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Amine Gas Treating Unit Best Practices - Troubleshooting Guide for H2S/CO2 Amine Systems

Amine Gas Treating Unit - Best Practices - Troubleshooting Guide for H2S/CO2 Amine Systems

Amine Gas Treating Unit - Best Practices - Troubleshooting Guide for H2S/CO2 Amine Systems Contents Process Capabilities for gas treating process Typical Amine Treating Typical Amine System Improvements Primary Equipment Overview Inlet Gas Knockout Absorber Three Phase Flash Tank Lean/Rich Heat Exchanger Regenerator Filtration Amine Reclaimer Operating Difficulties Overview Foaming Failure to Meet Gas Specification Solvent Losses Corrosion Typical Amine System Improvements Degradation of Amines and Alkanolamines during Sour Gas Treating APPENDIX Best Practices - Troubleshooting Guide

WWW.GBHENTERPRISES.COM AM I N ES GAS T REAT I N G Be st Pra c t ic e s Guide Cont e nt s Proc e ss Ca pa bilit ie s for ga s t re at ing proc e ss Typic a l Am ine Tre at ing Typical Amine System Improvements Prim a r y Equipm e nt Ove r vie w Inlet Gas Knockout Absorber Three Phase Flash Tank Lean/Rich Heat Exchanger Regenerator Filtration Amine Reclaimer WWW.GBHENTERPRISES.COM AM I N ES GAS T REAT I N G Be st Pra c t ic e s Guide Cont e nt s Ope rat ing Diffic ult ie s Ove r vie w Foaming Failure to Meet Gas Specification Solvent Losses Corrosion Typic a l Am ine Syst e m I m prove m e nt s De gra dat ion of Am ine s a nd Alk a nola m ine s during Sour Ga s Tre at ing APPEN DI X Be st Pra c t ic e s - Trouble shoot ing Guide WWW.GBHENTERPRISES.COM Am ine s: Ga s Tre at ing WWW.GBHENTERPRISES.COM Am ine s: Ga s Tre at ing WWW.GBHENTERPRISES.COM Am ine s: Ga s Tre at ing WWW.GBHENTERPRISES.COM Am ine s: Ga s Tre at ing WWW.GBHENTERPRISES.COM Am ine s: Ga s Tre at ing WWW.GBHENTERPRISES.COM Am ine s: Ga s Tre at ing WWW.GBHENTERPRISES.COM Am ine s: Ga s Tre at ing WWW.GBHENTERPRISES.COM Am ine s: Ga s Tre at ing Wastes Types Generated in Different CO2 Removal Process units WWW.GBHENTERPRISES.COM Typic a l Am ine s Tre at ing WWW.GBHENTERPRISES.COM Am ine s: Ga s Tre at ing Sour gas sweetening process WWW.GBHENTERPRISES.COM Am ine s: Ga s Tre at ing WWW.GBHENTERPRISES.COM Typic a l Am ine Syst e m Prim a r y Equipm e nt Ove r vie w WWW.GBHENTERPRISES.COM Typic a l Am ine Syst e m Prim a r y Equipm e nt Ove r vie w Inlet Gas Knockout Absorber Three Phase Flash Tank Lean/Rich Heat Exchanger Regenerator Filtration Amine Reclaimer WWW.GBHENTERPRISES.COM Typic a l Am ine Syst e m I nle t Ga s K nockout Before entering the absorber, the gas is passed through an inlet separator where entrained droplets or slugs of liquid are removed from the gas stream by impaction devices (to the right >>>>>) Baffles remove a portion of the liquids. Mist eliminator pads, located near the gas outlet of the tank, trap the rest. Typical contaminants in natural gas streams may be liquid hydrocarbons, salt water, sands, well treating compounds, pipeline treating chemicals, and compressor oils. WWW.GBHENTERPRISES.COM Typic a l Am ine Syst e m Tra y Tow e r Absorbe r The sour gas, freed of entrained liquids by the inlet separator, enters the bottom of the absorber. Usually the absorber is a tray column; although packed columns are also used. In either case, the objective is to provide intimate contact between the gas and the amine solvent so that the H2S and C02 molecules can transfer from the gas phase to the solvent liquid phase. In tray columns, a liquid level is maintained on each tray by a weir usually 2 or 3 inches high (Figure >>>>>). WWW.GBHENTERPRISES.COM Typic a l Am ine Syst e m Three Phase Flash Tank In many units the rich amine solution is sent from the absorber to a flash skimmer tank to recover hydrocarbons that may have dissolved or condensed in the amine solution in the absorber. The pressure of the solution is dropped as it enters the tank, allowing the lightest of the hydrocarbons to flash. The heavier hydrocarbons remain as a liquid, but separate from the aqueous amine, forming a separate liquid layer. WWW.GBHENTERPRISES.COM Typic a l Am ine Syst e m Lean/Rich Heat Exchanger The rich solvent is preheated before entering the stripper. Because the lean amine exiting the reboiler must be cooled before entering the absorber, there is an opportunity to exchange heat from the lean to the rich stream, thereby reducing the heat load on the reboiler. This is usually done in a shell and tube lean/rich heat exchanger with the rich solvent passed through the tubes, which are usually made of stainless steel. Note: Recommended maximum velocity to minimize corrosion in the tubes is 3 or 3.5 feet/sec. WWW.GBHENTERPRISES.COM Typic a l Am ine Syst e m Regenerator Like the absorber, the stripper is either a tray or packed column with approximately 20 trays or the equivalent height in packing. To minimize amine vaporization loss, there may be a water wash section at the top of the column with an additional four to six trays. The preheated rich amine enters near the top of the column and flows down countercurrent to a gas stream of steam, H2S, and C02. The steam is generated in the reboiler, lowering the partial pressure of H2S and C02 in the gas stream, enhancing driving force of the acid gases from the amine solution. WWW.GBHENTERPRISES.COM Typic a l Am ine Syst e m Filtration A filtration scheme of mechanical and activated carbon filters is important in maintaining good solution control. Mechanical filters such as, cartridge filters or precoat filters remove particulate material while call filters remove chemical contaminants such as entrained hydrocarbons and surface-active compounds. Filters are located in the rich line in some plants, and in the line in others. One manufacturer recommends filters in both rich and lean lines. Locating the filters in the rich line upstream of the lean rich heat exchanger will protect both the heat exchanger and the stripper from plugging, and reduce the erosion/corrosion rate in the heat exchanger. WWW.GBHENTERPRISES.COM Typic a l Am ine Syst e m Filtration A 10 to 20 micron mechanical filter should be adequate for particulate removal. If cotton filters are used, the cotton should be virgin cot ton rather than recycled. Recycled cottons may contain fibers with coatings which may be the source of amine solution foaming problems. Circulation rates through mechanical filters range from 5% of the circulating system to full fl depending on the degree of contamination. Recommendations for flow to carbon filters range from less than I percent to 5 to 10 percent and some units have been built with full flow. WWW.GBHENTERPRISES.COM Typic a l Am ine Syst e m Filtration Crit e ria I n de t e r m ining w he n a c a rbon be d should be cha nge d T he follow ing c a n be use d a s a guide : 1 ) a high pre ssure drop a c ross t he be d, c a use d by solids plugging t he voids; 2 ) a c olor c om pa rison be t w e e n a sa m ple t a ke n from t he out le t of t he filt e r a nd a pla nt sa m ple run t hrough fre sh c a rbon in t he la b. Ac t ive c a rbon w ill re m ove c olor; 3 ) a n inc re a se in foa m ing t e nde ncy in t he pla nt , or t he st a r t of a foa m ing proble m . WWW.GBHENTERPRISES.COM Typic a l Am ine Syst e m Amine Reclaimer WWW.GBHENTERPRISES.COM Typic a l Am ine Syst e m Amine Reclaimer WWW.GBHENTERPRISES.COM Typic a l Am ine Syst e m Ope rat ing Diffic ult ie s Am ine ga s sw e e t e ning pla nt s c a n ex pe rie nc e ope rat ing diffic ult ie s including foa m ing, fa ilure t o m e e t sw e e t ga s spe c ific at ion, high solve nt losse s, c orrosion, fouling of e quipm e nt , a nd c ont a m inat ion of t he a m ine solut ion. Oft e n one ope rat ing diffic ult y is t he c a use of a not he r. N ot a ll pla nt s ex pe rie nc e t he sa m e proble m s t o t he sa m e de gre e , a nd w hat m a y be a c ont inua l proble m in one pla nt m a y oc c ur only ra re ly in a not he r. WWW.GBHENTERPRISES.COM Typic a l Am ine Syst e m Ope rat ing Diffic ult ie s Foaming Failure to Meet Gas Specification Solvent Losses Corrosion WWW.GBHENTERPRISES.COM Typic a l Am ine Syst e m Ope rat ing Diffic ult ie s Foaming Failure to Meet Gas Specification Solvent Losses Corrosion WWW.GBHENTERPRISES.COM Typic a l Am ine Syst e m Ope rat ing Diffic ult ie s Sym pt om s of Foa m ing WWW.GBHENTERPRISES.COM Typic a l Am ine Syst e m Ope rat ing Diffic ult ie s: Foa m ing I Pure aqueous amine solutions do not foam. It is only in the presence of contaminants such as condensed hydrocarbons, small suspended particulate matter, or other surface active agents such as some pipeline corrosion inhibitors or compressor oils, that a foaming problem may develop. Foaming usually occurs in the absorber or the stripping tower, and is accompanied by a sudden noticeable increase in the differential pressure across the column. Other indications of a foaming condition may be a high solvent carryover, a drop in liquid levels, and the detection of off-specification gas. WWW.GBHENTERPRISES.COM Typic a l Am ine Syst e m Ope rat ing Diffic ult ie s: Foa m ing I I An immediate method to control a foaming problem is the addition of an antifoam at a location just upstream of the foam. Effective foam inhibitors for amine sweetening systems are silicone antifoams and polyalkylene glycols. Also widely used are high-boiling alcohols such as oleyl aIcohol and octylphenoxyethanol. It is advisable to test the antifoam on a plant sample in the laboratory before applying it in the field to verify that it will break the foam. In the event that one antifoam is ineffective, switching to another antifoam may solve the problem. WWW.GBHENTERPRISES.COM Typic a l Am ine Syst e m Ope rat ing Diffic ult ie s: Foa m ing I I I The silicone antifoams have proven to be quick and effective in controlling foaming problems in the gas treating industry. When using a silicone antifoam, the antifoam should be added downstream of the carbon filters because carbon filters will adsorb the silicone. Care should be exercised with respect to the amount of silicone antifoam added to a system. The silicone antifoams should be used only in small quantities, as recommended by the manufacturer. It is important to be aware that silicone antifoams used in excessive quantities have the potential to promote the formation of foam. WWW.GBHENTERPRISES.COM Typic a l Am ine Syst e m Ope rat ing Diffic ult ie s: Foa m ing I V The use of an antifoam may only be a temporary solution to a continuing problem. The objective in controlling foaming should be to minimize the level of contaminants in the amine solution. Of critical importance is the prevention of entrained contaminants in the feed gas from entering the amine system. The inlet separator, equipped with a demister pad and possibly filters, is instrumental in trapping most contaminants, and should be monitored to insure that it is operating efficiently and not being overloaded. Mechanical and carbon filters are necessary in maintaining a clean solution. In order to prevent hydrocarbons from condensing in the absorber, the lean amine feed temperature should be held between 10'F and 20'F above the temperature of the feed gas. WWW.GBHENTERPRISES.COM Typic a l Am ine Syst e m Ope rat ing Diffic ult ie s Foaming Failure to Meet Gas Specification Solvent Losses Corrosion WWW.GBHENTERPRISES.COM Typic a l Am ine Syst e m Ope rat ing Diffic ult ie s Ca use s of Fa ilure t o M e e t Spe c ific at ions WWW.GBHENTERPRISES.COM Typic a l Am ine Syst e m Ope rat ing Diffic ult ie s Failure to Meet Gas Specification I Difficulty in meeting the sweet gas specification may be the result of poor contact between the gas and the amine solvent, which may in turn be caused by foaming or mechanical problems in the contacting equipment. In the case of foaming, the gas remains trapped in bubbles, unable to contact the rest of the solvent, resulting in poor mass transfer of acid gas from the gas to the amine solution. In terms of mechanical damage, if trays are broken or have fallen, there may not be enough contact zones (trays) for adequate sweetening. If the trays are plugged, there is less contact between the gas and liquid on each tray, resulting in poorer sweetening. WWW.GBHENTERPRISES.COM Typic a l Am ine Syst e m Ope rat ing Diffic ult ie s Failure to Meet Gas Specification II Other explanations for off-specification gas may be related to the amine solution:  The circulation rate may be too low,  The amine concentration too low,  The lean solution temperature may be too high,  The acid gas loading in the lean solution may be too high. Monoethanolamine systems usually run with solution concentrations between 10 and 20 weight percent MEA, and a lean loading of 0.1 moles acid gas/mole of MEA. WWW.GBHENTERPRISES.COM Typic a l Am ine Syst e m Ope rat ing Diffic ult ie s Failure to Meet Gas Specification III Diethanolamine systems are between 20 and 30 weight percent DEA, with lean loadings of 0.02 to 0.05 moles acid gas/mole DEA. In order to reach these lean loadings, regeneration resulting in a steamto-acid gas ratio ranging from 1:1 to 3:1 (moles steam: moles acid gas) in the stripper overhead gas is usually required (1). In some cases, even higher ratios may be necessary to bring the loading down, as in lowpressure treating applications. WWW.GBHENTERPRISES.COM Typic a l Am ine Syst e m Ope rat ing Diffic ult ie s Failure to Meet Gas Specification IV One way to estimate the overhead steam-to-acid gas ratio, knowing the stripper overhead temperature and pressure, is to use steam table data and Raoult's law: PP H2O = x H2O psat where: PP H2O = partial pressure of water in the overhead gas; X H2O = mole fraction of water in the amine solvent; psat = vapor pressure of pure water at the temperature of the overhead gas. WWW.GBHENTERPRISES.COM Typic a l Am ine Syst e m Ope rat ing Diffic ult ie s Failure to Meet Gas Specification V Approximating the overhead gas as an ideal gas containing water, H2S and C02, the partial pressure of the acid gases can be obtained by subtracting the partial pressure of water, calculated from Raoult's law, from the stripper overhead pressure: PPacid gas = Poverhead – PP H2O The ratio of water partial pressure to acid gas partial pressure is equal to the mole ratio of steam to acid gas. WWW.GBHENTERPRISES.COM Typic a l Am ine Syst e m Ope rat ing Diffic ult ie s Failure to Meet Gas Specification VI As an example calculation of the steam-to-acid gas ratio, a stripper with an overhead temperature and pressure of 200'F and 20 psia, carrying a 27 weight percent (6 mole percent) DEA solvent, has a corresponding water vapor pressure of 11.5 psia as obtained from the steam tables. From Raoult's law, the partial pressure of water is 10.8 psia: PPH2 0 = (0.94) (11.5) = 10.8 psia The partial pressure of acid gas would be 20 psia less 10.3 psia or 9.19 psia, and the overhead steam-to-acid gas ratio would be 1.2 moles steam/mole acid gas (10.8 -t 9.19). WWW.GBHENTERPRISES.COM Typic a l Am ine Syst e m Ope rat ing Diffic ult ie s Foaming Failure to Meet Gas Specification Solvent Losses Corrosion WWW.GBHENTERPRISES.COM Typic a l Am ine Syst e m Ope rat ing Diffic ult ie s Solvent Losses Amine losses are largely through entrainment, caused by foaming or excessive gas velocities, and by leakage due to spills or corrosion. In MEA units the reclaimer bottoms disposal significantly adds to the makeup requirement. On a much smaller scale are vaporization losses from the absorber, the overhead condenser, and the flash tank, and degradation losses by chemical and thermal degradation WWW.GBHENTERPRISES.COM Typic a l Am ine Syst e m Ope rat ing Diffic ult ie s Foaming Failure to Meet Gas Specification Solvent Losses Corrosion WWW.GBHENTERPRISES.COM Typic a l Am ine Syst e m Ope rat ing Diffic ult ie s Fa c t ors in Corrosion WWW.GBHENTERPRISES.COM Typic a l Am ine Syst e m Ope rat ing Diffic ult ie s Corrosion I Corrosion is a problem experienced by many alkanolamine gas sweetening plants. When loaded with C02 and H2S, aqueous amine solutions can become corrosive to carbon steel. Corrosion rates are increased by high amine concentration, high acid gas loading, high temperatures, degradation products, and foaming. Also corrosive are acid gases flashed from solution. WWW.GBHENTERPRISES.COM Typic a l Am ine Syst e m Ope rat ing Diffic ult ie s Corrosion II Monoethanolamine is more reactive than diethanolamine and similarly more corrosive. As a result, the concentration of MEA is restricted to 10 to 20 weight percent, while DEA strengths range from 20 to 30 weight percent. Rich solution loadings are normally limited to the range of 0.25 to 0.45 moles acid gas/mole MEA, while in DEA systems loadings may range from 0.5 to 0.6 moles acid gas/mole DEA. The corrosiveness of a loaded amine solution is strongly influenced by the relative proportion Of C02 to H2S in the feed gas. C02 is more corrosive to carbon steel than is H2S in aqueous systems. WWW.GBHENTERPRISES.COM Typic a l Am ine Syst e m Ope rat ing Diffic ult ie s Corrosion III Thus, for gases containing a higher ratio Of C02 to H2S, the rich acid gas loading should be maintained at the lower end of the recommended loading range. In cases where the feed gas is predominantly H2S, loadings at the higher end of the loading range may be acceptable. In terms of design, a number of measures can be taken to minimize corrosion. Solution velocities should not exceed 3 or 3.5 ft/sec. WWW.GBHENTERPRISES.COM Typic a l Am ine Syst e m Ope rat ing Diffic ult ie s Corrosion IV The rich solution should be on the tube side of the lean/rich heat exchanger, and pressure should be maintained on the exchanger to prevent acid gases from flashing, creating an erosion/corrosion cycle. A low temperature heating medium should be used in the reboiler, thereby preventing accelerated corrosion rates and thermal degradation of the amine. All equipment should be stress relieved. WWW.GBHENTERPRISES.COM Typic a l Am ine Syst e m Ope rat ing Diffic ult ie s Corrosion V There are certain areas of amine sweetening plants which are more susceptible to corrosion than others, and, as a result, are often constructed of corrosion-resistant materials such as Type 304 stainless steel. These areas include: 1) the lean/rich heat exchanger tube bundle, 2) the reboiler tube bundle, 3) the stripping column, particularly the upper section and overhead gas line, 4) the reflux condenser, and 5) the rich solvent let-down valve and subsequent piping to the stripper. WWW.GBHENTERPRISES.COM Typical Amine System Improvements Several Key Operating Parameters that can Help maintain good Operation (Click here for full size Table) WWW.GBHENTERPRISES.COM Am ine s: Ga s Tre at ing De gra dat ion of Am ine s a nd Alk a nola m ine s during Sour Ga s Sw e e t e ning WWW.GBHENTERPRISES.COM AM I N ES GAS T REAT I N G Be st Pra c t ic e s Guide Cont e nt s De gra dat ion of Am ine s a nd Alk a nola m ine s during Sour Ga s Tre at ing Figure 1. Sour gas sweetening process Figure 2. Causes of amine degradation Figure 3. Problems irreversible degradation reaction Figure 4. Foam formations in the interior of the stripper by degradation products Figure 5. Foam formations by degradation products Figure 6. Crevice corrosion in the junction of pipelines Figure 7. Pitting corrosion occurring at the end of the pipe junction Figure 8. Fouling effect in the pipe line of gas sweetening plant Figure 9. CO2 induced degradation of MEA Figure 10. Reaction responsible for the degradation of DEA by C02 Figure 11. CO2 induced degradation of PZ and MDEA WWW.GBHENTERPRISES.COM AM I N ES GAS T REAT I N G Be st Pra c t ic e s Guide Cont e nt s De gra dat ion of Am ine s a nd Alk a nola m ine s during Sour Ga s Tre at ing Table 1. Degradation products of MEA induced by CO2 Table 2. Degradation products of MEA induced by CO2 and O2 Table 3. Degradation products of DEA induced by CS2 WWW.GBHENTERPRISES.COM Simplified amine gas sweetening PFD WWW.GBHENTERPRISES.COM Am ine s: Ga s Tre at ing CAUSES OF AMINE DEGRADATION WWW.GBHENTERPRISES.COM Am ine s: Ga s Tre at ing EFFECT OF DEGRADATION PRODUCTS WWW.GBHENTERPRISES.COM Am ine s Ga s Tre at ing Foam formations in the interior of the stripper by degradation products WWW.GBHENTERPRISES.COM Am ine s Ga s Tre at ing Foam formations by degradation products WWW.GBHENTERPRISES.COM Am ine s: Ga s Tre at ing Crevice corrosion in the junction of pipelines WWW.GBHENTERPRISES.COM Am ine s: Ga s Tre at ing Pitting corrosion occurring at the end of the pipe junction WWW.GBHENTERPRISES.COM Am ine s: Ga s Tre at ing Fouling effect in the pipe line of gas sweetening plant WWW.GBHENTERPRISES.COM Am ine s: Ga s Tre at ing CO 2 I nduc e d De gra dat ion of M EA WWW.GBHENTERPRISES.COM Am ine s: Ga s Tre at ing Major problems associated with chemical absorption using alkanolamines Degradation through irreversible side reactions With CO2, H2S and O2 leads to numerous problems with the process:      solvent loss foaming fouling increased viscosity corrosion WWW.GBHENTERPRISES.COM Am ine s: Ga s Tre at ing CO 2 induc e d de gra dat ion of M EA WWW.GBHENTERPRISES.COM Am ine s: Ga s Tre at ing Degradation products of MEA induced by CO2 WWW.GBHENTERPRISES.COM Am ine s: Ga s Tre at ing Degradation products of MEA induced by CO2 and O2 WWW.GBHENTERPRISES.COM Am ine s: Ga s Tre at ing De gra dat ion of DEA a nd it s ble nds WWW.GBHENTERPRISES.COM Am ine s: Ga s Tre at ing Degradation products of DEA and DEA blend DEA is a secondary alkanolamine, it has a reduced affinity to reaction with H2S and CO2. WWW.GBHENTERPRISES.COM Am ine s: Ga s Tre at ing Reaction responsible for the degradation of DEA by C02 WWW.GBHENTERPRISES.COM Am ine s: Ga s Tre at ing Degradation products of DEA induced by CS2 Table 3. WWW.GBHENTERPRISES.COM Am ine s: Ga s Tre at ing CO 2 induced degradation of PZ and MDEA Figure 11. WWW.GBHENTERPRISES.COM Am ine s: Ga s Tre at ing APPENDIX WWW.GBHENTERPRISES.COM Am ine s: Ga s Tre at ing Be st Pra c t ic e s - Trouble shoot ing Guide WWW.GBHENTERPRISES.COM Am ine s: Ga s Sw e e t e ning WWW.GBHENTERPRISES.COM Refinery Process Stream Purification Refinery Process Catalysts Troubleshooting Refinery Process Catalyst Start-Up / Shutdown Activation Reduction In-situ Ex-situ Sulfiding Specializing in Refinery Process Catalyst Performance Evaluation Heat & Mass Balance Analysis Catalyst Remaining Life Determination Catalyst Deactivation Assessment Catalyst Performance Characterization Refining & Gas Processing & Petrochemical Industries Catalysts / Process Technology - Hydrogen Catalysts / Process Technology - Ammonia Catalyst / Process Technology - Methanol Catalysts / process Technology – Petrochemicals Specializing in the Development & Commercialization of New Technology in the Refining & Petrochemical Industries Web Site: www.GBHEnterprises.com Refinery Process Stream Purification Refinery Process Catalysts Troubleshooting Refinery Process Catalyst Start-Up / Shutdown Activation Reduction In-situ Ex-situ Sulfiding Specializing in Refinery Process Catalyst Performance Evaluation Heat & Mass Balance Analysis Catalyst Remaining Life Determination Catalyst Deactivation Assessment Catalyst Performance Characterization Refining & Gas Processing & Petrochemical Industries Catalysts / Process Technology - Hydrogen Catalysts / Process Technology - Ammonia Catalyst / Process Technology Methanol Catalysts / process Technology – Petrochemicals Specializing in the Development & Commercialization of New Technology in the Refining & Petrochemical Industries Web Site: www.GBHEnterprises.com Refinery Process Stream Purification Refinery Process Catalysts Troubleshooting Refinery Process Catalyst Start-Up / Shutdown Activation Reduction In-situ Ex-situ Sulfiding Specializing in Refinery Process Catalyst Performance Evaluation Heat & Mass Balance Analysis Catalyst Remaining Life Determination Catalyst Deactivation Assessment Catalyst Performance Characterization Refining & Gas Processing & Petrochemical Industries Catalysts / Process Technology - Hydrogen Catalysts / Process Technology - Ammonia Catalyst / Process Technology Methanol Catalysts / process Technology – Petrochemicals Specializing in the Development & Commercialization of New Technology in the Refining & Petrochemical Industries Web Site: www.GBHEnterprises.com Refinery Process Stream Purification Refinery Process Catalysts Troubleshooting Refinery Process Catalyst Start-Up / Shutdown Activation Reduction In-situ Ex-situ Sulfiding Specializing in Refinery Process Catalyst Performance Evaluation Heat & Mass Balance Analysis Catalyst Remaining Life Determination Catalyst Deactivation Assessment Catalyst Performance Characterization Refining & Gas Processing & Petrochemical Industries Catalysts / Process Technology - Hydrogen Catalysts / Process Technology - Ammonia Catalyst / Process Technology Methanol Catalysts / process Technology – Petrochemicals Specializing in the Development & Commercialization of New Technology in the Refining & Petrochemical Industries Web Site: www.GBHEnterprises.com Refinery Process Stream Purification Refinery Process Catalysts Troubleshooting Refinery Process Catalyst Start-Up / Shutdown Activation Reduction In-situ Ex-situ Sulfiding Specializing in Refinery Process Catalyst Performance Evaluation Heat & Mass Balance Analysis Catalyst Remaining Life Determination Catalyst Deactivation Assessment Catalyst Performance Characterization Refining & Gas Processing & Petrochemical Industries Catalysts / Process Technology - Hydrogen Catalysts / Process Technology - Ammonia Catalyst / Process Technology Methanol Catalysts / process Technology – Petrochemicals Specializing in the Development & Commercialization of New Technology in the Refining & Petrochemical Industries Web Site: www.GBHEnterprises.com Refinery Process Stream Purification Refinery Process Catalysts Troubleshooting Refinery Process Catalyst Start-Up / Shutdown Activation Reduction In-situ Ex-situ Sulfiding Specializing in Refinery Process Catalyst Performance Evaluation Heat & Mass Balance Analysis Catalyst Remaining Life Determination Catalyst Deactivation Assessment Catalyst Performance Characterization Refining & Gas Processing & Petrochemical Industries Catalysts / Process Technology - Hydrogen Catalysts / Process Technology - Ammonia Catalyst / Process Technology Methanol Catalysts / process Technology – Petrochemicals Specializing in the Development & Commercialization of New Technology in the Refining & Petrochemical Industries Web Site: www.GBHEnterprises.com Refinery Process Stream Purification Refinery Process Catalysts Troubleshooting Refinery Process Catalyst Start-Up / Shutdown Activation Reduction In-situ Ex-situ Sulfiding Specializing in Refinery Process Catalyst Performance Evaluation Heat & Mass Balance Analysis Catalyst Remaining Life Determination Catalyst Deactivation Assessment Catalyst Performance Characterization Refining & Gas Processing & Petrochemical Industries Catalysts / Process Technology - Hydrogen Catalysts / Process Technology - Ammonia Catalyst / Process Technology Methanol Catalysts / process Technology – Petrochemicals Specializing in the Development & Commercialization of New Technology in the Refining & Petrochemical Industries Web Site: www.GBHEnterprises.com Refinery Process Stream Purification Refinery Process Catalysts Troubleshooting Refinery Process Catalyst Start-Up / Shutdown Activation Reduction In-situ Ex-situ Sulfiding Specializing in Refinery Process Catalyst Performance Evaluation Heat & Mass Balance Analysis Catalyst Remaining Life Determination Catalyst Deactivation Assessment Catalyst Performance Characterization Refining & Gas Processing & Petrochemical Industries Catalysts / Process Technology - Hydrogen Catalysts / Process Technology - Ammonia Catalyst / Process Technology Methanol Catalysts / process Technology – Petrochemicals Specializing in the Development & Commercialization of New Technology in the Refining & Petrochemical Industries Web Site: www.GBHEnterprises.com Refinery Process Stream Purification Refinery Process Catalysts Troubleshooting Refinery Process Catalyst Start-Up / Shutdown Activation Reduction In-situ Ex-situ Sulfiding Specializing in Refinery Process Catalyst Performance Evaluation Heat & Mass Balance Analysis Catalyst Remaining Life Determination Catalyst Deactivation Assessment Catalyst Performance Characterization Refining & Gas Processing & Petrochemical Industries Catalysts / Process Technology - Hydrogen Catalysts / Process Technology - Ammonia Catalyst / Process Technology Methanol Catalysts / process Technology – Petrochemicals Specializing in the Development & Commercialization of New Technology in the Refining & Petrochemical Industries Web Site: www.GBHEnterprises.com Refinery Process Stream Purification Refinery Process Catalysts Troubleshooting Refinery Process Catalyst Start-Up / Shutdown Activation Reduction In-situ Ex-situ Sulfiding Specializing in Refinery Process Catalyst Performance Evaluation Heat & Mass Balance Analysis Catalyst Remaining Life Determination Catalyst Deactivation Assessment Catalyst Performance Characterization Refining & Gas Processing & Petrochemical Industries Catalysts / Process Technology - Hydrogen Catalysts / Process Technology - Ammonia Catalyst / Process Technology Methanol Catalysts / process Technology – Petrochemicals Specializing in the Development & Commercialization of New Technology in the Refining & Petrochemical Industries Web Site: www.GBHEnterprises.com Refinery Process Stream Purification Refinery Process Catalysts Troubleshooting Refinery Process Catalyst Start-Up / Shutdown Activation Reduction In-situ Ex-situ Sulfiding Specializing in Refinery Process Catalyst Performance Evaluation Heat & Mass Balance Analysis Catalyst Remaining Life Determination Catalyst Deactivation Assessment Catalyst Performance Characterization Refining & Gas Processing & Petrochemical Industries Catalysts / Process Technology - Hydrogen Catalysts / Process Technology - Ammonia Catalyst / Process Technology Methanol Catalysts / process Technology – Petrochemicals Specializing in the Development & Commercialization of New Technology in the Refining & Petrochemical Industries Web Site: www.GBHEnterprises.com Refinery Process Stream Purification Refinery Process Catalysts Troubleshooting Refinery Process Catalyst Start-Up / Shutdown Activation Reduction In-situ Ex-situ Sulfiding Specializing in Refinery Process Catalyst Performance Evaluation Heat & Mass Balance Analysis Catalyst Remaining Life Determination Catalyst Deactivation Assessment Catalyst Performance Characterization Refining & Gas Processing & Petrochemical Industries Catalysts / Process Technology - 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Hydrogen Catalysts / Process Technology - Ammonia Catalyst / Process Technology Methanol Catalysts / process Technology – Petrochemicals Specializing in the Development & Commercialization of New Technology in the Refining & Petrochemical Industries Web Site: www.GBHEnterprises.com Refinery Process Stream Purification Refinery Process Catalysts Troubleshooting Refinery Process Catalyst Start-Up / Shutdown Activation Reduction In-situ Ex-situ Sulfiding Specializing in Refinery Process Catalyst Performance Evaluation Heat & Mass Balance Analysis Catalyst Remaining Life Determination Catalyst Deactivation Assessment Catalyst Performance Characterization Refining & Gas Processing & Petrochemical Industries Catalysts / Process Technology - Hydrogen Catalysts / Process Technology - Ammonia Catalyst / Process Technology Methanol Catalysts / process Technology – Petrochemicals Specializing in the Development & Commercialization of New Technology in the Refining & Petrochemical Industries Web Site: www.GBHEnterprises.com Refinery Process Stream Purification Refinery Process Catalysts Troubleshooting Refinery Process Catalyst Start-Up / Shutdown Activation Reduction In-situ Ex-situ Sulfiding Specializing in Refinery Process Catalyst Performance Evaluation Heat & Mass Balance Analysis Catalyst Remaining Life Determination Catalyst Deactivation Assessment Catalyst Performance Characterization Refining & Gas Processing & Petrochemical Industries Catalysts / Process Technology - Hydrogen Catalysts / Process Technology - Ammonia Catalyst / Process Technology Methanol Catalysts / process Technology – Petrochemicals Specializing in the Development & Commercialization of New Technology in the Refining & Petrochemical Industries Web Site: www.GBHEnterprises.com Refinery Process Stream Purification Refinery Process Catalysts Troubleshooting Refinery Process Catalyst Start-Up / Shutdown Activation Reduction In-situ Ex-situ Sulfiding Specializing in Refinery Process Catalyst Performance Evaluation Heat & Mass Balance Analysis Catalyst Remaining Life Determination Catalyst Deactivation Assessment Catalyst Performance Characterization Refining & Gas Processing & Petrochemical Industries Catalysts / Process Technology - Hydrogen Catalysts / Process Technology - Ammonia Catalyst / Process Technology Methanol Catalysts / process Technology – Petrochemicals Specializing in the Development & Commercialization of New Technology in the Refining & Petrochemical Industries Web Site: www.GBHEnterprises.com Am ine s: Ga s Tre at ing WWW.GBHENTERPRISES.COM Am ine s: Ga s Tre at ing WWW.GBHENTERPRISES.COM Am ine s: Ga s Tre at ing WWW.GBHENTERPRISES.COM Am ine s: Ga s Tre at ing WWW.GBHENTERPRISES.COM Am ine s: Ga s Tre at ing WWW.GBHENTERPRISES.COM Am ine s: Ga s Tre at ing WWW.GBHENTERPRISES.COM Am ine s: Ga s Tre at ing WWW.GBHENTERPRISES.COM Am ine s: Ga s Tre at ing Re fe re nc e List 1. 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Catalyst information from Johnson Matthey Group, “Absorbent for Sulphur Polishing,” available at http://www.synetix.com/refineries/pdfs/manuals/669w.pdf WWW.GBHENTERPRISES.COM Am ine s: Ga s Tre at ing Re fe re nc e List 14. Watson, J., Jones, K., “Removing H2S from Syngas Using Proven Technology in Japanese Waste Gasification Facility,” available at http://www.gtp-merichem.com/ support/technical_papers 15. Douglas L. Heguy, Gary J. Nagl, “The State of Iron Redox Sulfur Plant Technology New Developments to an Established Technology,” available at http://www.gtp-merichem.com/support/technical_papers 16. Dortmundt, D., Doshi, K., “Recent Developments in CO2 Removal Membrane Technology,” 1999. 17. Edwards, M.S., “H2S Removal Processes for Low-Btu Coal Gas,” prepared by Oak Ridge National Laboratory, Oak Ridge, Tennessee, for the Department of Energy/Fossil Energy Office of Program Planning and Analysis, Contract No. W-7405-eng-26, January 1979. 18. Tennyson & Schaaf, “Guidelines Can Help Choose Proper Process for Gas Treating Plants,” Oil and Gas Journal, January 1977. 19. W. Breckenridge, A. Holiday, J. Ong and C. Sharp “Use of SELEXOL Process in Coke Gasification to Ammonia Project” Laurance Reid Gas Conditioning Conference, February 17, 2000. WWW.GBHENTERPRISES.COM Am ine s: Ga s Tre at ing Re fe re nc e List 20. Degradation studies of amines and alkanolamines during sour gas treatment process M. S. Islam, R. Yusoff, B. S. Ali1*, M. N. Islam and M. H. Chakrabarti Department of Chemical Engineering, Faculty of Engineering, University of Malaya, 50603 Kuala Lumpur, Malaysia. Department of Chemistry, Faculty of Engineering, Bangladesh University of Engineering and Technology (BUET), Dhaka-1000, Bangladesh. 21. DOW Technical Article : Gas Sweetening Reprint: Printed 1998 Gas Sweetening 22. Amine Best Practices Group WWW.GBHENTERPRISES.COM