SYNTHETIC NATURAL GAS PLANT. Philadelphia, PA

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1 SYNTHETIC NATURAL GAS PLANT Philadelphia, PA

2 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

3 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.

4 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" R-202 Sulfur Absorber 7'6"ID x 32'3" R-204A 1st Stage Rich Gas Reactor 7'ID x 11'6" R-204B Spare 7'ID x 11'6" R-205A 2nd Stage Gas Rich Reactor 10'ID x 9'6" R-205B Spare 10'ID x 9'6" 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" '5"ID x 17'4" '6"ID x 7' 'ID x 10'2" R-210 Carbon Drum 3'6"ID x 10'6" Vessels

5 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

6 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' '/3' x 110'6" T-203 Carbonate Regenerator 12'6"ID x 141'6" Vessels

7 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

8 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 D-202 3rd Stage Reactor Drum D-203 Rich Gas Absorber Feed KO Drum D-204 Re-boiler KO Drum D-205 Product Gas KO Drum D-206 Reformer Steam Drum D-207 Recycle CO Converter Eff DO Drum D-208 Recycle Absorber Feed KO Drum D-209 Recycle Gas KO Drum D-211 Regenerator Overhead DO Drum D-212 Startup Cooler KO Drum D-213 Feed Return DO Drum D-214 Carbonate Flash Drum D-215 2nd Stage KO Drum D-216 Recycle Absorber Overhead KO Drum D-217 Pipeline Gas KO Drum

9 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

10 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

11 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/ /520 Syn Gas 1018/ /415 E-202 2nd Stage Waste Heat Exchanger BFW/Stm 460/ /520 Syn Gas 935/ /370 E-203 Rich Gas LP Steam Generator BFW/Stm 298/298 50/50 Rich Gas 535/ /313 E-204 3rd Stage Feed Pre Heat Exchanger Rich Gas 284/ /303 Rich Gas 682/ / E-205 Carbonate Re-boiler Carb.Sol. 236/236 8/8 Rich Gas 328/ /308 E-206 3rd Stage Waste Heat Exchanger BFW/Stm 460/ /520 Reac.Eff 686/ /288 E-207 3rd Stage Feed Water Exchanger BFW 228/ /701 Rich Gas 500/ /284 E-210 Reformer Gas Waste Heat Exchanger BFW/Stm 460/ /645 Ref. Gas 1382/ /325 E-211 Recycle Gas LP Stm Generator BFW/Stm 298/298 50/50 Conv. Gas 700/ /258 E212 E-213* Treated Water Pre Heater Recycle Meth. FIP Exchanger Treated Water Scrubbed Rec. Gas 60/ /130 Conv. Gas 360/ / / /274 E-214 Recycle Meth. Startup Heater Nitrogen 750/ /195 Meth. Rec. Gas Scrubbed Gas 700/ / / /269 Exchangers

12 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

13 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 Rich Gas 282/ /278 E-209 Product Gas Cooler Prod. Gas 156/ /163 E-215 Recycle Gas Cooler Recycle Gas 369/ /254 E-216 Regenerator Overhead Condenser CO2 + Steam 242/159 5/1 E-220 Startup Cooler Nitrogen 932/ /240 E-220 Startup Cooler H2+CH4+Steam 752/ /405 E-221 Feed Return Condenser Nap+Recy.Gas 752/ /275 E-221 Feed Return Condenser Pipeline Gas 752/ /395 E-222 Carbonate Solution Cooler Carb. Solution 222/ /395 E-223 Recycle Gas Trim Cooler Converter Gas 360/ /284 E-224 Pipeline Gas Compressor After Cooler Tube Normal (Inlet/Outlet) Nat. Gas 370/ /395 Exchangers

14 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

15 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 SF P-201B Spare SF P-203A Regenerator Reflux SF P-203B Spare SF P-206 Carbonate Transfer SF P-207 Carbonate Sump Pump SF Pumps

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

17 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 # HR 1676 # HR 23,790 # HR 21,300 # HR 21,300 # HR 2675 # HR SF SF SF SF SF Compressors

18 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.

19 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.

20 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 F F F 90 D-103 Water Wash Drum 6.5' ID x 26' 200 F F 25 D-104 Sour Water Receiver 5' ID x 15' 510 F F 50 D-105 R-101 Compressor Suction Drum Desulphurization Reactor 3' ID x 6' 160 F F 375 7' ID x 22.5' 200 F 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

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

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

23 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/ H.C.* 750/ H.C.* 400/ H.C.* 612/ H.C.* 255/ H.C.* 508/ H.C.* 70/ H.C.* 404/ H.C.* 110/ H.C.* 439/ Steam 330/ H.C.* 5/70 80 Exchangers

24 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

25 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 H.C.* 275/ H.C.* 144/ H.C.* 241/ Exchangers

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

27 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 P-102A/B Reactor Stripper 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 '

28 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

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

30 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 Driver Motor HP Safety Factor Mixers: Mixer Water Flow Naptha Flow Pressure Drop (Normal) Operating Pressure Operating Temp M GPM Max 406 GPM Max 14 PSI 75 Psig 100F

31 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

32 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 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 lb. mols/hr of sour gas containing up to 1.84 lb. mols H2S. Section 150

33 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' F 2 PSIG Vessels

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

35 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

36 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

37 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

38 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 D-302 Caustic Stage Drum Atmosphere D-303 Acid Stage Drum Atmosphere D-307 Fuel Gas KO Drum D-308 Blow down Drum (Stm) Section 300

39 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

40 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 Max P-301B Spare Max P-309A Cooling Water Pump P-309B Spare P-311A Naptha Fuel Pump / P-311B Spare / P-319A BFW Pump P-319B BFW Pump P-320A* Hydrazine Pump P-320B* Spare P-321* P-322* Stm Gen Phosphate Pump Pro. Stm. Drum Phosphate Pump P-323* Spare P-329 Phos. to Proc. Stm. Drums

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

42 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 AMB B-301A/B Forced Draft Fan AMB AMB ATM 13" WC 40 B-302A/B Atomizing Air Blower AMB AMB ATM Compressors/Blowers

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

44 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

45 Deionization Plant: Section 300 H 2 O Treatment

46 Flare Towers A-306

2.0 HYDROGEN GENERATION UNIT 2.1 INTRODUCTION

2.0 HYDROGEN GENERATION UNIT 2.1 INTRODUCTION 2.1.1 PURPOSE The objective of the unit is to produce hydrogen by steam reforming of full range naphtha i.e. C 5-140 O C SR naphtha & coker naphtha to meet