SYNTHETIC NATURAL GAS PLANT. Philadelphia, PA

SYNTHETIC NATURAL GAS PLANT Philadelphia, PA

SYNTHETIC NATURAL GAS PLANT The SNG facility was constructed in 1977 but has seen very little operational activity. The SNG Facility employs the British Gas hydro gasification process to convert naphtha feedstock into SNG at a design rate of 60,000 decatherms per day, and was constructed by Foster Wheeler Energy Corporation. The principle areas of the plant that are offered for sale are as follows: Hydrogen Plant: Produces 5.9 MMSCFD of 99+% of Hydrogen using British Hydro-Gasification Desulphurization Plant: Treats up to 117,500 lbs/hr of 2000 ppm Sulfur to a Sulfur Content Reduced to 5ppm Deionization Plant: Treats 350 GPM Complete with Cation Beds, Anion Beds, Deionization Beds, Carbon Vessels, Pumps & Regeneration System. Philadelphia, PA

Hydrogen Plant: Catalytic Rich Gas: Section 200 The CRG process employs the British Gas hydro gasification concept. Full capacity standby reactors are available for the first stage (CRG) reactor and the second (hydro gasification) reactor. Supplemental equipment is available for shut down and start up operations and for catalyst reductions. Hydrogen is produced in the CRG section by combining rich gas or natural gas with superheated steam over nickel catalyst beds in a hydrogen reformer which has a capacity of 5.9 MMSCFD of hydrogen. A Benfield hot potassium carbonate process accomplishes CO2 removal. A PSA purification skid is available for this H2 plant that elevates H2 purity to 99.9% or higher, if desired.

Hydrogen Plant: Catalytic Rich Gas: Section 200 Reactors: Reactor Function Size Design Temp Design PSI Normal Temp Normal PSI R-201 Sulfur Hydrogenator 8'ID x 62'3" 800 540 752 490 R-202 Sulfur Absorber 7'6"ID x 32'3" 800 540 752 490 R-204A 1st Stage Rich Gas Reactor 7'ID x 11'6" 1040 420 1010 375 R-204B Spare 7'ID x 11'6" 1040 420 1010 375 R-205A 2nd Stage Gas Rich Reactor 10'ID x 9'6" 965 420 941 345 R-205B Spare 10'ID x 9'6" 965 420 941 345 R-206 R-207 R-208 R-209 3rd Stage Rich Gas Reactor Recycle Gas Converter Recycle Gas Methanator Pipe Line Gas Sulfur Absorber 8'ID x 7'6" 840 375 727 305 6'5"ID x 17'4" 750 330 700 297 3'6"ID x 7' 850 330 700 300 3'ID x 10'2" 800 425 700 385 R-210 Carbon Drum 3'6"ID x 10'6" 700 440 650 400 Vessels

Hydrogen Plant: Catalytic Rich Gas: Section 200 R-201: Sulphur Hydrogenator R-205A: 2 nd Stage Gas Rich Reactor R-202: Sulphur Absorber Vessels R-207: Recycle Gas Converter

Hydrogen Plant: Catalytic Rich Gas: Section 200 Towers: Tower Function Size T-201 T-202 Rich Gas CO2 Absorber Recycle Gas CO2 Absorber Design Temp Design PSI Normal Temp Normal PSI 10'/7' x 114' 345 330 295 300 3'/3' x 110'6" 345 335 275 330 T-203 Carbonate Regenerator 12'6"ID x 141'6" 300 60 250 10 Vessels

Hydrogen Plant: Catalytic Rich Gas: Section 200 T-201: Rich Gas CO 2 Absorber T-203: Carbonate Regenerator T-202: Recycle Gas CO 2 Absorber Vessels

Hydrogen Plant: Catalytic Rich Gas: Section 200 Drums: Tank Function Design Temp Vessels Desig n PSI Normal Temp Normal PSI D-201 Process Steam Drum 650 151 460 450 D-202 3rd Stage Reactor Drum 330 330 282 300 D-203 Rich Gas Absorber Feed KO Drum 335 375 284 340 D-204 Re-boiler KO Drum 335 375 284 340 D-205 Product Gas KO Drum 160 330 110 300 D-206 Reformer Steam Drum 510 525 460 450 D-207 Recycle CO Converter Eff DO Drum 410 334 360 289 D-208 Recycle Absorber Feed KO Drum 320 332 270 330 D-209 Recycle Gas KO Drum 160 332 120 254 D-211 Regenerator Overhead DO Drum 210 50 162 5 D-212 Startup Cooler KO Drum 190 278 140 250 D-213 Feed Return DO Drum 210 543 140 435 D-214 Carbonate Flash Drum 290 50 236 8 D-215 2nd Stage KO Drum 400 375 369 340 D-216 Recycle Absorber Overhead KO Drum 210 333 150 279 D-217 Pipeline Gas KO Drum 150 165 100 140

Hydrogen Plant: Catalytic Rich Gas: Section 200 D-202: 3 rd Stage Reactor Drum D-205: Product Gas KO Drum D-203: Rich Gas Absorber Feed KO Drum Vessels

Hydrogen Plant: Catalytic Rich Gas: Section 200 D-204: Re-boiler KO Drum D-211: Regenerator Overhead DO Drum D-205: Product Gas KO Drum Vessels

Hydrogen Plant: Catalytic Rich Gas: Section 200 Shell/Tube Exchangers: Tank Function Shell Fluid Shell Temp F Shell Pressure Tube Fluid Tube Temp F Tube Pressure E-201 1st Stage Waste Heat Exchanger BFW/Stm 460/460 525/520 Syn Gas 1018/808 420/415 E-202 2nd Stage Waste Heat Exchanger BFW/Stm 460/460 525/520 Syn Gas 935/735 375/370 E-203 Rich Gas LP Steam Generator BFW/Stm 298/298 50/50 Rich Gas 535/236 318/313 E-204 3rd Stage Feed Pre Heat Exchanger Rich Gas 284/572 307/303 Rich Gas 682/445 322/313. 5 E-205 Carbonate Re-boiler Carb.Sol. 236/236 8/8 Rich Gas 328/284 312/308 E-206 3rd Stage Waste Heat Exchanger BFW/Stm 460/460 525/520 Reac.Eff 686/500 203/288 E-207 3rd Stage Feed Water Exchanger BFW 228/403 710/701 Rich Gas 500/282 288/284 E-210 Reformer Gas Waste Heat Exchanger BFW/Stm 460/460 650/645 Ref. Gas 1382/655 330/325 E-211 Recycle Gas LP Stm Generator BFW/Stm 298/298 50/50 Conv. Gas 700/369 262/258 E212 E-213* Treated Water Pre Heater Recycle Meth. FIP Exchanger Treated Water Scrubbed Rec. Gas 60/155 140/130 Conv. Gas 360/270 286/284 158/482 278/274 E-214 Recycle Meth. Startup Heater Nitrogen 750/650 200/195 Meth. Rec. Gas Scrubbed Gas 700/369 262/258 350/482 274/269 Exchangers

Hydrogen Plant: Catalytic Rich Gas: Section 200 E-202: 2 nd Stage Waste Heat Exchanger E-205: Carbonate Re-boiler E-210: Reformer Gas Waste Heat Exchanger E-211: Recycle Gas LP Steam Generator Exchangers

Hydrogen Plant: Catalytic Rich Gas: Section 200 Air Cooled Exchangers: Air Side Design Tank Function Temp In Temp Out Fluid Tube Temp F Tube Pressure E-208 Rich Gas Absorber feed Cooler 75 193 Rich Gas 282/270 282/278 E-209 Product Gas Cooler 75 96.1 Prod. Gas 156/110 267/163 E-215 Recycle Gas Cooler 75 114.1 Recycle Gas 369/120 258/254 E-216 Regenerator Overhead Condenser 75 127.9 CO2 + Steam 242/159 5/1 E-220 Startup Cooler 75 137.9 Nitrogen 932/140 245/240 E-220 Startup Cooler 75 164.7 H2+CH4+Steam 752/140 410/405 E-221 Feed Return Condenser 75 142.6 Nap+Recy.Gas 752/140 280/275 E-221 Feed Return Condenser 75 144.9 Pipeline Gas 752/140 405/395 E-222 Carbonate Solution Cooler 75 139.3 Carb. Solution 222/158 405/395 E-223 Recycle Gas Trim Cooler 75 180.2 Converter Gas 360/270 286/284 E-224 Pipeline Gas Compressor After Cooler Tube Normal (Inlet/Outlet) 75 92.8 Nat. Gas 370/100 398/395 Exchangers

Hydrogen Plant: Catalytic Rich Gas: Section 200 E-209: Product Gas Cooler E-220: Start-up Cooler E-222: Carbonate Solution Center E-224: Pipeline Gas Compressor Air Cooler Exchangers

Hydrogen Plant: Catalytic Rich Gas: Section 200 Pumps: Pump Function Normal GPM Desig n GPM Pumping Temp Suction Pressure Discharge Pressure Driver Motor HP P-201A Carb. Circ. Pump 3532 3885 222 19.7 410 1500 + 1.0 SF P-201B Spare 3532 3885 222 19.7 410 1500 + 1.0 SF P-203A Regenerator Reflux 116 150 159 2.8 114 25 + 1.0 SF P-203B Spare 116 150 159 2.8 114 25 + 1.0 SF P-206 Carbonate Transfer 60 72 150 16 45 7.5 + 1.0 SF P-207 Carbonate Sump Pump 60 72 200 4 56 10 + 1.0 SF Pumps

Hydrogen Plant: Catalytic Rich Gas: Section 200 P-201A: Carbonate Circulation Pump P-201B: Spare P-203A: Regenerator Reflux Pumps P-203B: Spare

Hydrogen Plant: Catalytic Rich Gas: Section 200 Compressors: Tank Function Capacity # Hr Normal Capacity # HR Design Temp Sucti on Temp Discharge Pressur e Suction Pressure Discharg e Driver Motor HP C-201A C-201B Recycle Hydrogen Compressor Spare 1443 # HR 1443 # HR C-202 Startup Compressor ----- C-203A C-203B C-204 Methane Recirc. Compressor Methane Recirc. Compressor Pipeline Gas Compressor ----- ---- ---- 1676 # HR 1676 # HR 23,790 # HR 21,300 # HR 21,300 # HR 2675 # HR 120 243 268 559.6 500 + 1.15 SF 120 243 268 559.6 500 + 1.15 SF 140 220 200 250 250 + 1.15 SF 110 145 280 329 400 + 1.05 SF 145 180 327 383.7 400 + 1.05 SF 80 140 110 50 200 Compressors

Hydrogen Plant: Catalytic Rich Gas: Section 200 C-202: Start-up Compressor C-203A: Methane Re-circulation Compressor C-204: Pipeline Gas Compressor Compressors

Naphtha Hydrodesulphurization Plant Section 100 Vessels: This plant provides a water wash system to remove possible salt contaminants from raw naphtha feedstock. A deaerator is also present in this section to strip dissolved oxygen from the naphtha feedstock. The HDS section will treat up to 117,500 lbs/hr of heavy naphtha of 2000 ppm sulfur to a sulfur content reduced to 5 ppm.

Naphtha Hydrodesulphurization Plant: Section 100 Vessels: Vessels: Tank Function Size D-101 Separator D-102 Naphtha Stripper Overhead Drum 7' ID x 22.5' Boot 5' ID x 16.5' Boot Design Temp Design PSI Normal Temp Normal PSI 200 F 417 110 F 375 200 F 135 100 F 90 D-103 Water Wash Drum 6.5' ID x 26' 200 F 180 80 F 25 D-104 Sour Water Receiver 5' ID x 15' 510 F 104 460F 50 D-105 R-101 Compressor Suction Drum Desulphurization Reactor 3' ID x 6' 160 F 416 110 F 375 7' ID x 22.5' 200 F 417 110 F 375 T-101 Tower 8' ID x 38'7.5"" 150F 93 NA NA T-102 Tower 7'6"ID x 85'1.5" 515F 146 NA NA Vessels

Naphtha Hydrodesulphurization Plant: Section 100 Vessels Vessels: D-101: Separator D-102: Naphtha Stripper D-103: Water Wash Drum

Naphtha Hydrodesulphurization Plant: Section 100 Vessels Vessels: D-104: Sour Water Receiver

Naphtha Hydrodesulphurization Plant: Section 100 Shell/Tube Exchangers: Tank Function Shell Fluid Shell Temp F Shell Pressure Tube Fluid Tube Temp F Tube Pressure E-101A E-101B E-101C E-101D E-103A/B E-105 Reactor Effluent Feed Exchanger Reactor Effluent Feed Exchanger Reactor Effluent Feed Exchanger Reactor Effluent Feed Exchanger Naptha Stripper Bottoms Feed Exchanger Naptha Feed Preheater H.C.* 503/605 464 H.C.* 750/612 384 H.C.* 400/503 468 H.C.* 612/508 380 H.C.* 255/400 472 H.C.* 508/404 376 H.C.* 70/255 476 H.C.* 404/260 372 H.C.* 110/340 150 H.C.* 439/241 115 Steam 330/275 50 H.C.* 5/70 80 Exchangers

Naphtha Hydrodesulphurization Plant: Section 100 Exchangers Vessels: E-101A: Reactor Effluent Feed Exchanger E-101B: Reactor Effluent Feed Exchanger E-103A/B: Naphtha Stripper Bottom Feed Exchanger E-105: Naphtha Feed Pre-heater

Naphtha Hydrodesulphurization Plant: Section 100 Vessels: Air Cooled Exchangers: Tank Function Temp In Temp Out Fluid E-102 E-104 E-106 Reactor Effluent Cooler Naphtha Striper Overhead Condenser Desulphfurized Naphtha Cooler Tube Temp F Tube Pressure 75 144 H.C.* 275/110 367 75 117 H.C.* 144/100 100 75 106 H.C.* 241/100 90 Exchangers

Naphtha Hydrodesulphurization Plant: Section 100 Exchangers Vessels: E-102: Reactor Effluent Cooler E-104: Naphtha Stripper Overhead Condenser E-106: Desulphurized Naphtha Cooler

Naphtha Hydrodesulphurization Plant: Section 100 Pumps Vessels: Pumps: Tank P-101A/B Function Naphtha De-aerator GPM Norm al Design GPM Pumping Temp Suction Pressure Discharge Pressure Driver Motor HP 369 406 100 26 114.3 30 P-102A/B Reactor Stripper 368 405 100 64 572 250 P-103A/B P-104A/B P-105 P106A Naphtha Stripper Reflux Pump Naphtha Stripper Bottoms Pump Water Circulation Pump Naphtha Stripper Re-boiler Pump 208 250 100 92 150 20 400' 440 193 89 600 300 180 198 100 25 75 10 1545 1700 278 109 210 200

Naphtha Hydrodesulphurization Plant: Section 100 Pumps Vessels: P-101A/B: Naphtha De-aerator P-103A/B:Naphtha Stripper Reflux Pump P-104A:Naphtha Stripper Bottoms Pump P-104B:Naphtha Stripper Bottoms Pump

Naphtha Hydrodesulphurization Plant: Section 100 Pumps P106A: Naphtha Stripper Re-boiler Pump Vessels:

Naphtha Hydrodesulphurization Plant: Section 100 Compressors & Mixers Vessels: Compressors: Tank C-101A/B Function HDS Recycle Compressor Capacity ACFM Capacity Lb/Min Temp Suction Temp Discharge Pressure Suction Pressure Discharge 369 406 100 26 114.3 30 Driver Motor HP 500 1.15 Safety Factor Mixers: Mixer Water Flow Naptha Flow Pressure Drop (Normal) Operating Pressure Operating Temp M-101 198 GPM Max 406 GPM Max 14 PSI 75 Psig 100F

Naphtha Hydrodesulphurization Plant: Section 100 Compressors & Mixers Vessels: C-101A: HDS Recycle Compressor C-101B: HDS Recycle Compressor

Stretford Sulphur Recovery The bulk of the sulfur in the plant naphtha feed is removed in the hydrodesulphurization (HDS) unit, the sweet naphtha going to the SNG unit and the sulfur leaving the HDS unit as H2S in the sour gas purge. The sour gas, composed of mainly light hydrocarbons, is burnt in the plant fuel system. In order to reduce pollution of the atmosphere by combustion products to an absolute minimum, the H2S is removed from the sour gas before combustion, by the Stretford Process. The Stretford Process was developed by the North Western Gas Board, now part of the British Gas Corporation, who license the process. The Stretford Process for H2S removal is by continuous liquid washing using an adequate alkaline solution containing dyestuff intermediates. The H2S+O is converted to elemental sulfur, which is separated from the solution, washed to remove the solution from the sulfur cake, and stored ready for disposal. The Stretford Unit that we are offering is designed to treat 78.71 lb. mol/hr of sour gas containing up to 7.34 lb. mols of H2S and to reduce the H2S content of the sweet gas to less than 1 vppm. Alternatively, the unit can treat 148.92 lb. mols/hr of sour gas containing up to 1.84 lb. mols H2S. Section 150

Stretford Sulphur Recovery: Section 150 Reactor: Reactor Function Size Design Temp Design PSI Normal Temp Normal PSI R-151 Oxidizer 18' x 21' 140F Static Head 110F Atmosphere Tower: Tower Function Size Design Temp Design PSI Normal Temp Normal PSI T-151 H2S Absorber 10' x 4'6" x 90'6" 140F 75F 110F 40 Tanks: Tank Function Size Design Temp Design PSI Normal Temp Normal PSI TK-151 Pumping Tank 14'6" x 15' 140 Static Head 110F Atmosphere TK-152 Slurry Tank 12' x 12' 140 Static Head 110F Atmosphere TK-153 Decanter Tank 10'9" x 7' 140 Static Head 110F Atmosphere TK-154 Filtrate Tank 5' x 6' 140 Static Head 110 F Atmosphere TK-155 Reagent Tank 5' x 6' 140 Static Head 110 F Atmosphere TK-156 HC Flash Tank 8' x 15' 140 25 110F 2 PSIG Vessels

Stretford Sulphur Recovery: Section 150 TK-153: Decanter Tank TK-156: HC Flash Tank T-151: H2S Absorber Vessels

Stretford Sulphur Recovery: Section 150 P-151A/B: Solution Circulation Pumps P-152A: Slurry Feed Pump P-153A: Re-slurry Pump P-154: Filtrate Pump Pumps

Stretford Sulphur Recovery: Section 150 P-151A/B: Oxidizing Air Blowers Blowers

Deionization Plant 350GPM 2 Deionization beds (2) Vessels each 2 an-ion beds negative ion removal 2 cat-ion beds positive ions removal 2 Carbon Vessels (hydrocarbon removal carbon absorption units) 4 pumps Regeneration system- strips an-ions and cations off the resins designed for this unit Support facilities include drums, tanks, pumps, compressors, blowers, de-aerator, boilers, Electrical systems and a full demineralization plant/water treatment package. Section 300

Deionization Plant Tanks: Tank Function Capacity (gallons) TK-307 Treated Water 67,680 TK-308 Neut. Tank 44,616 TK-310 Cooling Water Surge Tank 8,550 Size 24' x 24' 15' x 33' 9" 9' x 18' Design Temp Design PSI Normal Temp Normal PSI 210 Atmosphere 160 Atmosphere 150 Atmosphere 120 Atmosphere 170 Atmosphere 120 Atmosphere Drums: Tank Function Design Temp Design PSI Normal Temp Normal PSI D-301 Air Receiver 450 135 120 115 D-302 Caustic Stage Drum 200 30 120 Atmosphere D-303 Acid Stage Drum 200 31 120 Atmosphere D-307 Fuel Gas KO Drum 160 56 110 30 D-308 Blow down Drum (Stm) 260 27 212 0 Section 300

Deionization Plant: Section 300 TK-307: Treated Water D-307: Fuel Gas KO Drum D-308: Blow Down Drum (Stm) TK-308: Neutralizing Tank Vessels

Deionization Plant: Section 300 Pumps: Pump Function GPM Normal Desig n GPM Pumps Pumping Temp Suction Pressure Discharge Pressure Driver Motor HP P-301A Treated Water Pump 295 354 40-110 Max -2 100 40 P-301B Spare 295 354 40-110 Max -2 100 40 P-309A Cooling Water Pump 325 325 120-2 51 20 P-309B Spare 325 325 120-2 51 20 P-311A Naptha Fuel Pump 61 85 30/95.07 155 30 P-311B Spare 61 85 30/95.07 155 30 P-319A BFW Pump 528 600 225 13.2 670 350 P-319B BFW Pump 528 600 225 13.2 670 350 P-320A* Hydrazine Pump 0-30 0-5.25 33-100 0 50.5 P-320B* Spare 0-30 0-5.25 33-100 0 50.5 P-321* P-322* Stm Gen Phosphate Pump Pro. Stm. Drum Phosphate Pump 0-30 0-5.25 33-100 0 50.5 0-30 0-5.25 33-100 0 590.5 P-323* Spare 0-30 0-5.25 33-100 0 590.5 P-329 Phos. to Proc. Stm. Drums 0-5 0-5.25 33-100 0 590.5

Deionization Plant: Section 300 P-309A: Cooling Water Pump P-311A: Naphtha Fuel Pump P-319A: BFW Pump P-319B: BFW Pump Pumps

Deionization Plant: Section 300 Compressors & Blowers: Tank Function Capacity ACFM Capacity Lb/Min Temp Suctio n Temp Discharge Pressure Suction Pressure Discharge Driver Motor HP C-301A/B Instrument/Plant Compressor & Spare 660 786 AMB 120 14.7 135 200 B-301A/B Forced Draft Fan ------ 21310 AMB AMB ATM 13" WC 40 B-302A/B Atomizing Air Blower ------ 575 AMB AMB ATM 13.5 40 Compressors/Blowers

Deionization Plant: Section 300 DH-301: De-Aerator De-Aerator

Deionization Plant: Section 300 Water Treatment Package: The water treatment package consists of carbon purifier, cation, anion, and mixed bed treatment. The equipment is capable of delivering 255,300 gallons per 24 hours at a maximum effluent flow rate of 354 gpm. See chart below for water effluent properties. Test Result Alkalinity 1 ng /L Total Hardness nil Sulfate nil Chloride nil Silica 0.05 ng /L Total Dissolved Solids 1ng/L H 2 O Treatment

Deionization Plant: Section 300 H 2 O Treatment

Flare Towers A-306

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