The present invention relates to a packed bed and process for removal of residual mercury from gaseous hydrocarbons.

Natural gas which is produced from a natural gas well is usually separated and purified to provide products for a variety of end uses. The high-pressure mixture produced from the well, i.e. the wellstream, is typically sent to a separator vessel or a series of separator vessels maintained at progressively lower pressures where the wellstream is separated into a gaseous fraction and a liquid fraction.

The gaseous fraction leaving the separator, which may contain the impurities mercury, carbon dioxide and hydrogen sulfide, is sent to a gas treatment and purification plant where the mercury concentration is

₃ normally reduced to < 0.1 micrograms/Nm , the CO concentration is reduced to a few parts per million (ppm) , and the H_S to about one (1) pp .

The purification of the gaseous fraction is commonly achieved by passing the gaseous fraction over a bed of activated carbon which has been impregnated with sulfur. In this step, the mercury in the gas reacts with the sulfur and is essentially removed from the gaseous fraction. The mercury content of the gas can be reduced from about 250 microgfrra«ms/Nm 3 or higher to less than about 0.1 micrograms/Nm3"

The gas leaving the sulfur/carbon bed then could be treated with a hot aqueous potassium carbonate solution which has the ability to absorb CO and H_S.

This step produces a natural gas stream having a reduced CO and H S content. For example, the CO content of the gas can be reduced from about 15% to

about 0.3% and the H S content from about 80 ppm to about 6 ppm.

The natural gas stream which resulted from treatment with the carbonate solution is further treated in order to reduce the amount of CO- and H_S by treating the gas with an amine solution, e.g. an aqueous solution of diethanolamine. Diethanolamine has the ability to absorb CO and H_S, and can reduce the CO content from about 0.3% to about 50 ppm, and the H-S content from about 6 ppm to about 1 ppm. The natural gas is then washed with water to remove traces of entrained amine. This water wash, however, neither removes residual mercury, typically present in levels of less than 0.1 microgram/Nm 3, nor residual H S and CO-, typically about 1 ppmv and 50 ppmv, respectively. The washed natural gas is water-saturated and has to be dried prior to liquefaction. Usually drying is achieved by contacting the wet gas with a desiccant in a packed bed specifically designed for this purpose. The desiccant bed undergoes repeated cycles of adsorption and regeneration. To ensure that the desiccant bed retains its integrity during the drying and regeneration cycles, a protective layer of inert alumina spheres having a depth of about 0.5 to 2 ft (15 to 61 cm) is placed over the desiccant. The alumina spheres in the protective layer are somewhat larger than the desiccant particles.

The dried gas, which still contains small amounts of mercury, CO and H S, can be further purified by contacting it with an adsorbent bed comprising sulfur on carbon, which has the ability to selectively remove mercury from the gas. Usually such an adsorbent can reduce the mercury concentration to less than about 0.01 microgram/Nm 3. However, including such an additional bed causes a pressure drop in the system,

which is undesirable in a system where elevated pressure is required for the maximum efficiency.

Although the Hg content of the gas is reduced by the use of this additional adsorbent bed, its H_S and CO_ content remain unchanged at about 1 and 50 ppmv respectively. In a liquefaction process, the temperature required to liquefy methane is 109°K, i.e. -164°C, which is well below the freezing point of CO _? . Thus, in time, C0_ can accumulate in the cold parts of a liquefaction train and can cause plugging which is undesirable. Although H ₂ S is present in lesser amounts than the CO , its freezing point, 187°K, i.e. -86°C, is also well above the 109°K, which means that any H S in the gas will become a solid at the conditions of the liquefaction process which can add to the plugging problem.

Thus, it would be beneficial to provide a mechanism for further reducing the level of residual mercury from the gas leaving the desiccant bed without the pressure reduction which usually results from using a second adsorbent bed. It would also be very desirable to remove CO and H ₂ S from the gas to reduce the risk of plugging.

According to one aspect of the invention there is provided a packed bed for removing moisture and mercury from a gas at a temperature range of substantially 50°F to 120°F (10°C to 49°C) comprising: a layer of desiccant particles; a porous layer containing an element selected from the group consisting of silver, gold and mixtures thereof; and at least one protective layer of pellets or spheres for maintaining the integrity of the packed bed, said pellets or spheres being larger than the desiccant particles and comprising an inert substrate on which an active compound selected from the group consisting of copper

oxide, copper hydroxide and copper sulfide is impregnated.

The present invention provides a conventional packed bed containing a desiccant with means for removing residual mercury, H ₂ S and CO- from a gas, such as a natural gas stream, by providing a porous silver and/or gold-containing layer, and an inert protective layer, e.g. of alumina pellets, with an active compound having at least one of copper hydroxide, copper oxide and copper sulfide. The active compound provides the desiccant bed with the additional advantage of removing H_S and CO as well as mercury from the gaseous fraction without incurring the pressure loss inherent in utilizing a separate downstream adsorbent bed for removing Hg.

It has been found that directing a gas stream containing residual amounts of mercury through a porous silver and/or gold-containing layer efficiently removes residual amounts of mercury. In addition, it has been found that alumina impregnated with copper hydroxide or with copper oxide reacts with hydrogen sulfide to form copper sulfide. It has also been found that copper sulfide can be used to remove mercury from natural gas. Moreover, CO can react with copper oxide and copper hydroxide at relatively high pressures to form copper carbonate. Copper carbonate is thermally unstable and decomposes at 200°C to give off CO .

The present invention utilizes these phenomena in providing an improved gas purification procedure for the removal of mercury from natural gas. Specifically, the present invention takes advantage of the ability of silver and/or gold to react with mercury, the ability of copper oxide and copper hydroxide to react with hydrogen sulfide and carbon dioxide, the ability of copper carbonate to thermally decompose at about 220°C

and the ability of copper sulfide to remove mercury from a gaseous stream. The present invention also takes advantage of the ability to regenerate copper sulfide which is used to remove the mercury from the gas stream at the temperature of desiccant regeneration.

The packed bed includes at least one porous silver and/or gold-containing layer. Both silver and gold have the ability to remove mercury from a gas stream by amalgamation. The mercury present in the gas stream becomes an amalgam with the silver and/or gold-containing layer as the gas stream passes through. The amalgamated mercury in the silver and/or gold-containing layer is then removed during desiccant regeneration. The porous silver and/or gold-containing layer may be in the form of a screen woven from silver containing and/or gold-containing wire. The screen is woven to from about 4 to about 80 size mesh, preferably from about 10 to 30 size mesh and most preferably into a screen having about a 20 size mesh. Alternatively, the porous silver and/or gold-containing layer may be in the form of loosely packed silver and/or gold wire or silver and/or gold "wool". A key to the method of the method and apparatus of the invention is that the silver and/or gold-containing layer is porous and can allow a gas stream to pass through without incurring a pressure drop which is inherent when utilizing separate and additional downstream mercury removal beds.

The porous silver and/or gold-containing layer may be composed of more than one type of the above- described porous silver-containing elements. For example, the porous silver and/or gold-containing layer may include a silver-containing screen, a gold- containing screen and/or loosely packed silver wire or "wool", gold wire or "wool" and/or other forms of

porous silver and/or gold-containing materials. The porous silver and/or gold layer may be disposed above and/or below the desiccant in the desiccant bed. In a preferred embodiment, however, the desiccant bed includes both a porous silver and/or gold layer disposed above the desiccant as well as another porous silver and/or gold layer disposed below the desiccant.

The desiccant of the present invention may comprise any solids which have the ability to adsorb water and release it upon heating to regenerate the desiccant, as well as to withstand the regeneration temperatures described below.

The protective layer of inert pellets or spheres, are usually placed on top of a desiccant bed to ensure that the desiccant bed retains its integrity during drying and regeneration. The porous silver and/or gold-containing layer may then be placed above the alumina pellets or spheres. It should be noted, however, that the protective layer may also, or instead, be disposed under the desiccant bed.

The protective layer preferably includes a porous substrate: alumina in the form of pellets is a preferred substrate of the present invention, but other substrates may also be utilized including silica, silica-alumina, molecular sieves, silica gels, and combinations thereof. Those skilled in the art will also appreciate that certain porous substrates will also provide the added advantage of having the ability to absorb some moisture from the moisture-containing gas thereby supplementing the dehydration performed by the desiccant.

The active substances, namely the copper hydroxide, copper oxide, and copper sulfide are most preferably impregnated into separate pellets. Thus, some of the pellets will be treated with copper

hydroxide while others will be treated with copper oxide, and still others will be treated with copper sulfide. While it is preferred that the entire protective layer of alumina pellets is treated with one or more of these reactive substances, some of the pellets may be left untreated leaving some inert pellets in the protective layer.

Any known method for impregnating the porous substrate with these active compounds may be utilized. For example, the copper hydroxide impregnated alumina pellets may be prepared by thoroughly mixing 30 parts by weight of alumina (dry basis) with 8 parts copper hydroxide and 62 parts of deionized water, extruding the mixture through a 0.25 inch (0.64 cm) dieplate and drying at 120°C. The copper oxide impregnated pellets may be prepared by heating the copper hydroxide impregnated pellets to 400°C. The copper sulfide impregnated pellets may be prepared by reacting the copper hydroxide impregnated pellets with gaseous hydrogen sulfide.

When copper oxide is added to a substrate, it is preferably added in an amount of about 10-20% by weight of said substrate, most preferably about 12-18%. Similarly, copper hydroxide is preferably added in an amount of about 10-30% by weight based on the weight of the substrate, and most preferably in an amount of about 15-20% by weight. Lastly, when copper sulfide is utilized, it is preferably added in an amount of 10-20% by weight of the substrate, most preferably in an amount of about 12-18% by weight.

According to one preferred embodiment of the present invention, the ratio of each type of pellet, in other words the ratio of pellets treated with copper hydroxide to the number treated with copper oxide to the number treated with copper sulfide is about 1:1:1.

Copper sulfide has the ability to remove mercury from natural gas to about the same purity level as other mercury removal materials while allowing the adsorbed mercury to be stripped off during the desiccant regeneration cycle (heating with a gas sweep to about 500 to 700°F [260 to 371°C]). Hence, the copper sulfide is periodically and simultaneously regenerated with the desiccant. Thus, in addition to supplying integrity to the packed bed, the CuS- impregnated alumina spheres remove mercury from the gas, without the requirement for an additional specially designed adsorbent bed with its additional inherent pressure drop. The copper hydroxide and copper oxide not only have the ability to react with CO and H_S and remove them from the gas, but by forming copper sulfide, also assist in reducing the level of mercury in the gas.

According to another aspect of the invention there is provided a process for removing moisture and mercury from a gas at a temperature range of substantially 50°F to 120°F (10°C to 49°C) comprising the steps of: purifying said gaseous fraction with a solution which has the ability to absorb carbon dioxide and hydrogen sulfide contained in the gas; washing said purified gas with water to remove entrained absorbent solution and provide a substantially absorbent solution-free stream; contacting said stream with a packed bed comprising: a layer of desiccant particles; a porous layer containing an element selected from the group consisting of silver, gold and mixtures thereof; and at least one protective layer of pellets or spheres for maintaining the integrity of the packed bed, said pellets or spheres being larger than the desiccant particles and comprising an inert substrate on which an active compound selected from the group consisting of copper

oxide, copper hydroxide and copper sulfide is impregnated.

The packed bed used in this process may have one or more features of the packed bed described above. Preferably the gas is natural gas, although it may be used in the purification of other gases, such as hydrogen, ethylene, etc. Desirably the purifying solution comprises a carbonate. The gas is preferably subsequently washed with diethanolamine. One of the advantages of the present invention is that it does not require substantial changes to a conventional gas treatment process. The benefits of the present invention may be obtained while supplying the contaminated, moisture-containing natural gas into the packed bed at a pressure of about 1 to 100 atmospheres (101 to 10100 KPa) , at a temperature of substantially 50 to 120°F (10 to 49°C) and at a space velocity of about 1 to 300. Most preferably, the contaminated, moisture-containing gas is fed into the desiccant bed at a pressure of about 20 to 60 atmospheres (203 to 608 KPa), a temperature of about 60 to 110°F (16 to 43°C), and at a space velocity of about 100 to 200. Those skilled in the art will appreciate that the space velocity is defined as the volume of gas passing through the packed bed every hour divided by the volume of the packed bed. As used herein, the volume of the packed bed is considered to be the sum of the volume of the desiccant and the total volume of pellets whether treated with one of the above mentioned active compounds or untreated and left in an inert state.

As mentioned above, the packed bed can be regenerated by passing a gas such as methane, ethane or propane, through the desiccant bed at a temperature of about 400 to 700°F (204 to 371°C) , most preferably at a temperature of about 600°F (316°C). This regeneration

step advantageously decomposes accumulated copper carbonate into carbon dioxide and copper oxide. The carbon dioxide is also advantageously carried away with the regenerating gas while the copper oxide remains in the alumina pellets for future use in removing contaminants from the natural gas.