الفهرس 
Chapter One : IntroductionOnly 14 pages are availabe for public view
 |  | from | 174 |  |  |
| | | from | 174 | | |
Abstract
Natural gas consumption is predicted to grow by more than 60% between now and 2040, owing to its reduced environmental effect when compared to other fossil fuels. Depending on the geological state of the reservoir, raw natural gas comprises a diverse spectrum of gases, including methane, heavier hydrocarbons such as ethane, propane, isobutene, regular butane, and a significant number of acid gases such as CO2, H2S, and CO.
Impurities must be removed from raw natural gas in order to: (i) increase calorific value, (ii) meet gas pipeline specifications (< 2 mol. % CO2 and 4 Part per million (PPM) H2S), (iii) optimize operating and capital costs, (iv) meet environmental criteria, and (v) raise the selling price of gas. Furthermore, considerable CO2 removal (50 PPM) is required when shipping natural gas as a liquid, Liquefied Natural Gas (LNG), to prevent CO2 freezing. As a result, eliminating these acid gases is a necessary and unavoidable step in the processing and conditioning of natural gas, which may be viewed as a stepping stone toward employing this energy source in a variety of applications.
In this study, an Aspen HYSYS, V 12 simulation study for an industrial gas sweetening plant held at Gulf of Suez Petroleum Company (GUPCO) in Raas-shukier, Egypt, was performed with feed composition of Flow rate of 12 million standard cubic feet per day (12 MMSCFD), temperature for feed gas of 41 ºC, pressure of 48.052 bar, and fluid package as an acid gas cleaning. The goal is to investigate the effect of different alternative reagent combinations in order to conduct comparative technical and payment studies with the goal of achieving higher recovery with the least amount of forging currency payment.
There are many treatment methods available for removal of CO2 and H2S. One method uses a single chemical solvent such as di ethanol amine (DEA), di glycol amine (DGA), di iso propanol amine (DIPA), methyl di ethanol amine (MDEA), piprazine (PZ), mono ethanol amine (MEA), SULFOLANE, or tri ethanol amine (TEA). Another one uses a mixed reagent of two chemicals such MDEA+PZ and MDEA+SULFOLANE. The normal focus has been on the amines which give more than 95 % removal of acid gas .A preceding investigation (M.Sc. ,which showed that DEA+PZ removed H2S and CO2 from acid gas by 99.98%, DGA +PZ by 100%, MDEA+PZ by 100%, MEA by 100%, MEA+PZ chemicals by 100% and PZ by100%.
Therefore, the most efficient amines utilized for gas sweetening are DEA+PZ, DGA +PZ, MDEA+PZ, MEA , MEA + PZ and PZ., which reached a recovery of the unit more than 99 % , while MEA being the cheapest one attaining the 100 % elimination of the acid gas. The second-best method of removing acid gases is mixing MEA with PZ; it completely recovered the H2S and CO2 removal. Furthermore, compared to MEA and MEA+PZ, the agents DGA+PZ, MDEA+PZ, DEA+PZ, and PZ provided more than 99 % recovery for the elimination of acid gas. Corrosion inhibitor researches were done to determine the corrosion rate in the amine unit, as this plant engaged DEA in the sweetening process. Within this unit, impurities known as heat stable salts (HSS) are formed and gradually developed past descent, thus the corrosion rate in the DEA unit increases. The unique procedure may minimize chemical consumption, unit downtime, Liquefied Petroleum Gas (LPG) recovery, inspection time, and diminution of the corrosion rate from 14 Mils per year (MPY) to 3 MPY and applying a corrosion inhibitor from NALCO champion firm. The cost of chemical depending on mass flow rate was examined, and the optimal neat dosage was established. The optimization discovered that the application of corrosion inhibitor 50 parts per million (PPM) may be considered the most recommended process.
The present study aims at deciding the best methodology to be used preferentially between the whole groupings (binaries) of treating amines, as well as it will be possible, taking the processing methodology, economics and benefits into consideration.