PROCESS FOR SELECTIVELY REMOVING HYDROGEN SULFIDE FROM A GAS STREAM AT HIGH PRESSURE

Abstract: Hydrogen sulfide can be removed selectively from a gas stream also containing carbon dioxide at high pressure, such as those found at natural gas production wellheads, by contacting the gas stream with an alkaline liquid for a time period of less than about 80 milliseconds.

Description: The present invention is directed to the selective removal of hydrogen sulfide from a gas stream. In particular, the present invention is directed to the selective removal of hydrogen sulfide from a high pressure gas stream which also con- tains carbon dioxide by using a metal chelate solution. Through operation at high pressures, the present invention may be used in situations where low pressure operation would be costly and time-consuming, such as in the removal of hydrogen sulfide from the gas stream of a natural gas production well. The present invention provides a process for the removal of hydrogen sulfide from a gas stream containing hydrogen sulfide and carbon dioxide, which process comprises contacting the gas stream with a stoichiometric excess of polyvalent metal chelate solution over the hydrogen sulfide, the solution having a pH of about 8.0 to 9.2 for a time less than 0.08 sec. to absorb hydrogen sulfide and not carbon dioxide, by flowing the gas stream and the solution past from two to six mixing elements in a static mixer, the gas stream, which can be from the well head of a natural gas production well, being maintained at a pressure of 5340-6170 kPa (760-880 psig) during the contacting period. The polyvalent metal-chelate solution is preferably iron- HEDTA (N- hydroxyethylethylenediaminetriacetic acid). Fig. 1 is a schematic representation of the equipment used in the experimental work described below; Figs. 2-4 are graphical representations of the data obtained in the experimental work described below. As noted above, the present process is directed to the selective removal of hydrogen sulfide from a gas stream at high pressure. The following apparatus and procedure were used in conducting the high pressure removal of hydrogen sulfide with an alkaline absorbing solution. Referring to Fig. 1, wellhead gas was contacted with absorbing solution in a static mixer and quickly separated in a gas/liquid separator. The gas/liquid separator was operated at the wellhead pressure, while the gas flow rate was varied through the use of valve V₁. An orifice flange was set up to measure the gas flow rate downstream of valve V₁. The pressure gauge on the gas/liquid separator indicated wellhead pressure when valve V₁ was shut and flowing pressure during testing. Valve V₂ was opened slightly to allow a slow flow to the gas chromatograph and the hydrogen sulfide tube samplers. Liquid was pumped to the static mixer by a variable speed Zenith® gear pump. A two-liter cell was used for the liquid reservoir, and wellhead pressure pressurized the liquid reservoir which fed the pump. The wellhead gas which pressurized the liquid reservoir first passed through a methyldiethanol amine scrubber which removed the acid gases from the gas. Wellhead temperature was monitored by a thermocouple, in-line with a pyrometer. Three solutions were tested. The first solution was 50% by weight methyldiethanol amine. The amine was purchased from Pfaltz and Bauer, Inc. The remaining two solutions were dilutions of Dow Chemical's Versenol 5% iron chelate solution, and iron-HEDTA chelate solution. The concentrations of the solutions were 0.32 molar and 0.11 molar, and the pH of each was adjusted to 9.2 with ammonium carbonate solution. The gas tested had a composition of 95.3 mole percent methane, 1.5 mole percent ethane, 0.3 mole percent propane, 0.4 mole percent nitrogen, 1.8 mole percent carbon dioxide, 0.1 mole percent hydrogen sulfide and 0.6 mole percent other hydrocarbons. The gas was tested at pressures from 5340 to 6170 kPa (760 to 880 psig). Four different sizes of static mixers were used during the test: 12.7 mm (1/2″) diameter by 152.4 mm (6″) long; 9.5 mm (3/8″) diameter by 114.3 mm (4-1/2″) long; 6.4 mm (1/4″) diameter by 63.5 mm (2-1/2″) long; and 6.4 mm (1/4″) diameter by 127 mm (5″) long. In the first test, the 50% by weight amine solution was used with the 12.7 mm (1/2″) static mixer. The gas flow rate was set at 85,000 standard liter per hour (3,000 standard cubic feet per hour), which resulted in a gas- liquid contact time in the static mixer of 100 milliseconds. This was the maximum flow rate that could be run with this equipment because of pressure drop limitations in the equipment. Five liquid flow rates were run, and the results are shown in Fig. 2. This figure shows the percent of hydrogen sulfide removed as a function of excess molar amine pumped. Approximately 9% of the carbon dioxide also was removed with the hydrogen sulfide. This was not unexpected, because of the relatively long contact time between the liquid and the gas. About 70% of the hydrogen sulfide was removed with a pumped amine stoichiometric excess of 300%. To reduce the gas-liquid contact time, the 9.5 mm (3/8″) static mixer was used. With a gas flow rate of 59400 standard liter/hour (2,100 scfh), a contact time in the static mixer of 17 milliseconds was maintained for the second test. As can be seen in Fig. 2, at the shorter con- tact time, the hydrogen sulfide still was removed, but not as efficiently as at the longer contact time. Carbon dioxide was also removed (about 8%) which was not expected. These results illustrate that both the amine/hydrogen sulfide and amine/carbon dioxide reactions are kinetically limited. Other work has shown that carbon dioxide removal is diffusion limited, and can be controlled by limiting the gas-liquid contact time to under 80 milliseconds. A concentrated iron chelate solution also was run to determine if selective hydrogen sulfide absorption could be achieved at the higher pressures. Because of limited pumping rates, less gas was processed in this test. The 6.4 mm x 63.5 mm (1/4″ x 2-1/2″) static mixer was used to obtain a short gas-liquid contact time of 17 milliseconds. Fig. 3 shows that in contacting the gas with a 12-fold stoichiometric excess of iron, 89% of the hydrogen sulfide was removed with no carbon dioxide absorption. For either iron chelate or amine solutions, a stoichiometric excess over the hydrogen sulfide is necessary, since the mixing does not provide for a stoichiometric reaction. The 6.4 mm x 127 mm (1/4″ x 5″) static mixer then was tested and operated at the same gas rate. This produced a gas-liquid contact time of 30 milliseconds in the static mixer, doubling not only the contact time, but also the number of mixing elements in the static mixer. Fig. 3 shows that a slight increase in hydrogen sulfide absorption was achieved with no carbon dioxide absorption. This shows that the six mixing elements in the 6.4 mm x 63.5 mm (1/4″ x 2-1/2″) static mixer were sufficient to obtain the needed liquid dispersion to assure kinetic control of the reaction. In the next test, the iron chelate solution was diluted to yield a final iron chelate concentration of 0.11 M, as opposed to the 0.32 M solution tested previously. Again, no carbon dioxide was absorbed during the test. As shown in Fig. 3, to achieve 80% hydrogen sulfide removal, a 380% molar excess of iron chelate was needed. The data from all the tests are given in the Table on the following page Fig. 4 shows the same data as Fig. 3, but as a function of pumping rate. The dilute solution is not as efficient in this case. However, only a 5% increase in hydrogen sulfide removal is seen over the dilute solution. Since concentration appears to make very little difference, the limiting factor for the concentrations tested is the total liquid surface area. The total liquid surface area is a function of the mean drop diameter and the volume of liquid pumped. The mean drop diameter is controlled by the type and number of static mixer elements used along with the velocity of the fluids and the physical properties of both the liquid and gas. This is described in U.S. Patent 4,499,059. Using static mixers with a gas-liquid system, a stable mean drop diameter is obtained with two to six static mixer elements. Additional elements do not reduce the mean drop diameter. Thus, with six mixing elements, the total liquid surface area can be controlled by varying the liquid flow rate, and hence at constant gas rates the solution pH's, the hydrogen removal efficiency can be controlled by varying the liquid flow rate. The polyvalent metal chelate solution must have a pH of at least 7, preferably 8-9, and may be a polyvalent metal chelate solution, with pH adjusted by sodium or ammonium carbonate. The polyvalent metal may be selected from iron, copper, manganese, lead, mercury, palladium, platinum, tungsten, nickel, chromium, cobalt, vanadium, titanium, tantalum, zirconium, molybdenum and tin, preferably iron, copper and manganese, and most preferably iron. The chelating agent may be selected from amino acetic acids derived from ammonia or 2-hydroxyalkylamines, such as gly- cine, diglycine (aminodiacetic acid), nitrilo triacetic acid, 2-hydroxyalkylglycine, di-hydroxyalkylglycine and hydroxyethyl or hydroxypropyldiglycine, amino acetic acids derived from ethylene diamine, diethylenetriamine, 1,2-propylenediamine and 1,3-propylenediamine, such as EDTA, 2-hydroxy EDTA, and diethylene triamine pentacetic acid, amino acetic acid derivatives of cyclic 1,2-diamines, such as 1,2-diaminocyclohexane-N, N- tetraacetic acid, and amides of polyamino acetic acids, as disclosed in U. S. Patent No. 3,580,950 to Bersworth. EDTA and N-hydroxyethylethylenediaminetriacetic acid (HEDTA) are particularly preferred. The alkaline liquid also may be selected from aqueous solutions of inorganic salts having an alkaline reaction, such as alkali metal hydroxides, phosphates, borates, metaborates or arsenites, solutions of organic bases, such as alkanolamines, like monoethanol amine, diethanolamine, triethanolamine, N-methyldiethanolamine, alkanoldiamines, alkenylpolyamines, or solutions of salts of weak organic acids, such as amino carboxylic acids and aminosulfonic acids, or other alkaline liquids. Alkali metal hydroxides and alkanolamines are preferred, particularly diethanolamine and N- methyldiethanolamine. Thus, the present invention provides a process for the selective removal of hydrogen sulfide from a gas stream also containing carbon dioxide, at high pressure, by contacting the gas stream with an alkaline liquid. A limited gas-liquid contact time of less than 0.08 sec. allows selective removal of hydrogen sulfide. Although a detailed description of the present inven- tion has been provided above, the present invention is not limited thereto.

Claims: 1. A method of selectively removing hydrogen sulfide from a gas stream comprising hydrogen sulfide and carbon dioxide, which method comprises contacting the gas stream with a solution of a polyvalent metal chelate for a period sufficient to absorb the hydrogen sulfide but not the carbon dioxide, the contact period being less than 80 ms, the gas stream being at a pressure from 5340 to 6170 kPa (760 to 880 psig) during the contact period and the solution having a pH above 7.0 and being in stoichiometric excess over the hydrogen sulfide. 2. A method according to claim 1 wherein the polyvalent metal comprises iron, copper, manganese, lead, mercury, palladium, platinium, tungsten, nickel, chromium, cobalt, vanadium, titanium, tantalium, zirconium, molybdenium or tin. 3. A method according to claim 2 wherein the polyvalent metal comprises iron, copper or manganese. 4. A method according to claim 3 wherein the polyvalent metal comprises iron. 5. A method according to any preceding claim wherein the chelating agent comprises an aminoacetic acid or amide derived from ammonia, a hydroxyalkylamine, ethylene diamine, diethylenetriamine, 1,2-propylenediamine, 1,3-propylenediamine or a cyclic 1,2-diamine. 6. A method according to claim 5 wherein the chelating agent comprise ethylenediaminetetraacetic acid or N-hydroxyethylenediaminetriacetic acid. 7. A method according to any preceding claim wherein the solution has a pH from 8.0 to 9.2. 8. A method according to any preceding claim wherein the contact is effected by flowing the gas stream and the solution past from two to six mixing elements in a static mixer. 9. A method according to claim 8 wherein the gas stream and the solution flow past six mixing elements.

Inventors: JONES, TIMOTHY ALAN, SNAVELY, EARL SAMUEL, JR.
Applicants: MOBIL OIL CORPORATION
Application year: 1988
Main classification: B01D53
IPC codes: B01D53, C10L3