 orthogonal array Taguchi method, the experiments were conducted and three levels of amine concentrations (25, 28, and 30 wt %), temperatures (40, 50, and 60°C), and circulation rates of lean amine (220, 240, and 260 m 3 h −1) were considered as the key operational parameters on CO 2 removal. To evaluate the ability of the HYSYS simulation software and the Kent−Eisenberg thermodynamic model to predict CO 2 absorption by an aqueous DEA solution in the gas sweetening process, the field data were compared with the results of the simulation. It was observed that the maximum removal of CO 2 is achieved at a lean amine concentration of 30 wt %, a temperature of 40°C, and a circulation rate of 260 m 3 h −1. Also, the experimental results indicate that the effects of the selected process variables on CO 2 absorption are not linear and the most effective parameter on carbon dioxide removal is the concentration of amine in an aqueous solution and the temperature of the lean amine has the least effect. Besides, the obtained simulation results are in the range of the unit design basis but have some deviations from field data. The findings of this study can help in better understanding of the selection of the effective variables in the natural gas sweetening process and obtaining their appropriate values to achieve the highest efficiency.

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Monitoring, modeling, and optimization of parameters affecting the recovery efficiency of acid gases from a sweetening unit
Walaa Shehata

Amine processes are the advanced technology available today for the removal of carbon dioxide (CO 2) and hydrogen sulfide (H 2 S) acid gases. Methyldiethanolamine (MDEA) is a well-known tertiary amine used selectively for the removal of carbon dioxide from natural gas. There are many parameters that can affect the efficiency of separating these acid gases from natural gas. In this paper, we have studied, modeled, and optimized different operating parameters of sour gas feed and MDEA solution which affect the CO 2 recovery efficiency from an existing sweetening unit. These operating parameters are the sour gas feed temperature and pressure, volume ratio (%) of carbon dioxide in the feed gas, amine inlet temperature, and amine circulation rate. Actual data were collected from an industrial CO 2 sweetening unit over one year. These data were used to study the effect of the studied operating parameters on the recovery efficiency of CO 2 from the sweetening unit. All studied operating parameters were found to have an impact on the recovery efficiency of the removed gases. A response surface methodology approach was used in Design-Expert software version 13 to model the relationship between considered operating parameters and CO 2 recovery efficiency. In addition, Design Expert numerical optimization has been used to maximize CO 2 recovery efficiency. The results showed that the optimal range of sour gas feed temperature is 34.71 to 45.56 • C, sour gas feed pressure is 8.32 to 10.04 barg, the volume ratio (%) of carbon dioxide in the sour gas feed is 8.51 to 10.15, the temperature of the amine is 38.03 to 43.96 • C, and the amine circulation rate is 788.39 to 1122.35 m 3 /h. The presented work can be considered as a guideline for increasing the recovery efficiency of CO 2 for both new and existing sweetening units.

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Amine-based gas-sweetening processes prove economically more viable than the Benfield HiPure process
Richard J O H N Ochieng

2013

The removal of CO2 and H2S from natural gas streams is a crucial step for the Liquefied Natural Gas (LNG) industry. Since its inception, ADGAS (Abu Dhabi Gas Liquefaction limited) has been employing the Benfield HiPure process in its LNG plant in Das Island to purify sour natural gas to ultra-sweet specifications before it is compressed to produce LNG. This work compares the technical and economic performance of some simple amine-based processes to the Benfield HiPure process used in ADGAS LNG units. These process alternatives are evaluated and assessed based on the product purity, energy consumption and overall economic performance. Simulation results using the simulator ProMax clearly underpin the possibility of replacing the Benfield HiPure process with amine-based processes that achieve the same level of gas purity but with a better economics. Processes using mixed amines such as MDEA/DGA and MDEA/DEA prove more economically viable with a 50% reduction in capital costs and 20% a...

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S Imulation Studies on Natural Gas Sweetening Using P Iperazine Amine
Babu Ponnusami

This work aims at studying acid gas removal from natural gas with piperazine (PZ) amine by using Aspen HYSYS V9.0. Design of acid gas removal process is explained using sensitivity analysis. Plant capacity enhancement studies are performed by considering the crucial parameters like sour gas feed rate, amine recirculation rate and regenerator reboiler duty etc. The optimum feed temperature is identified as 31 0 C. Optimum concentration and flow rate of amine is 30 wt% and 350 m 3 /hr respectively. Rigorous hydraulic studies are performed for absorber to know the operational issues like flooding and weeping in the column. Arranging the packing in the absorber solved the operational issues and improved the C O2 and H2S removal efficiencies by 58% and 20% respectively. By arranging packing revenue losses are minimized by 2.1%. The techno-economic analysis results of this study are useful for process engineers working in gas plants to take reasonable decisions in operating the gas plant.

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Simulation of gas sweetening process using new formulated amine solutions by developed package and HYSYS
Reza Dorosti

2014

Commercial packages as HYSYS consider known amine solutions such as "MDEA, DEA, MEA ..." for simulation of gas sweetening processes. In the present work a software package was developed to represent equilibrium calculation of sour gases and new formulated amine solution. The software package accounts for chemical equilibria in the liquid phase and physical equilibria between the liquid and vapor phases. The Peng–Robinson– (PR) equation was used to represent the fugacity coefficient in the vapor phase. The liquid phase was treated as an electrolyte solution and activity coefficients were represented by the Deshmukh Mather equation. In this package a suitable and perfect platform was created to enter the new formulated amine solutions required information for simulation of gas sweetening process using HYSYS. The validity of software package calculations was compared to HYSYSAmine -Package for MDEA and reasonable agreement was achieved. The developed package as an HYSYS exten...

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Gas sweetening process
SUBHASISH MITRA

In Oil & Gas industry gas sweetening process is inevitable when raw natural gas contains acid gases like H2S and CO2. Removal of these acid gases is essential since their presence poses severe corrosion problem to the downstream process lines and equipment. Primary, Secondary and Tertiary amines are widely used as solvent for sweetening purpose. This compilation aims at providing general insight to the sweetening process, associated operational problems and troubleshooting measures.

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Theoretical effect of concentration, circulation rate, stages, pressure and temperature of single amine and amine mixture solvents on gas sweetening performance
Nilay Sarker

This simulation experiment performed by Aspen Hysys is about theoretical investigation of gas sweetening performance of single amine solvents MEA1, MDEA2, DEA3, DGA4, DIPA5 and mixed amine solvents DGA–MEA, DEA–MDEA and SULFOLANE6–MDEA. Sweet gas having very high percentage of methane is produced by MEA (95.36%), DGA–MEA (95.37%), DEA–MDEA (95.51%) and SULFOLANE–MDEA (95.10%) and DGA (93.76%) shows lowest performance. DGA, SULFOLANE–MDEA, MDEA remove H2S at a lower circulation rate and DEA, DIPA need higher but satisfactory circulation rate. Increasing stage number shows positive effect on DEA, DIPA and SULFOLANE–MDEA. Pressure change has no significant effect. Temperature increase and methane percentage are negatively correlated for all solvents (except low circulating DIPA). With temperature increase H2S composition increases for DEA–MDEA, DGA–MEA; CO2 increases for DEA–MDEA, DGA–MEA and high circulating SULFOLANE–MDEA.

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Optimization of Process Parameters for Natural Gas Sweetening Using Aspen Hysys and Response Surface Methodology
Akeem Arinkoola

2016

Amines process remains the most economic and efficient technology available today for the removal of acid gases. However, the costs associated with pumping higher flow rates and cost of increased energy needs for the regeneration of solution can undermine the economic feasibility of the project portfolio. The absorber pressure, the composition and temperature at which the sour gas is available dictates sour gas and amine flow rates needed to meet the sweet gas specifications. To improve absorber capacity for a given sweet gas specification, optimization are commonly carried out using spread sheet with an adjust function to manipulate sour gas flow rate for fixed amine flow rate. This study performed optimization using response surface methodology on a simulated and calibrated amine plant. The result shows that the optimum operating conditions for 96% CO2 removal were temperature of 30 oC, mass flow rate of 868.75 kg/hr and 20 numbers of plates. In conclusion, using experimental desi...

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References (20)

  1. Abry, R.G.F., and M.S. Dupart, "Amine Plant Troubleshooting and Optimization," Hydrocarbon Processing, Vol. 74, (No. 4), p. 41 (April, 1995).
  2. Barth, D., C. Tondre, G. Lappai, and J.J. Delpeach, "Kinetic Study of Carbon Dioxide Reaction and Tertiary Amines in Aqueous Solution," Journal of Physical Chemistry, Vol. 85, p. 3660 (1981).
  3. Bullin, J.A., J.C., Polasek, and J.W. Holmes, "Optimization of New and Existing Amine Gas Sweetening Plants by Computer Simulation," Proceedings of the 60 th GPA Annual Convention, p. 142 (1981).
  4. Bullin, J.A., and J.C. Polasek, "Selective Absorption Using Amines," Proceedings of the 61 st GPA Annual Convention, p. 86 (1982).
  5. Bullin, J.A., J.C. Polasek, and S.T. Donnelly, "The use of MDEA and Mixtures of Amines for Bulk CO2 Removal," Proceedings of the 68 th GPA Annual Convention, p. 135 (1989).
  6. Chen, C-C., L.B. Evans, "A Local Composition Model for the Excess Gibbs Energy of Aqueous Electrolyte Systems," AIChE Journal, Vol. 32, (No. 3), p. 444 (1986).
  7. Cornelissen A.E., "Simulation of Absorption of H2S and CO2 into Aqueous Alkanolamines," Shell Laboratory, p 3.1-3.15 (1982).
  8. Danckwerts, P.V., "The Reaction of CO2 with Ethanolamines," Chemical Engineering Science, Vol. 34, p. 443 (1979).
  9. Huffmaster, M.A., and P. Nasir, "Amine and Sulfinol Treating System Optimization," Proceedings of the 74 th Annual GPA Convention, p. 133 (1995).
  10. Keller, A, B. Scott, D. Tunnell, E. Wagner, and M. Zacher, "How Efficient Are Refinery Amine Units?" Hydrocarbon Processing, Vol. 74, (No. 4), p. 91 (April, 1995).
  11. Kent, R.L., and B. Eisenberg, "Better Data for Amine Treating," Hydrocarbon Processing, Vol. 55, (No. 4), p. 153 (March, 1976).
  12. Kohl, A. and F. Riesenfeld, Gas Purification, 4th Ed., Gulf Publishing Company, Houston, Texas (1985).
  13. Law D., "New MDEA Design in Gas Plant Improves Sweetening, Reduces CO2," Oil & Gas Journal, Vol. 92, (No 35), p. 83 (August, 1994).
  14. MacKenzie, D.H., F.C. Prambil, C.A. Daniels, and J.A. Bullin, "Design & Operation of a Selective Sweetening Plant Using MDEA," Energy Progress, Vol. 7, (No. 1), p. 31 (March, 1987).
  15. Okimoto, F. T., "The Benefits of Selective Gas Treating," Proceedings of the 72 nd GPA Annual Convention, p. 149 (1993).
  16. Polasek, J.C., G. A. Iglexias-Silva, and J. A. Bullin, "Using Mixed Amine Solutions for Gas Sweetening," Proceedings of the 71 st GPA Annual Convention, p. 58 (1992).
  17. Polasek, J.C., and J.A. Bullin, "Selecting Amines for Sweetening Units," Energy Progress, Vol. 4, (No. 3), p. 146 (September, 1984).
  18. Polasek, J.C., J.A. Bullin, and S.T. Donnelly, "How to Reduce Costs in Amine-Sweetening Units," Chemical Engineering Progress, p. 63 (March, 1983).
  19. Sartori, G. And D.W. Savage, "Sterically Hindered Amines for CO2 Removal from Gases," Industrial Engineering Chemistry Fundamentals, Vol. 22, p. 239 (1983).
  20. Spears, M.L., K. Hagan, J.A. Bullin, and C.J. Michalik, "Converting to Mixed Amines on the Fly," To be presented at the 75 th GPA Annual Convention on March 11-13, (1996).

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