Process Description And Pfds.pdf

Lummus Petrochemicals Bloomfield, NJ HMEL (HPCL Mittal Energy Ltd) Petrochemical Complex

CLIENT PROJECT

2.4

222334

Process Description

Proj. No.

DOCUMENT NAME

Process Description

The following is a brief description of the processing scheme for this proposal, as shown on the Process Flow Diagrams. 2.4.1

Refinery Off Gas (ROG) Treating Unit

A combined stream of refinery off gas (ROG) from the PFCC and DCU is routed to the ROG Treating Unit. A mixed LPG produced in the refinery is also fed to the ROG to be used as wash liquid. The ROG Treating Unit provides the following products: 

ROG Fuel Gas which is sent to the SCU Fuel Gas System



C2/C3 stream that is fed to the SCU Deethanizer



C4+ stream that is fed to the Total Hydrogenation Unit (THU)

2.4.1.1

ROG Amine System

The refinery off gas from OSBL is delivered to the ROG Treating Unit on flow control at the battery limit 2 conditions of 9.5 kg/cm g and 40ºC which is then sent to the ROG DGA/Water Wash Column for bulk removal of CO2 and H2S. An online analyzer on the main feed detects the composition of the refinery off gas feed including levels of acid gas (CO2 and H2S). The ROG DGA/Water Wash Column is comprised of two sections. The top portion consists of bubble cap trays which serve as a water wash section to prevent amine entrainment in the overhead product. Wash water for the ROG DGA/Water Wash Column comes from the Continuous Blowdown Cooler located in the SCU. Waste water from the water section (bubble cap trays) is totally drawn off the bottom most tray and sent to Neutralization (OSBL). The bottom portion is comprised of packed beds and serves as the amine wash section. A lean Diglycoamine (DGA) solution, supplied by the DGA Regenerator, is fed to the top of the amine wash section above the packed beds. The water wash in the top section prevents carry-over of Lean DGA into the rest of the system. The refinery off gas is fed below the bottom section of the column where the acid compounds (H2S and CO2) are absorbed into the Lean DGA solution by countercurrent contact as the vapor continues up the tower. The bottom of the tower will have a higher temperature, due to the heat of absorption. The overhead of the ROG DGA/Water Wash Column is sent to ROG Caustic/Water Wash Tower. Any oils that form in the absorption process can be skimmed off the liquid level in the sump of the ROG DGA/Water Wash Column and sent to ROG DGA Oil Degassing Drum. Overhead vapor from Degassing Drum is sent to Wet Flare, while any liquid is sent to the Amine Drain system. Acid gas leaves the ROG DGA/Water Wash Column bottoms with the rich amine solution where it is sent to the DGA Regenerator HP Flash Drum. Liquid hydrocarbons are separated out from the amine solution and sent to the Quench Tower. The Rich DGA from the flash drum is then preheated against the hot bottoms (regenerated Lean DGA) of the regenerator in the Lean DGA/Rich DGA Exchanger.

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CONFIDENTIAL

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Lummus Petrochemicals Bloomfield, NJ HMEL (HPCL Mittal Energy Ltd) Petrochemical Complex

CLIENT PROJECT

222334

Process Description

Proj. No.

DOCUMENT NAME

The DGA Regenerator is comprised of bubble cap trays in the top section and packed beds in the middle and bottom sections. The Rich DGA from the ROG DGA/Water Wash Column is fed to the top of the packed bed section, and makeup DGA combined with makeup water is fed to the bottom of the regenerator. The reboiler duty for the regenerator is provided by controlling the amount of LP Steam sent to the DGA Regenerator Reboiler. The gross overhead from the DGA Regenerator is condensed against cooling water in the DGA Regenerator Condenser and collected in the DGA Regenerator Reflux Drum. The DGA Regenerator pressure is controlled by throttling the acid gas vented from the reflux drum, and a secondary pressure controller introduces nitrogen to the overhead line if the pressure becomes too low. Any liquid that condenses is pumped by the DGA Regenerator Reflux Pumps and sent as reflux to the top of the tower. Acid gases are vented off the reflux drum and sent to the Acid Gas Flare. The bottoms of the DGA Regenerator, Lean DGA, is pumped and cooled by exchanging heat with Rich DGA feed in the Lean DGA/Rich DGA Exchanger. The Lean DGA is cooled further against cooling water in the Lean DGA Cooler before being filtered. The Lean DGA is then recycled back to the ROG DGA/Water Wash Column. A provision is included the remove heat-stable salts formed in the amine system via the DGA Reclaimer. The exchanger is used in batch operation utilizing MP steam to evaporate the DGA solution, leaving behind DGA sludge to be drained to drums and sent for disposal OSBL. 2.4.1.2

ROG Caustic Treatment and Oxygen Converter

A caustic wash removes acid gases (H2S and CO2) by reaction and a non-regenerable waste caustic stream is created. While the amine treatment is used to remove the bulk amount of the acid gases, the caustic treatment brings down acid gases down to specifications levels. The ROG Caustic/Water Wash Tower operates similarly to the SCU Caustic/Water Wash Tower except the one in the Refinery Off Gas unit functions as two separate caustic/water sections. The overhead from the ROG DGA/Water Wash Column is sent to the lower section of the ROG Caustic/Water Wash Tower. The refinery off gas is washed in the lower packed section with weak level caustic to remove CO2 and H2S. The treated gas is then washed with water in bubble cap trays to prevent caustic carryover. Wash water for the tower comes from the Continuous Blowdown Cooler located in the SCU. Waste water from the lower water section (bubble cap trays) is totally drawn off below the bottom most tray and sent to Waste Water Treatment (OSBL). The refinery off gas vapor is then totally drawn off and sent to the ROG Oxygen Converter Feed/Effluent Exchanger. On-line analyzers are provided to detect the amounts of CO2 and H2S entering and leaving this section of ROG Caustic/Water Wash Tower. The refinery off gas is heated in the ROG Oxygen Converter Feed/Effluent Exchanger and by High Pressure (HP) Steam in the ROG Oxygen Converter Feed Heater. The hot refinery off gas is passed through the ROG Oxygen Converter. The catalyst selectivity is moderated by injecting Dimethyl Disulfide (DMDS) upstream of the ROG Oxygen Converter Feed Heater which is eventually removed in the upper portion of the ROG Caustic/Water Wash Tower. The Oxygen Converter catalyst primarily removes oxygen, acetylene, and NOx by reaction to other species. Oxygen is converted to water and NOx is converted to ammonia and water. The Oxygen Page 2 of 31

CONFIDENTIAL

2/14/2017

Lummus Petrochemicals Bloomfield, NJ CLIENT PROJECT

HMEL (HPCL Mittal Energy Ltd) Petrochemical Complex

222334

Process Description

Proj. No.

DOCUMENT NAME

Converter also hydrogenates acetylene to ethane and ethylene. The scheme provides a spare reactor bed for in situ regeneration of the catalyst. On-line analyzers are provided to detect the amounts of C2H2, C2H4, CO, O2, and NOX, entering and leaving the O2 Converter. The hot oxygen-free refinery off gas effluent is cooled by cross-exchange in the ROG Oxygen Converter Feed/Effluent Exchanger. Purge gas recycles from OSBL LLDPE, HDPE and PP units and a vent stream from the DGA Regenerator HP Flash Drum are compressed by the reciprocating Recycle Gas Compressor and mixed with the hot oxygen-free refinery off gas before being cooled against cooling water in the ROG Oxygen Converter Effluent Cooler. The combined streams are then sent to the upper caustic/water wash section of the ROG Caustic/Water Wash Tower. The recycle purge streams contain amounts of ethylene and propylene that can be recovered. However, the recycle streams also contain NOx that may form unstable gums and salts which can result in exchanger plugging, dangerous reactions during upsets, and reactions forming ammonia salts. By directing the recycle purge streams back to the ROG Caustic/Water Wash Tower it ensures that the ethylene and propylene will be recovered also ensuring that the NOx will be removed from the refinery off gas by the ROG Oxygen Converter before entering the SCU. The ROG has the capability to handle the external NOx from the purge streams. The oxygen free refinery off gas and recycle purge gas streams are washed with strong level caustic in a packed section. This section ensures near complete removal of CO2 and H2S. The acid free ROG vapor flows to a water wash section comprised of bubble cap trays. Wash water for the tower comes from the Continuous Blowdown Cooler located in the SCU. Waste water from the lower water section (bubble cap trays) is totally drawn off below the bottoms most tray and sent to Waste Water Treatment (OSBL). Strong caustic solution from the upper section of the ROG Caustic/Water Wash Tower is added to the lower section caustic circulation to maintain the appropriate concentration of caustic solution. A net flow of caustic from the bottom of this tower is sent to the SCU Spent Caustic Treatment. Despite low diolefin concentration, polymeric oil (yellow oil) may form to some extent in the ROG Caustic/Water Wash Tower. Provisions are made for this oil to be decanted from the tower bottom and sent, along with the spent caustic for treatment in the SCU. The overhead of the upper section of the ROG Caustic/Water Wash Tower is chilled against 9°C propylene refrigerant in the ROG Dryer/Treater Feed Chiller. The chilled effluent is sent to ROG Dryer/Treater Feed Gas KO Drum where condensed water and/or hydrocarbon is knocked out sent to Waste Water Treatment. The overhead from the KO Drum proceeds to the ROG Dryer/Treater. The refinery off gas passes through ROG Dryer/Treater for drying and removal of trace impurities such as water, NH3, COS, CO2, CS2, acetonitrile, aldehydes, and amines to less than 1 ppm (w). After treatment, the treated refinery off gas is sent through a filter and then to the ROG Cold Box Exchanger No. 1. One ROG Dryer/Treater is in operation while the second treater is being regenerated or on standby. Online analyzers are provided to detect the amounts of H2O, CO2, H2S, NOx, and NH3 entering and leaving the treaters. A third probe is placed in the bottom portion of the adsorbent bed to detect breakthrough of impurities. Page 3 of 31

CONFIDENTIAL

2/14/2017

Lummus Petrochemicals Bloomfield, NJ HMEL (HPCL Mittal Energy Ltd) Petrochemical Complex

CLIENT PROJECT

222334

Process Description

Proj. No.

DOCUMENT NAME

Regeneration of the ROG Dryer/Treater is accomplished by circulating hot methane-rich regeneration gas from the Regeneration Electric Heater at 290°C and heating the bed in order to drive out impurities adsorbed in the treater bed. The spent regeneration gas is returned to the fuel gas system. After the bed has reached the required temperature, the bed is cooled with unheated regeneration gas. 2.4.1.3

Mixed LPG Treating

Mixed LPG from OSBL is delivered to the ROG Treating Unit at the battery limit conditions of 12.0 2 kg/cm g and 40ºC which is then passed through the LPG Treater for sulfur removal. The concentration of the sulfur is reduced to specification levels. On-line analyzers are provided to detect the amounts of H2S entering and leaving the treater. A third probe is placed in the top portion of the treater to detect breakthrough of impurities. The treated LPG stream passes through another on-line analyzer for detection of C2H4, C2H6, C3H6, C3H8, BD, C4s, and C5+ and then through a filter. The treated LPG is combined with a portion of the Depropanizer heavies’ bottoms before entering the ROG Cold Box Exchanger No. 1. One LPG Treater is in operation while the second treater is being regenerated or on standby. Regeneration of the LPG Treater is accomplished by heating the bed with 290°C regen gas in order to drive out the impurities adsorbed in the treater bed. The spent regeneration gas is returned to the fuel gas system. After the bed has reached the required temperature, the bed is cooled with unheated regeneration gas. 2.4.1.4

Refining Off Gas Chilling & ROG Demethanizer

The treated refinery off gas and LPG enter the ROG Cold Box Exchanger No.1 where the streams are progressively chilled by 4 levels of propylene refrigeration; the refrigeration levels range from 9°C to 40°C. The refinery off gas and LPG proceed to the ROG Cold Box Exchanger No.2 in which they are both chilled by binary refrigerant. The treated refinery off gas enters the ROG Demethanizer between packed beds in the middle section of the tower. The LPG temperature is controlled to -90°C by controlling the amount of binary refrigerant flows to ROG Cold Box Exchanger No.2. The LPG is then mixed with reflux from the ROG Demethanizer Reflux Pumps and used as wash liquid in the ROG Demethanizer. In the ROG Demethanizer fractionation is based on the absorption principle whereby the ethylene and heavier components are absorbed by the LPG wash liquid. The tower is comprised of packed beds and the fractionation occurs on the basis of the absorption principle whereby the C2’s contained in the refinery off gas are absorbed by the C3+ LPG Wash Liquid. The gross overhead of the ROG Demethanizer is partially condensed by binary refrigerant in the ROG Demethanizer Condenser which is also part of the ROG cold box package. The condenser effluent is sent to the ROG Demethanizer Reflux Drum where any liquid that condenses is pumped by the ROG Demethanizer Reflux Pumps as reflux back to the tower. The overhead from the reflux drum, called ROG Fuel Gas, is comprised primarily of methane and lighter compounds where the temperature of this stream is progressively heated in the ROG Cold Box Exchanger No. 2 and further heated in the ROG Cold Box Exchanger No. 1. Once it is heated, the ROG Fuel Gas is sent to the SCU Fuel Gas System. The

Page 4 of 31

CONFIDENTIAL

2/14/2017

Lummus Petrochemicals Bloomfield, NJ HMEL (HPCL Mittal Energy Ltd) Petrochemical Complex

CLIENT PROJECT

222334

Process Description

Proj. No.

DOCUMENT NAME

pressure in the ROG Demethanizer is accomplished by controlling the amount of this stream being sent to the SCU fuel gas system. The ROG Demethanizer Reboiler supplies heat to the tower by subcooling 48°C propylene refrigerant. The temperature in the ROG Demethanizer is controlled by the amount of propylene refrigerant sent to the reboiler. The LPG wash liquid along with C2 & heavier components from refinery off gas is pumped from the bottom of the tower to the ROG Depropanizer. An on-line analyzer on this stream detects the amount of methane that is found in this stream. 2.4.1.5

ROG Depropanizer

The ROG Demethanizer bottoms are pumped by the ROG Demethanizer Bottoms Pump to the ROG Depropanizer. The gross overhead vapor of the tower is totally condensed in the ROG Depropanizer Condenser by -27°C propylene refrigerant which is then sent to the ROG Depropanizer Reflux Drum. Total liquid from the reflux drum is pumped by the ROG Depropanizer Reflux Pumps where a portion is sent as reflux back to the tower. The balanced overhead liquid product, which contains C2 and C3 components, is sent to the SCU Deethanizer. Tower reboiler duty is provided by Low Pressure (LP) Steam in the ROG Deethanizer Reboiler. A portion of the ROG Depropanizer bottoms product, which contains C4 and heavier components, is sent to the SCU Total Hydrogenation Unit (THU). The remaining balance of the ROG Depropanizer bottoms is sent back to the ROG Demethanizer to be used as wash liquid. An on-line analyzer is provided with probes in two locations which detect the top and bottom specification of the ROG Depropanizer with measurements made for C1, C2, and C3 components. If any methane or other non-condensable component makes its way to this tower, it will accumulate in the ROG Depropanizer Reflux Drum. The pressure of the reflux drum is controlled by a pressure controller that would regulate the amount of non-condensables sent back to the cold box for reprocessing. A hand control (HC) provides the ability to vent the non-condensables to the Cold Flare in high pressure scenarios.

Page 5 of 31

CONFIDENTIAL

2/14/2017

Lummus Petrochemicals Bloomfield, NJ HMEL (HPCL Mittal Energy Ltd) Petrochemical Complex

CLIENT PROJECT

2.4.2

222334

Process Description

Proj. No.

DOCUMENT NAME

Steam Cracking Unit (SCU)

The Steam Cracker Unit (SCU) is designed to produce the following products and by-products: 

Polymer Grade Ethylene



Polymer Grade Propylene



PSA Quality Hydrogen Product



Fuel Gas



C5+ Pyrolysis Gasoline



Carbon Black Feedstock

Capacity and Mode of Operation The plant is designed for a production capacity of 1200 KTPA of Polymer Grade Ethylene and 500 KTPA of Polymer grade Propylene (for Design Case-1) and 1200 KTPA of Polymer Grade Ethylene and 720 KTPA Polymer Grade Propylene(for Design Case-2) based on 8000 operating hours per year. 2.4.2.1

Furnace Feed System

Ethane recycle from the Cold Box Offgas Exchanger No. 6 is superheated in the Ethane Feed Preheater against quench water prior to feeding into the cracking heaters. For Design Case-1, the major portion of the propane recycle from the Propylene Fractionator No. 2 is heated and vaporized in the Propane Feed Vaporizer by quench water. The vaporized recycle propane is then superheated against quench water in the Propane Feed Heater. For Design Case-1, a small amount of the propane recycle from the Propylene Fractionator No. 2 is combined with hydrogenated C4/C5’s from the Total Hydrogenation Unit (THU) on flow control to balance the feeds. For Design Case-2, all propane recycle is combined with the hydrogenated C4/C5’s and then sent to the C4/C5 Feed Vaporizer Drum where they are vaporized by C4/C5 Feed Vaporizer. The pressure in the C4/C5 Feed Vaporizer Drum is controlled by adjusting the LP Steam flow to the C4/C5 Feed Vaporizer. The vaporized cracker feed from the vaporizer drum is preheated against LP Steam in the C4/C5 Feed Heater prior to entering the cracking heaters. Provisions to purge any heavy ends from the C4/C5 Feed Vaporizer Drum are provided to minimize any fouling in the vaporizer. Full range Naphtha from OSBL is delivered to the Steam Cracking Unit (SCU) at the battery limit 2 conditions of 9.0 kg/cm g and 40ºC which is then pumped by the Naphtha Feed Pumps, filtered and combined with C6 raffinate from the Aromatics Extraction Unit (AEU) and C5 recycle from the Pyrolysis Gasoline Hydrogenation Unit (PGH). The combined stream is preheated with quench water in the Naphtha Feed Preheater before being sent to the cracking heaters. Light Kerosene/Heavy Naphtha from OSBL is delivered to the SCU at the battery limit conditions of 6.0 2 kg/cm g and 40ºC which is then pumped by the Kero Feed Pumps, filtered and preheated with quench water in the Naphtha Feed Preheater before being sent to the cracking heaters.

Page 6 of 31

CONFIDENTIAL

2/14/2017

Lummus Petrochemicals Bloomfield, NJ HMEL (HPCL Mittal Energy Ltd) Petrochemical Complex

CLIENT PROJECT

2.4.2.2

222334

Process Description

Proj. No.

DOCUMENT NAME

Cracking Heaters

A total of seven SRT cracking heaters provide the cracking capacity of the plant; six heaters will be in operation along with one spare heater to allow for decoking or maintenance. There are 6 SRT VII cracking heaters and 1 SRT VI recycle heater installed. The SRT VII heaters are grouped to process Kero/Heavy Naphtha, Naphtha and C5 Recycle/C6 Raffinate as the first group, Propane Recycle and Hydrogenated C4/C5’s as the second group, and one common spare heater to best process the different feed and recycle streams, simplify operation, and minimize cost. The SRT VII heaters are designed to crack all feeds, thus providing full feedstock flexibility for easy operation. Five feed supply headers are provided and the cracking heaters are connected as shown in the matrix below. This matrix can be updated if necessary to provide more feedstock flexibility. Feed Supply Header Arrangement

F-20001 F-20002 F-20003 F-20004

Ethane X X X

Propane X X X

C4/C5

Naphtha

Kero

X X X

X X

X

X X X

X X X

F-20005 F-20006 F-20007

The SRT VI and SRT VII heaters are a twin radiant cell design which has two radiant cells with a common convection section between the radiant cells, a common stack with ID fan on top of the convection section and a common VHP stream drum. The 8-coil SRT VI radiant coil heater design is selected for ethane and propane recycles cracking to provide long run lengths at optimum TIC without sacrificing cracking selectivity. The 14-coil SRT VII radiant coil heater design is selected for C4/C5, naphtha and kerosene cracking to provide maximum cracking selectivity without sacrificing run length. For Design Case-1, the ethane/propane recycles will be cracked in the SRT VI recycle heater. Ethane will be split cracked in 2 coils against propane in 2 coils in radiant cell "A" and ethane will be cracked in all 4 coils in cell “B”. A small amount of propane is spilled over into the hydrogenated C4/C5’s for feed balancing. For Design Case-2, 100% ethane recycle cracking will take place in both cells of the SRT VI Heater. The propane recycle will be mixed with the hydrogenated C4/C5’s and cracked in the SRT VII cracking heaters. For Design Case-1, the C4/C5 feed with spill-over propane recycle will be cracked in 1 full SRT VII cracking heater and split cracked in 4 coils against naphtha in 3 coils in cell "A" and 100% naphtha in cell "B" of the second full heater. The remaining naphtha will be cracked in 2 full heaters. Kero will be cracked in 1 full heater. For Design Case-2, the C4/C5 feed with all the propane recycle will be cracked in 1 full SRT VII cracking heater and split cracked in 4 coils against naphtha in 3 coils in cell "A" and 100% naphtha in cell "B" of the second full heater. The most of the remaining naphtha will be cracked in 2 full

Page 7 of 31

CONFIDENTIAL

2/14/2017

Lummus Petrochemicals Bloomfield, NJ CLIENT PROJECT

HMEL (HPCL Mittal Energy Ltd) Petrochemical Complex

222334

Process Description

Proj. No.

DOCUMENT NAME

heaters. Split cracking of naphtha in 3 coils against kero in 4 coils will take place in cell "A" and 100% kero cracking in cell "B" in 1 SRT VII cracking heater. The two tables below show the heater allocation as discussed above. Heater Allocation – Design Case 1

F-20001 F-20002 F-20003 F-20004 F-20005 F-20006 F-20007

coils/ feed 6 2 14

Ethane Propane C3 + C4/C5’s

4 10 14 14 14 14

C3 + C4/C5’s Naphtha spare Naphtha Naphtha Kero

Feed

Heater Allocation – Design Case 2

F-20001 F-20002 F-20003 F-20004 F-20005 F-20006 F-20007

coils/ feed 8 14 4

Ethane C3 + C4/C5’s C3 + C4/C5’s

10 14 14 14 3 11

Naphtha spare Naphtha Naphtha Naphtha Kero

Feed

The convection section of the SRT VI recycle heater design consist of the following sections from top to bottom: 

Upper Feed Preheat (UFP)



BFW Preheat (BFW)



Lower Feed Preheat (LFP)



Upper Mixed Preheat (UMP)



Upper Steam Superheater (USSH)



Middle Steam Superheater (MSSH)



Lower Steam Superheater (LSSH)

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CONFIDENTIAL

2/14/2017

Lummus Petrochemicals Bloomfield, NJ CLIENT PROJECT



HMEL (HPCL Mittal Energy Ltd) Petrochemical Complex

222334

Process Description

Proj. No.

DOCUMENT NAME

Lower Mixed Preheat (LMP)

The convection section of the SRT VII cracking heater design consist of the following sections from top to bottom: 

Upper Feed Preheat (UFP)



BFW Preheat (BFW)



Lower Feed Preheat (LFP)



Upper Mixed Preheat (UMP)



Dilution Steam Superheater (DSSH)



Upper Steam Superheater (USSH)



Middle Steam Superheater (MSSH)



Lower Steam Superheater (LSSH)



Lower Mixed Preheat (LMP)

The effluent from one radiant coil is fed to a single conventional primary Transfer Line Exchanger and is cooled against BFW for VHP steam production. The TLEs generate steam at a pressure of 111 kg/cm2g during normal cracking operation. The BFW to the VHP steam drum is preheated by flue gas in the convection section. The steam generated in the TLEs is separated in the steam drum and then superheated in the Upper Steam Superheat (USSH), Middle Steam Superheat (MSSH) and Lower Steam Superheat (LSSH) coils. To control the final superheated outlet temperature, phosphate-free BFW is injected into the partially superheated steam between the steam superheat coils. After BFW injection, the steam is superheated in the LSSH coil for final superheating to 510°C. There are two desuperheaters per convection section: one at the outlet of the USSH and one at the outlet of the MSSH. The desuperheaters are required for VHP steam temperature control and to prevent the steam going below the saturation point after BFW injection during decoking operation. External crossover piping connects the lower mix preheat coils to the individual coil inlet manifolds. Critical flow venturis are provided to equalize flow distributions to the inlet tubes of the radiant coil. DMDS is injected into the dilution steam header at the inlet to each heater as required. The SRT VII cracking heaters have a two-pass radiant coil with an “8-1” coil configuration. The 8-1 designation refers to the 8 inlet tubes flowing to a single larger outlet tube. One radiant coil is composed of four 8-1 units exiting to a single TLE. The SRT VII cracking heaters has 14 radiant coils. The length of the SRT VII radiant coil is 10.36 meter. Below is an illustration of the 8-1 radiant coil configuration (coil sketch below is for understanding purpose only and not to scale). The radiant coil of the SRT VI cracking heater is a two-pass radiant coil with a “7-1” coil configuration; very similar to the SRT VII radiant coil design. The 7-1 designation refers to the 7 inlet tubes flowing to a single larger outlet tube. One radiant coil is composed of four 7-1 units exiting to a single TLE. The SRT VI cracking heaters has 8 radiant coils. The length of the SRT VI radiant coil is 13.72 meter.

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CONFIDENTIAL

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Lummus Petrochemicals Bloomfield, NJ CLIENT PROJECT

HMEL (HPCL Mittal Energy Ltd) Petrochemical Complex

222334

Process Description

Proj. No.

DOCUMENT NAME

8-1 Radiant Coil Configuration of the SRT VII Cracking Heaters

The burner arrangement for the SRT VI recycle heater comprises of hearth and integral burners on the firebox floor plus 1½ row of wall burners at the top of the firebox. The burner arrangement for the SRT VII cracking heaters comprises of hearth and integral burners on the firebox floor only. The shorter SRT VII radiant coil design does not require wall burners. The hearth burners, integral burners and wall burners, if applicable, are independently controlled. During normal operation, the integral burners and wall burners are base loaded while the average coil outlet temperature (COT) controller adjusts the hearth firing rate of the cracking heater. Since fuel gas to the furnace can vary in composition, the fuel flow is compensated by the caloric value from a Wobbe meter to maintain a constant firing rate. In addition to average COT control, automatic coil balancing has been furnished to ensure that all coils are operating at the same outlet temperature.

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CONFIDENTIAL

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Lummus Petrochemicals Bloomfield, NJ CLIENT PROJECT

HMEL (HPCL Mittal Energy Ltd) Petrochemical Complex

222334

Process Description

Proj. No.

DOCUMENT NAME

A jackshaft is provided to adjust the hearth burner air dampers from the DCS and safety interlock system for automatic preset shutdown conditions to protect the convection section. The integral burners and wall burners are self-inspirating and do not require any air adjustments. One ID Fan will be provided for each heater with an inlet damper for firebox draft control. Flue gas exhaust from the ID Fan is vented to atmosphere via a single stack. The cracking heater effluent from the TLE is directed to the main transfer line via the Transfer Line Valve (TLV). The Transfer Line Valve is part of a 3-valve system which also includes the Small (SDV) and Large Decoke Valves (LDV). The SDV is mechanically linked to the TLV to make sure the heater effluent will not be blocked and cause overpressure. The objectives of the transfer line valve and decoke valve system are: a.

To provide heater isolation during decoking

b.

To prevent reverse flow during switching

c.

To prevent overpressure of the individual heater during switching

The heater’s cracked effluent outlet piping that connects to the main transfer line must be positively isolated during the decoking operation to prevent leakage of air into the hydrocarbon-carrying main transfer line during the burn-off phase of the decoking cycle. Likewise, positive isolation is necessary when maintenance is being performed on the heater (i.e., mechanical cleaning of TLE's), to ensure against a backflow of hydrocarbon gas into the heater piping or decoke system. To achieve the objectives described above, Lummus has utilized both mechanical and electronic link transfer line valve systems in the US Gulf Coast and worldwide. For this project, the 3-valve mechanical link transfer line valve system using double disc, metal seat gate valves is recommended. Regardless of feedstock type, the heater effluent from all of the SRT VII cracking heater TLEs is fed to two main transfer lines. One main transfer line takes the effluent from three of the SRT VII heaters and the other main transfer line takes the effluent from the remaining SRT VII heaters. Each main transfer line directs the effluent to one of two Common Quench Fittings at the inlet of the Gasoline Fractionator. Part of the cracked gas from the SRT VI recycle heater (C2/C3 recycles) is sent to the PFO Stripper Feed Quench Fitting for viscosity control with the excess cracked gas going to the Gasoline Fractionator via one of the Common Quench Fittings. After each run, the cracking heaters are decoked with dilution steam plus decoking air to burn off the coke deposits in the radiant coils. The decoking effluent is sent to the firebox where the remaining coke fines are burned. The radiant coil decoke step can be followed by the TLE decoking / polishing step. The steam drum pressure is increased during TLE decoking using the backpressure valve in the VHP steam line to battery limit. TLE decoking is typically done every 3 to 5 radiant coil cycles for all feeds except kerosene. It is recommended to apply TLE decoking for kerosene cracking at every radiant coil cycle. Radiant coil decoking requires approximately twenty-four (24) to thirty (30) hours from feed-out to feed-in. If any Primary TLE outlet maximum temperature was reached in the previous run, then an additional ten (10) hours is necessary on that cracking heater, immediately following the radiant coil decoke, to clean the Primary TLE(s) with a decoking / polishing step. Page 11 of 31

CONFIDENTIAL

2/14/2017

Lummus Petrochemicals Bloomfield, NJ CLIENT PROJECT

2.4.2.3

HMEL (HPCL Mittal Energy Ltd) Petrochemical Complex

222334

Process Description

Proj. No.

DOCUMENT NAME

Gasoline Fractionator

The hot effluent from the cracking heaters is combined in the main transfer lines, quenched in the quench fittings, and sent to the Gasoline Fractionator system where they are further cooled to stop the pyrolysis reactions. Pyrolysis Fuel Oil (PFO) is separated as a bottoms product, a liquid Pyrolysis Gas Oil (PGO) side stream is withdrawn as product, and gasoline and lighter materials are taken as overhead vapor. Heat is removed by circulating quench oil from the tower bottom, and is recovered via dilution steam generation in the Quench Oil / Dilution Steam Reboiler. The slightly cooled quench oil is split, and a portion is sent to the Common Quench Fitting where it used to cool the main feed to the tower. The remaining portion of the slightly cooled quench oil is used to preheat the process water in the Quench Oil / Dilution Steam Drum Feed Preheater feeding the Dilution Steam Drum. A total draw-off pan oil loop removes more heat from fractionator by preheating the feed to the Process Water Stripper in the Pan Oil / Process Water Stripper Feed Preheater. The top of the Gasoline Fractionator is refluxed with gasoline condensed in the Quench Tower. The Gasoline Fractionator is comprised of three different sections. The top section is comprised of valve trays that serve to separate out the gasoline and lighter ends from the heavier hydrocarbons in the stream. The second section, Packed Bed #1, is comprised of packing which provides a heat removal zone for the Pan Oil loop. The third section, Packed Bed #2, also containing packing serves as a heat removal zone for the Quench Oil Loop. Part of the TLE effluent from the SRT VI Heater (C2/C3 recycles) is used to strip the fuel oil product and control the viscosity of the circulating quench oil stream. The composition of the quench oil is changed by increasing the concentration of relatively lighter components. This is accomplished by stripping the quench oil entering the Pyrolysis Fuel Oil Stripper with part of the Cracking Heater effluent in the PFO Stripper Feed Quench Fitting prior to entering the stripper. High Pressure steam is substituted for heater effluent when the heater is being decoked. A relatively high percentage of components boiling between 280°C and 370°C are stripped out and circulated through the quench oil circuit. As a result, these components do not readily leave the system with the stripped pyrolysis fuel oil and, therefore, concentrate in the circulating quench oil. The concentration of this mid-boiling range material maintains quench oil viscosity within the desired limits. The PFO Stripper is steam stabilized using MP steam to achieve a fuel oil product of acceptable flash point greater than 110°C. The overhead of PFO Stripper containing vaporized light material is combined with Pyrolysis Gas Oil (PGO) withdrawn from the trayed section of the Gasoline Fractionator then sent to the bottoms of the Gasoline Fractionator. The bottoms of stripper, PFO product, is filtered then pumped via the PFO Pump and cooled against quench water in the PFO Product Cooler prior to being sent to OSBL storage. The C9+ stream from the BTX Tower bottoms is combined with the PFO product prior to being cooled in the PFO Product Cooler. There is a small stream of PFO that is circulated back to the Gasoline Fractionator bottoms, which affects the amount of vaporization in the PFO Stripper Feed Quench Fitting.

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The quench oil from the bottom of the Gasoline Fractionator is filtered and then passed through the Quench Oil Coke Removal Package to improve the quench oil quality for use in the QO/DS Exchangers as well as in the quench fittings. The liquid side-draw of pan oil from the bottom section of Packed Bed #1, essentially free of coke fines, is not filtered prior to use in the pan oil exchangers. A portion of the pan oil is filtered, pumped, and used as purge oil for the instrumentation prior to returning to the Gasoline Fractionator bottoms. Provisions for flux oil injection into the circulating quench oil have also been provided. 2.4.2.4

Quench Tower

Overhead vapor from the Gasoline Fractionator is sent to the Quench Tower where it is cooled and partially condensed by direct counter-current contact with recirculating water, called quench water (QW). The recirculating quench water is sent from the tower bottoms to supply low level heat to various process users. Provision for amine injection to the recirculating quench water is provided for pH control. The circulating quench water is pumped by the Quench Water Circulation Pumps and cooled in various exchangers. A portion of the high temperature Quench Water is sent to the Propylene Fractionator No. 2 Reboiler and then to the Propylene Fractionator No. 1 Reboiler after which it is sent to the Quench Water return line. The remaining high temperature quench water undergoes further cooling in the following exchangers (unless noted otherwise): st

1 Level: High Temperature Quench Water 

Deethanizer Reboiler

Quench Water not used in providing heat at the high temperature level is bypassed into the medium temperature header through a differential pressure control valve. The remaining medium temperature quench water undergoes further cooling in the following exchangers: nd

2 Level: Medium Temperature Quench Water 

Propane Feed Heater



Kero Feed Preheater



Naphtha Feed Preheater



Ethane Feed Preheater

Quench Water not used in providing heat at the medium temperature level is bypassed into the low temperature header through a differential pressure control valve. The low temperature quench water undergoes further cooling in the following exchangers: rd

3 Level: Low Temperature Quench Water 

Caustic Charge Gas Feed Heater



Propane Feed Vaporizer



PFO Product Cooler

The majority of the quench water in the return line is cooled in the Quench Water Cooler No. 1 with a portion of the total quench water used as a hot quench water bypass to maintain a mid-quench water Page 13 of 31

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return temperature of 54°C. A major portion of this flow combines with the hot quench water bypass and is fed on flow control to the lower section of the Quench Tower. This flow is reset by the Quench Tower bottom temperature controller to maintain a bottoms temperature of 82°C. The remainder of the quench water flow is cooled to 38°C in the Quench Water Cooler No. 2 with cooling water and sent on flow control to the top of the Quench Tower. The overhead vapor from the Quench Tower is sent to the charge gas compression section. The heavy gasoline condensed in the Quench Tower is separated from the re-circulating quench water and the condensed dilution steam in the tower bottom. The majority of the condensed hydrocarbons are returned to the Gasoline Fractionator on flow control, and the balance hydrocarbons are sent to the Pyrolysis Hydrogenation Unit (PGU), on flow control reset by level control in the Quench Tower bottoms and to the Spent Caustic Treatment as wash gasoline. The Quench Tower also provides a stream of process water feed to the Process Water Stripper. 2.4.2.5

Process Water Stripping and Dilution Steam Generation

The process water leaving the Quench Tower bottoms is preheated against pan oil and routed to the Process Water Stripper. The process water is stripped with steam generated in the Process Water Stripper Reboiler in order to remove acid gases and volatile hydrocarbons. A provision for live LP steam injection is also provided to the bottom of the stripper to ensure continuity of operation. The amount of vapor sent back to the Quench Tower from the stripper is controlled by setting the amount of LP Steam to the Process Water Stripper Reboiler. The stripped process water from the Process Water Stripper is pumped via the Dilution Steam Drum Feed Pumps and preheated by quench oil in the Quench Oil / Dilution Steam Drum Feed Preheater before entering the Dilution Steam Drum. This feed is fed on flow control reset by the level controller on the sump of steam drum. Makeup water from the boiler feed water system is sent to the top of the steam drum which serves as a wash to prevent caustic from carrying over into the Cracking Heaters. The main duty for this tower is provided by the Quench Oil / Dilution Steam Reboiler. The remaining duty is supplemented by the Dilution Steam / MP Steam Exchanger. The dilution steam generated leaves the top of Dilution Steam Drum and is sent to the Dilution Steam Separator where any remaining liquid droplets are removed, and combined with the steam drum blowdown stream. The dilution steam is superheated against Medium Pressure (MP) steam in the Dilution Steam Superheater and then used as dilution steam in the cracking heaters and as purge steam to instruments and valves. The pressure of the dilution steam is set by controlling the amount of MP Steam sent to superheater. Provisions for amine injection into the Process Water Stripper and Dilution Steam Drum feeds are provided for pH control. To prevent a build-up of non-volatiles, a blowdown stream from the Dilution Steam Drum is drawn, cooled against cooling water in the Dilution Steam Blowdown Cooler and sent on flow control to OSBL waste treatment facility.

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Charge Gas Compression (Stages 1-2) st

The Quench Tower overhead vapors are sent to the Charge Gas Compressor 1 Stage Suction drum. Any hydrocarbon and water liquids knocked out in this drum are pumped to the Quench Tower by the st st CGC 1 Stage Suction Drum Pumps. The overhead vapor from this drum enters the 1 stage of the Charge Gas Compressor. A steam turbine utilizing Very High Pressure Steam (VHPS) drives the CG Compressor. Boiler Feed Water (BFW) is injected into the compressor to help maintain temperature below 100°C consequently reducing fouling. Wash Oil Injection is provided individually at all three compression stages to wash the rotors as required. st

The compressed hydrocarbon stream continues to the Charge Gas Compressor 1 Stage Aftercooler where it is cooled by cooling water. Continuous vents from the Pyrolysis Gasoline Hydrogenation (PGH) Unit and Total Hydrogenation Unit (THU), as well as other normally closed vents from other parts of the nd SCU are combined with the cooled charge gas and sent to the Charge Gas Compressor 2 Stage Suction Drum. nd

Any hydrocarbons condensed in the Charge Gas Compressor 2 Stage Suction Drum are sent to the nd Quench Tower. Any water that is knocked out in CGC 2 Stage Suction Drum is sent to the Charge Gas st nd Compressor 1 Stage Suction Drum. The overhead vapor from this drum enters the 2 stage of the Charge Gas Compressor. nd

The compressed hydrocarbon stream continues to the Charge Gas Compressor 2 Stage Aftercooler where it is cooled by cooling water. A continuous vent from the Propylene Fractionator Vent Condenser and the MEA Regenerator HP Flash Drum along with normally closed offspec ethylene BOG vapors are nd combined with the cooled charge gas and sent to the Charge Gas Compressor 2 Stage Discharge Drum. nd

Any hydrocarbons and water components that are knocked out in the Charge Gas Compressor 2 Stage nd Discharge Drum are sent back to Charge Gas Compressor 2 Stage Suction Drum. The vapor from the nd CGC 2 Stage Discharge Drum is heated to 45°C by Quench Water in the Caustic Charge Gas Feed Heater and sent to the SCU Amine/Water Wash Column. This preheat prevents hydrocarbon condensation which contributes to "yellow oil" formation. However, the temperature should not be increased above this value since high temperatures can lead to precipitation of salts resulting in plugging. 2.4.2.7

Amine System nd

Charge gas from the Charge Gas Compressor 2 Stage Discharge Drum is sent to the SCU MEA/Water Wash Column for bulk removal of CO2 and H2S. An online analyzer on the feed detects the levels of acid gas (CO2 and H2S) in the charge gas. The SCU MEA/Water Wash Column is comprised of two sections. The top portion consists of bubble cap trays which serve as a water wash section to prevent amine entrainment in the overhead product. Wash water for the SCU MEA/Water Wash Column comes from the Continuous Blowdown Cooler. Waste water from the water section (bubble cap trays) is totally drawn off the bottom most tray and sent to Neutralization (OSBL). The bottom portion is comprised of packed beds and serves as the amine wash section.

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A lean Monoethanolamine (MEA) solution, supplied by the MEA Regenerator, is fed to the top of the amine wash section above the packed beds. The water wash in the top section prevents carry-over of Lean MEA into the rest of the system. The charge gas is heated by Quench Water in the Amine Charge Gas Feed Heater prior to being fed below the bottom section of the column. The acid compounds (H2S and CO2) in the charge gas are absorbed into the Lean MEA solution by countercurrent contact as the vapor continues up the tower. The bottom of the tower will have a higher temperature, due to the heat of absorption. The overhead of the SCU MEA/Water Wash Column is sent to the Caustic/Water Wash Tower. Any oils that form in the absorption process can be skimmed off the liquid level in the sump of the SCU MEA/Water Wash Column and sent to SCU MEA Oil Degassing Drum. Overhead vapors from Degassing Drum is sent to Wet Flare, while any liquid is sent to the Amine Drain system. Acid gas leaves the ROG MEA/Water Wash Column bottoms with the rich amine solution where it is sent to the MEA Regenerator HP Flash Drum. Liquid hydrocarbons are separated out from the amine solution and sent to the Quench Tower. The Rich MEA from the flash drum is then preheated against the hot bottoms (regenerated Lean MEA) of the regenerator in the Lean MEA/Rich MEA Exchanger. The MEA Regenerator is comprised of bubble cap trays in the top section and packed beds in the middle and bottom sections. The Rich MEA from the SCU MEA/Water Wash Column is fed to the top of the packed bed section, and makeup MEA combined with makeup water is fed to the bottom of the regenerator. The reboiler duty for the regenerator is provided by controlling the amount of LP Steam sent to the MEA Regenerator Reboiler. The gross overhead from the MEA Regenerator is condensed against cooling water in the MEA Regenerator Condenser and collected in the MEA Regenerator Reflux Drum. The MEA Regenerator pressure is controlled by throttling the acid gas vented from the reflux drum, and a secondary pressure controller introduces nitrogen to the overhead line if the pressure becomes too low. Any liquid that condenses is pumped by the MEA Regenerator Reflux Pumps and sent as reflux to the top of the tower. Acid gases are vented off the reflux drum and sent to the Acid Gas Flare. The bottoms of the MEA Regenerator, Lean MEA, is pumped and cooled by exchanging heat with Rich MEA feed in the Lean MEA/Rich MEA Exchanger. The Lean MEA is cooled further against cooling water in the Lean MEA Cooler before being filtered. The Lean MEA is then recycled back to the SCU MEA/Water Wash Column. A provision is included the remove heat-stable salts formed in the amine system via the MEA Reclaimer. The exchanger is used in batch operation utilizing MP steam to evaporate the MEA solution, leaving behind MEA sludge to be drained to drums and sent for disposal OSBL. 2.4.2.8

Acid Gas Removal

The treated charge gas from the SCU MEA/Water Wash Column is fed to the bottom of the lower packed bed in the Caustic/Water Wash Tower where acid gases (H2S and CO2) are removed by weak caustic pumped in by the Weak Caustic Circulation Pump. Acid gases react with caustic to form sodium sulfide and sodium carbonate salts. The cleaner charge gas continues through to the bottom of the upper packed bed in the tower where acid gases are removed by medium level caustic pumped to the top of the Page 16 of 31

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bed by the Middle Caustic Circulation Pumps. The charge gas then proceeds to the third section of acid gas removal where strong caustic solution is pumped in from the Strong Caustic Circulation Pumps. In this section the required CO2 spec in the Ethylene Product is met. Before the acid-free charge gas leaves the Caustic/Water Wash Tower, wash water is introduced to the top of section of the tower to ensure no caustic is carried over into downstream equipment. Wash water for the Caustic/Water Wash Tower comes from the Continuous Blowdown Cooler. Waste water from the water section is totally drawn off below the bottom most tray of the top section and sent to Spent Caustic Wash Gasoline Mixer. Any significant breakthrough of H2S or CO2 can jeopardize downstream operations or final product specifications. 20% Caustic is fed from OSBL to the suction line of the Strong Caustic Circulation Pumps to make up any caustic that leaves the bottoms (spent caustic) of caustic tower. 2.4.2.9

Charge Gas Compression (Stage 3)

After acid gas removal in the Caustic/Water Wash Tower, the charge gas is cooled by 9°C propylene rd refrigeration in the Caustic Tower Effluent Cooler and sent to the Charge Gas Compressor 3 Stage Suction Drum. In this drum the condensed hydrocarbon and water phases are separated. The hydrocarbon is split into two streams. One stream is recycled to the Quench Tower to maintain gasoline rd inventory. The other stream is pumped by the CGC 3 Stage Suction Drum Pumps to the Liquid rd Condensate Coalescer Package. An interface level controller sends water from the 3 Stage Suction rd Drum to the Quench Tower. The overhead vapor from this drum enters the 3 stage of the Charge Gas Compressor. rd

The compressed hydrocarbon stream continues to the Charge Gas Compressor 3 Stage Aftercooler No. 1 where it is cooled against cooling water. The charge gas undergoes further cooling in the Charge Gas rd Compressor 3 Stage Aftercooler No. 2 by 9°C propylene refrigerant and is sent to the Charge Gas rd Compressor 3 Stage Discharge Drum. In this drum the condensed hydrocarbon and water phases are rd separated. The hydrocarbon stream is pumped by the CGC 3 Stage Discharge Drum Pumps to the rd Liquid Condensate Coalescer Package. An interface level controller sends water from 3 Stage Discharge Drum to the Quench Tower. The overhead vapor from the discharge drum is sent to the Charge Gas Dryers. 2.4.2.10

Spent Caustic Pretreatment

The spent caustic solution and yellow oil from the SCU and ROG Caustic/Water Wash Towers cannot be discharged to the environment without further treatment. The spent caustic solution contains sodium carbonate, sodium sulfide, and a small percentage of free, unreacted, sodium hydroxide. In addition, the solution may contain dispersed hydrocarbons. The dispersed hydrocarbons may cause considerable fouling in the OSBL Wet Air Oxidation Unit (WAO) and are therefore removed with a gasoline wash. Spent caustic leaves the bottom of the SCU and ROG Caustic/Water Wash Towers, along with a cooled wash gasoline stream is sent to the Spent Caustic Wash Gasoline Mixer and then processed in the Spent Caustic Coalescer. Wash gasoline is pumped from the Quench Tower on flow ratio control, maintaining a consistent ratio to the spent caustic flow. Prior to entering the Spent Caustic Coalescer it is cooled by cooling water in the Spent Caustic Wash Gasoline Cooler. The gasoline wash recovers hydrocarbon from the spent caustic stream. In the Spent Caustic Coalescer the combined stream is first degassed, Page 17 of 31

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then passed through a packed coalescing pad and into the settling compartment where the gasoline/caustic separation takes place. The spent caustic is routed to the WAO unit where it undergoes further treatment. The Wet Air Oxidation unit converts the sodium sulfides to sodium sulfates and thiosulfates. The spent gasoline from the Spent Caustic Coalescer requires further water washing to reduce the quantity of entrained caustic which can lead to a pH problem. The gasoline is sent to the Spent Gasoline/Wash Water Mixer where it is contacted with wash water prior to entering the Spent Gasoline Coalescer. Wash water is pumped from the Process Water Stripper bottoms on flow ratio control, maintaining a consistent ratio to the wash gasoline flow from Spent Caustic Coalescer. In the Spent Gasoline Coalescer the combined stream is passed through a packed coalescing pad and into the settling compartment where the gasoline/water separation takes place. The spent wash water is sent to the WAO and the spent gasoline is returned to the Quench Tower. 2.4.2.11

Charge Gas and Liquid Condensate Drying

The charge gas passes through the Charge Gas Dryers for moisture removal. After drying, the charge gas is sent through the Charge Gas Dryer Outlet Filters and then to the HP Depropanizer. The removal of water from the charge gas is necessary to prevent the formation of ice and hydrates in the HP Depropanizer. Two Charge Gas Dryers are in operation while the third dryer is being regenerated or on standby. Each dryer contains two desiccant bed sections. A moisture analyzer is provided below the first (main) bed to indicate the arrival of the wet gas “front”. The second bed (guard) prevents break-through moisture from leaving the dryer. Any indication of the wet gas “front” reaching the analyzer probes indicates exhaustion and the dryers should be switched immediately. Regeneration is carried out by circulating hot methanerich regeneration gas from the regeneration system at 232°C to drive out moisture adsorbed in the dryer bed. After the bed has reached the required temperature, the bed is cooled with unheated regeneration gas. The spent regeneration gas is returned to the fuel gas system. rd

Liquid condensate is pumped from the CGC 3 Stage Suction and Discharge Drums to the Liquid Condensate Coalescer Package where the separated hydrocarbon proceeds to the Liquid Condensate Dryers for moisture removal. Any free water in the feed stream is removed from the bottom boot of Liquid Condensate Coalescer and sent to the Quench Tower. After drying, the liquid condensate flows through the filters and then sent directly to the HP Depropanizer. One Liquid Condensate Dryers is in operation while the second dryer is being regenerated or on standby. Each dryer contains one desiccant bed. A moisture analyzer is provided towards the end of the bed to indicate arrival of the wed gas “front”. Any indication of the wet gas “front” reaching the analyzer probe indicates exhaustion and the dryer should be switched immediately. The regeneration procedure is similar to that of the Charge Gas Dryers mentioned above. An on-line analyzer on the effluent from the Liquid Condensate Dryers measures any water that may break through. A separate on-line analyzer provides a composition of the charge gas, as well as detecting any acid gases (CO2 and H2S).

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Regeneration System

Dryers and treaters in the complex operate on the principle of Temperature Swing Adsorption (TSA), in which water and/or impurities adsorb into a packed bed at one temperature, and are released from the bed at higher temperature during regeneration. The size of the beds determines how long each adsorption cycle is, before the beds become saturated and require regeneration. Fuel gas from the ROG as well as methane rich offgas from the SCU fuel gas system is combined and used as regeneration gas in the complex. It is split into two cooling and heating regeneration headers. The cooling regeneration gas is at a temperature of 40°C. The heating regeneration gas is preheated by the Regeneration Feed/Effluent Exchanger and then against High Pressure (HP) Steam in the Regen Gas Heater. The temperature of the heating regeneration gas is controlled to 240°C by throttling the amount of HP Steam sent to Regen Gas Heater. A portion of the spent regeneration gas is further heated to 290-300°C by the Treater Regeneration Gas Electric Heater and sent to treaters that require hotter regeneration gas than typically provided. A mixture of heating and cooling regeneration gas is sent to the dryers and treaters on flow control. The regeneration procedure consists of several steps including gradual heating by regeneration gas, holding at this temperature until all water is driven from the molecular sieve, and finally cooling the beds before returning to service. Flow control on the combined regeneration gas is established by controlling the heating regeneration gas sent to the dryer or treater. Temperature control on the combined regeneration gas is established by resetting the set point on the flow controller of the cooling regeneration gas. The spent regeneration gas from the users is cooled in the Regeneration Feed/Effluent Exchanger and cooled in the Regeneration Gas Cooler by cooling water. The cooled regeneration gas continues to the Regeneration Gas K.O. Drum for removal of water prior to re-entering the fuel gas system. Any condensed water from the regeneration gas K.O. drum is returned to the Quench Tower. The reactors in the complex require different types of gases during their regeneration cycles. A Reactor Reduction Gas Heater heats a Nitrogen (N2) stream along with Hydrogen (H2) when required. The temperature is controlled by throttling the amount of Medium Pressure (MP) Steam sent to Reactor Reduction Gas Heater. There are also provisions for Plant Air, Very High Pressure (VHP) Steam, and Low Pressure (LP) Steam to be sent to reactors during regeneration oxidation steps. 2.4.2.13

Depropanization and Acetylene Hydrogenation

The purpose of the Depropanizer system is to achieve a C4's content in the net overhead consistent with the allowable specifications of the final C3 product streams. The bottoms composition is adjusted to maintain the bottoms temperature such that fouling tendencies in the trays and the reboiler are minimized. The Depropanizer system employs a two tower system, with each tower operating at a different pressure. By utilizing two distillation towers, refrigeration demand and fouling is minimized, when compared with single-tower systems. The charge gas from the Charge Gas Dryers and the condensed hydrocarbon liquid from the Liquid Condensate Dryer are fed to the bottom and middle of the top section of the High Pressure (HP) Depropanizer. The gross overhead from the High Pressure Depropanizer is heated by Acetylene Page 19 of 31

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Converter reactor effluent in the Acetylene Converter Feed/Effluent Exchanger No. 1 and No. 2. The temperature of the reactor feed after Feed/Effluent Exchanger No. 2 is set to 53°C by controlling the amount that bypasses it. An on-line analyzer detects the amount of C4’s in this stream, which indicates tower separation performance. A separate analyzer detects any carbon monoxide found in the stream, which is a temporary poison to the Acetylene Converter catalyst that reduces activity. The reactor feed is heated in the Acetylene Converter Heater. The front end Acetylene Converter system selectively hydrogenates acetylene to ethylene and ethane. Some methyl-acetylene/ propadiene (MAPD) are hydrogenated to propylene and propane. An on-line analyzer on this stream measures the amount of acetylene, ethane, and MAPD in the reactor feed. The Acetylene Converter contains 3 beds operating in series with intercoolers after each staged cooled by cooling water. Temperature controllers downstream of each intercooler set the temperature of the cooled effluent feeding the next bed, by controlling the amount bypassing each intercooler. Reactor regeneration is performed ex-situ. The reactor vessels are configured to be put in any order to allow single vessel catalyst replacement if required. The reactor effluent is cooled by in the Acetylene Converter Aftercooler by cooling water. An on-line analyzer on this stream measures the amount of acetylene, ethane, and MAPD in the reactor effluent. The reactor effluent then is further cooled in the Acetylene Converter Feed/Effluent Exchanger No. 2 after which it is sent to the Acetylene Converter Dryer for moisture removal. The dryer effluent is filtered then further cooled in Acetylene Converter Feed/Effluent Exchanger No. 1 and then sent to the HP Depropanizer Condenser. The hydrocarbons are partially condensed by -27°C propylene refrigerant and then enters the HP Depropanizer Reflux Drum. The liquid from reflux drum is pumped by the HP Depropanizer Reflux Pumps on flow control back to the HP Depropanizer as reflux. The condensed liquid from the reflux drum provides some of the reflux to the HP Depropanizer. The net overhead from the HP Depropanizer, which contains the C3 and lighter components of the charge gas, is then fed to the chilling train. Tower reboiler duty is provided by Desuperheated Low Pressure (LP) Steam in the HP Depropanizer Reboiler. Only one of the reboilers is in operation; a spare is provided for periodic cleaning. The HP Depropanizer bottoms is cooled by cooling water in the HP Depropanizer Bottoms Cooler and then fed to the LP Depropanizer. An on-line analyzer provides a measurement of C2’s in the bottoms stream which is an indication of tower separation performance. Polymerization inhibitor from the Polymerization Inhibitor Injection System is injected into the HP Depropanizer feed and Reboiler inlet streams. The bottoms product of the HP Depropanizer is fed to the LP Depropanizer. The gross overhead of the LP Depropanizer is fully condensed by -27°C refrigerant in the LP Depropanizer Condenser. The condensed stream leaving the condenser enters the LP Depropanizer Reflux Drum. Total liquid from the reflux drum is pumped by the LP Depropanizer Reflux Pumps where a portion is sent as reflux back to the LP Depropanizer. The remaining overhead liquid product is sent to the HP Depropanizer. Tower reboiler duty is provided by Desuperheated Low Pressure (LP) Steam in the LP Depropanizer Reboiler. Only one of the reboilers is in operation; a spare is provided for periodic cleaning. The LP Depropanizer bottoms product, which contains C4 and heavier components, is pumped by the LP Page 20 of 31

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Depropanizer Bottoms Pumps to the Debutanizer. On-line analyzers detect the amount of C4’s in the overhead product stream as well as the C3’s in bottoms product stream, which indicate tower separation performance. Polymerization inhibitor from the Polymerization Inhibitor Injection System is injected into the LP Depropanizer feed and Reboiler inlet streams. A normally closed vent stream from the LP nd Depropanizer Reflux Drum is provided to rout material back to the Charge Gas Compressor 2 Stage Suction Drum for reprocessing. 2.4.2.14

Charge Gas Chilling

The charge gas from the HP Depropanizer overhead is progressively chilled against -40°C propylene refrigerant in the Demethanizer Feed Chiller and then in the Demethanizer Reboiler before it is finally chilled in the Offgas Exchanger No. 3. The temperature of the charge gas is set to -80°C by controlling the amount of Binary Refrigerant (BR) sent to Offgas Exchanger No. 3 and the stream is flashed in the Demethanizer Feed Separator No. 1. The condensate is separated in the Demethanizer Feed Separator No. 1 and fed to the Demethanizer as the “Bottom Feed”. The overhead vapor from the Demethanizer Feed Separator No. 1 is further chilled against offgases and binary refrigerant in the Offgas Exchanger No. 2. The temperature of the charge gas is set to -110°C by controlling the amount of binary refrigerant sent to Offgas Exchanger No. 2 and the stream is flashed in the Demethanizer Feed Separator No. 2. The condensate from the Demethanizer Feed Separator No. 2 is sent to the Demethanizer as the “Middle Feed”. The overhead vapor from the Demethanizer Feed Separator No. 2 is further chilled against offgases and binary refrigerant in the Offgas Exchanger No. 1, and is mixed with methane wash liquid in the Demethanizer Feed/Methane Wash Mixer, and is flashed in the Demethanizer Feed Separator No. 3. The condensate from the Demethanizer Feed Separator No. 3 is sent to the Demethanizer as the “Top Feed”. The overhead vapor from the Demethanizer Feed Separator No. 3, called hydrogen rich offgas, is reheated by charge gas in the cold box system and compressed in the Hydrogen Compressor before being sent to the Hydrogen Pressure Swing Adsorption (PSA) Unit for hydrogen purification. The pressure of the Demethanizer Feed Separator No. 3 is controlled by two pressure controllers. Primary pressure control is accomplished by resetting the speed controller on the H2 Compressor. In a high pressure scenario, the speed controller for the H2 Compressor may reach its limit and secondary pressure control is accomplished by sending the hydrogen rich offgas to the fuel gas system. The Hydrogen Compressor is comprised of two stages and the discharge from each stage is cooled to 45°C by cooling water in the Hydrogen Compressor Intercooler and Aftercooler. The pressure of the stream is increased to provide sufficient pressure for the purified hydrogen (>99.9 mol.%) from the PSA Unit to be sent to the following locations: 

Total Hydrogenation Unit (THU)



MAPD Converter



Pyrolysis Gasoline Hydrogenation (PGH) Unit

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HMEL (HPCL Mittal Energy Ltd) Petrochemical Complex

222334

Process Description

Proj. No.

DOCUMENT NAME

A portion is sent out as High Pressure (HP) Hydrogen product to OSBL while the remaining high purity H2 from the PSA is exported on flow control as hydrogen product to OSBL. Offgas from the PSA Unit is recompressed to fuel gas header pressure (to maximize hydrogen recovery) and is combined with returned regeneration gas and is sent directly to the Fuel Gas system. A portion of this fuel gas is sent to the Fuel Gas Knock-Out Drum where any liquids are removed on level control and sent back to the Quench Tower. The pressure of KO drum is controlled by two pressure controllers in the overhead line. In a high pressure scenario, fuel gas is vented to the Wet Flare. In a low pressure scenario, supplemental fuel gas is brought into the KO drum from OSBL. The overhead of the KO drum undergoes further processing in the Fuel Gas Filter/Coalescer where condensate is removed and sent back to the Quench Tower. The processed fuel gas is consumed by the Cracking Heaters any excess is sent to OSBL. On-line analyzers detect the composition of this fuel gas stream, to control the firing rate in the cracking heater burners. 2.4.2.15

Demethanization

The Demethanizer tower is comprised of multiple packed bed sections and its primary purpose is to separate methane and lighter components from the remaining charge gas. The tower operates at a top pressure just high enough to permit overhead methane product to get into the fuel gas system. By minimizing the operating pressure, the separation efficiency is increased which reduces both reflux requirements and energy consumption. There are three primary condensed liquid feeds (top/middle/bottom) to the Demethanizer which come from feed separator drums in the chill train. Demethanizer gross overhead vapor at -130°C is partially condensed with binary refrigerant in the Demethanizer Condenser and sent to the Demethanizer Reflux Drum. The overhead of the reflux drum is sent back to the cold box where it is heated before being sent to the regeneration system; any fuel gas not used for regeneration proceeds to the PSA unit for hydrogen recovery. A control valve controls the flow of this stream through the control box which sets the pressure in the Demethanizer tower. The liquid from the reflux drum is pumped by the Demethanizer Reflux Pumps. A portion is sent on flow control as reflux to the top bed of the Demethanizer, while the remaining liquid is used as methane wash liquid in the Demethanizer Feed Separator No. 3 in the charge gas chilling train to reduce ethylene loss. Tower reboiler duty is provided by heat interchange with hot charge gas from the HP Depropanizer Reflux Drum in the Demethanizer Reboiler. A temperature controller sets the temperature profile in the tower by bypassing a portion of the charge gas around the reboiler. The bottoms product is pumped by the Demethanizer Bottoms Pumps and split into two streams before being heated in the cold box and eventually entering the Deethanizer. One stream is sent directly as liquid from the cold box to the Deethanizer as the “Upper Feed”. The other stream is vaporized in the cold box and sent to the Deethanizer as the “Lower Feed”. A level controller resets the flow controller on the “Lower Feed” upstream of the cold box. The “Upper Feed” flow controller is set on ratio control relative to the “Lower Feed”. An on-line analyzer in the tower bottoms detects for methane, an indication of tower separation performance. Provisions are made to reprocess vents from ethylene fractionation or the binary refrigeration system. Page 22 of 31

CONFIDENTIAL

2/14/2017

Lummus Petrochemicals Bloomfield, NJ CLIENT PROJECT

2.4.2.16

HMEL (HPCL Mittal Energy Ltd) Petrochemical Complex

222334

Process Description

Proj. No.

DOCUMENT NAME

Deethanization

The Demethanizer bottoms product, which is split into two streams as described in the Demethanizer section, feeds the Deethanizer. The Deethanizer is comprised of multiple valve trays and its primary purpose is to create a C2 stream sent to the Ethylene Fractionator and a C3 stream sent to the Propylene Fractionators. A treated C2/C3 stream from the ROG Depropanizer is fed to the system. The gross overhead vapor of the Deethanizer is partially condensed against -27°C propylene refrigerant in the Deethanizer Condenser. The two phase stream leaving the condenser enters the Deethanizer Reflux Drum where an overhead vapor stream, containing ethane and ethylene, is sent to the Ethylene Fractionator. The tower overhead pressure is set by a pressure controller in the gross overhead line resetting the flow controller on the C2s sent to the Ethylene Fractionator. In a high pressure scenario, a second pressure controller will open a normally closed vent on the reflux drum to the Cold Flare. Total liquid from reflux drum is pumped by the Deethanizer Reflux Pumps, and sent as reflux back to the tower. The level in the reflux drum is controlled by throttling the amount of propylene refrigerant sent to the Deethanizer Condenser. Tower reboiler duty is provided by Quench Water (QW) in the Deethanizer Reboiler. A tray temperature controller sets the temperature by resetting the set point of the flow controller on the QW feeding the reboiler. The Deethanizer LP Steam Reboiler is provided for use as a startup/spare reboiler. The Deethanizer bottoms product, which contains C3 and heavier components, is pumped by the Deethanizer Bottoms Pumps to the MAPD Trim Reactor Feed Cooler. On-line analyzers are provided in the net overhead vapor product and bottoms product to measure their compositions, and tower separation performance. 2.4.2.17

Ethylene Fractionation

The Ethylene Fractionator is comprised of multiple valve trays and its primary purpose is to produce 99.95 mol.% ethylene overhead product, as well as high purity ethane bottoms product which is recycled to the cracking heater feed system. The net overhead vapor product from the Deethanizer Reflux Drum is fed to the Ethylene Fractionator. The gross overhead vapor of the fractionator is totally condensed against -40°C propylene refrigerant in the Ethylene Fractionator Condenser before it enters the Ethylene Fractionator Reflux Drum. The tower overhead pressure is set by a pressure controller in the gross overhead line which controls the amount of propylene refrigerant sent to the condenser. In a high pressure scenario, a second pressure controller will open a normally closed vent on the reflux drum to the Cold Flare. If any non-condensables accumulate in the reflux drum, a hand control (HC) provides the ability to send this material back to the Demethanizer for reprocessing. The liquid from the reflux drum, ethylene product, is pumped by the Ethylene Fractionator Reflux Pumps and sent back to the tower as reflux. A portion of this ethylene product is sent on flow ratio control to the OSBL storage spheres, maintaining a constant ratio to the reflux flow. This prevents exporting offspec Ethylene Product. The level controller on the reflux drum resets the reflux flow and, therefore, the product draw-off rate. Onspec HP Ethylene from OSBL storage is pumped to the Offgas Exchanger No. 6 in the cold box to heat the stream, before it is vaporized in the kettle side of the Ethylene Product Vaporizer by 9°C Page 23 of 31

CONFIDENTIAL

2/14/2017

Lummus Petrochemicals Bloomfield, NJ CLIENT PROJECT

HMEL (HPCL Mittal Energy Ltd) Petrochemical Complex

222334

Process Description

Proj. No.

DOCUMENT NAME

propylene refrigerant. The vaporized ethylene from product vaporizer undergoes more heating in Offgas Exchanger No. 6, and is sent as HP Ethylene Product Vapor to OSBL. A continuous ethylene rundown stream is withdrawn from the Ethylene Fractionator Reflux Drum and is chilled by binary refrigerant in the Ethylene Rundown Chiller. The ethylene rundown (in liquid phase) is sent to OSBL Storage. A level controller in OSBL Storage, sends a high level override to control the flow if the level gets too high. Higher levels of rundown can be achieved during SCU turn down. Tower reboiler duty is provided by two reboilers which permits the maximum cold recuperation from this tower. In the kettle type Ethylene Fractionator Side Reboiler a liquid stream withdrawn from the tower is vaporized by -10°C propylene refrigerant. In the Ethylene Fractionator Reboiler a portion of the bottom sump is vaporized by 9°C propylene refrigerant. . The Ethylene Fractionator bottoms product, ethane recycle, is sent to the cold box. In the cold box, the ethane recycle is heated and vaporized in the Offgas Exchangers No. 5 and 6 before is recycled back to the cracking heater feed system. On-line analyzers are provided on the overhead and bottoms product to ensure product specifications are met. 2.4.2.18

MAPD Conversion

The Deethanizer bottoms is blended with an MAPD Converter recycle stream, and is cooled in the MAPD Trim Reactor Feed Cooler by cooling water. The effluent from the cooler is sent on flow control to MAPD Converter. Hydrogen from the PSA is blended with cooled effluent from MAPD Trim Reactor Feed Cooler. A temperature controller sets this combined stream temperature by controlling the amount of the Deethanizer bottoms stream bypasses the cooler prior to entering the MAPD Converter. The MAPD Converter is a trickle flow (down flow) single trim reactor system which reduces the MAPD content in the effluent stream to specification levels. The amount of hydrogen injected is just slightly above the amount required to saturate the MAPD so there is not any need for a separator on the outlet. There is a distributor inside of the reactor to ensure that the hydrogen is properly mixed. As the liquid reacts with H2 in the reactor a noticeable temperature rise will occur, which leads to vaporization. A vapor product is removed from the bottom of the converter on back pressure control sent to the Propylene Fractionator No. 1. Maintaining back pressure, ensures the liquid in the converter bottom sump has enough pressure to be sent to the fractionator. A portion of the bottom liquid product from the converter is recycled back to the feed by the MAPD Recycle Pumps which helps control temperature rise, and henceforth, controlling the vaporization that occurs in the reactor. On-line analyzers detect the MAPD, propylene, and propane on the feed and product sides of the MAPD Converter. If too much hydrogen is added, the reactor may become less selective, so it is important to closely monitor this during operation.

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CONFIDENTIAL

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2.4.2.19

HMEL (HPCL Mittal Energy Ltd) Petrochemical Complex

222334

Process Description

Proj. No.

DOCUMENT NAME

Propylene Fractionation

The two towers, Propylene Fractionator No. 1 and No. 2, work together as essentially one propylene fractionator. The feed to this system is effluent from the MAPD Converter which enters Propylene Fractionator No.1. The primary purpose of this upper tower is to produce 99.5 mol.% propylene product, while the lower tower produces a high purity propane bottoms product which is recycled to the cracking heater feed system. The gross overhead vapor of Propylene Fractionator No. 1 is totally condensed against cooling water in the Propylene Fractionator Condenser before it enters the Propylene Fractionator Reflux Drum. The tower overhead pressure is set by a “hot vapor bypass”, where a portion of the gross overhead bypasses the condenser and is fed directly to the reflux drum. Depending on the amount of material that bypasses the condenser, the operating pressure of the reflux drum will change. By changing the pressure difference between the condenser and the reflux drum, the liquid level in the condenser will expose or submerge more condenser tubes. A second pressure controller in the gross overhead line which controls the amount of cooling water sent to the condenser. In a high pressure scenario, a hand control can open a vent on the reflux drum to the Cold Flare. A continuous vent from the reflux drum is cooled in the Propylene Fractionator Vent Condenser by cooling water where any liquid that condenses is sent back to nd the CGC 2 Stage Discharge Drum. Any non-condensables are sent on flow control to the Charge Gas nd Compressor 2 Stage Discharge Drum. In a low pressure scenario, the pressure controller on the gross nd overhead vapor line will cut back on the amount of vented to the CGC 2 Stage Discharge Drum. The liquid from the reflux drum, is pumped by the Propylene Fractionator No. 1 Reflux Pumps and sent as reflux to the top of Propylene Fractionator No. 1. A pasteurization section is provided at the top of Propylene Fractionator No.1 to strip residual hydrogen added in the MAPD Converter from the propylene. The propylene product (99.5% purity) is withdrawn as a side draw from tower No. 1, and is pumped by the Propylene Product Pumps and sent to the Propylene Treater Feed Cooler. A flow ratio controller controls this product side-draw, maintaining a constant ratio to the reflux flow. This prevents the draw-off of off-spec Propylene Product. Tower reboiler duty for tower Propylene Fractionator No. 1 is provided by quench water sent to the Propylene Fractionator No. 1 Reboiler. The bottoms product of tower No. 1 is pumped by the Propylene Fractionator No. 2 Reflux Pump as reflux to the top of Propylene Fractionator No. 2. The overhead vapor of Propylene Fractionator No.2 is sent to the bottom of Propylene Fractionator No. 1. Tower reboiler duty for the tower No. 2 is provided by provided by quench water sent to the Propylene Fractionator No. 2 Reboiler. The tower bottoms product, primarily propane, is sent to the Propane Feed Vaporizer and the C4/C5 Feed Vaporizer Drum in the furnace feed system. On-line analyzers are provided on the overhead and bottoms product to ensure product specifications are met.

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CONFIDENTIAL

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2.4.2.20

HMEL (HPCL Mittal Energy Ltd) Petrochemical Complex

222334

Process Description

Proj. No.

DOCUMENT NAME

Propylene Product System

Propylene product from the Propylene Product Pumps is cooled by cooling water in the Propylene Treater Feed Cooler before entering the PG Propylene Treaters. In the Propylene Treaters, the polymer grade propylene product is treated for reduction of COS to trace levels (<30 ppbw). The treated polymer grade propylene is filtered then split into two streams. The first is a propylene rundown stream which is chilled by propylene refrigerant in the Propylene Rundown Chiller Package. The propylene rundown (in liquid phase) is sent to OSBL HP Storage. A level controller in OSBL Storage, sends a high level override to control the flow if the level gets too high. Higher levels of rundown can be achieved during SCU turn down. The second stream continues to OSBL HP Liquid Propylene Storage. Polymer grade propylene is pumped from HP storage to product conditions. A provision is made for offspec propylene product to be reprocessed in the Deethanizer. One PG Propylene Treater is in operation while the second treater is being regenerated or on standby. On-line analyzers are provided to detect the amounts of COS entering and leaving the treaters. A third probe is placed in the bottom portion of the treater to detect breakthrough of impurities. Regeneration of the PG Propylene Treaters is carried out by circulating hot methane-rich regeneration gas from the Treater Regeneration Gas Electric Heater at 290°C to drive out the impurities adsorbed in the treater bed. After the bed has reached the required temperature, the bed is cooled with unheated regeneration gas. The spent regeneration gas is returned to the fuel gas system. 2.4.2.21

Debutanization

The LP Depropanizer bottoms stream containing C4 and heavier material is fed to the Debutanizer. Polymerization Inhibitor from the Polymerization Inhibitor Package is injected into the main feed to the Debutanizer to limit fouling in the tower. The Debutanizer is comprised of multiple valve trays and the primary purpose of this tower is to separate a mixed C4 product sent to the Total Hydrogenation Unit (THU) from a C5+ raw pyrolysis gasoline product sent to the Pyrolysis Gasoline Hydrogenation (PGH) unit. The gross overhead vapor of the Debutanizer is totally condensed in the Debutanizer Condenser by cooling water before it enters the Debutanizer Reflux Drum. The tower overhead pressure is set by a “hot vapor bypass”, where a portion of the gross overhead bypasses the condenser and is fed directly to the reflux drum. In a high pressure scenario, a second pressure controller in the gross overhead vapor line can open a vent on the reflux drum to the Wet Flare. If any non-condensables accumulate in the reflux drum, a hand control (HC) provides the ability to send this material back to the Quench Tower for reprocessing. Total liquid from the reflux drum is pumped by the Debutanizer Reflux Pumps and a portion is sent as reflux back to the tower. The remaining overhead liquid product is sent to the THU. A provision is made to send this mixed C4 product to OSBL storage; the ability to inject TBC into this stream (to limit polymerization) is provided from the TBC Inhibitor Injection System. Tower reboiler duty is provided by Low Pressure (LP) Steam in the Debutanizer Reboiler. A tray temperature controller sets the temperature by resetting the set point of the flow controller on the LP feeding the reboiler. The bottoms temperature of 130°C should be closely monitored and controlled to limit fouling. The Debutanizer bottoms product, which is raw pyrolysis gasoline, is sent to the PGH unit. Page 26 of 31

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HMEL (HPCL Mittal Energy Ltd) Petrochemical Complex

222334

Process Description

Proj. No.

DOCUMENT NAME

The raw pyrolysis gasoline is combined with gasoline from the Quench Tower, and cooled in the Pyrolysis Gasoline Cooler by cooling water. Gasoline Polymerization Inhibitor from the Gasoline Polymerization Inhibitor Package is injected into the raw pyrolysis gasoline product. An on-line analyzer is provided to detect the top specification of the Debutanizer with measurements made for C3 and C5 components. A second on-line analyzer detects C4 components that end up in the raw pyrolysis gasoline product. 2.4.2.22

Propylene Refrigeration System

The Propylene Refrigeration system is a closed loop four stage system, which utilizes a steam turbine driven centrifugal compressor. The system provides refrigeration at four levels: -40°C, -27°C, -10°C and 9°C. The compressor discharge vapor is desuperheated and condensed by cooling water. The liquid propylene refrigerant is subcooled against cold streams in the ROG and SCU areas before being used at each level. During normal operation, propylene vapor extracted from the compressor 2nd stage discharge is condensed against the ethylene fractionator side reboiler. Major propylene refrigeration users in the SCU are the ethylene fractionator condenser, the binary refrigerant condenser and the HP and LP depropanizer condensers. Other users are the charge gas area and Demethanizer feed chilling. The propylene refrigeration system also provides cooling to the ROG, PGH, and THU. 2.4.2.23

Binary Refrigeration System

The binary refrigeration system is a two-component, constant composition mixed refrigeration system composed of methane and ethylene. It is a closed, three stage system utilizing a steam turbine driven centrifugal compressor and dry mechanical seals. The system provides four levels of refrigeration to the ethylene unit users from -40°C to -134°C. It supersedes the ethylene and methane refrigeration systems of older plants. The binary refrigerant (BR) compressor discharge vapors are cooled first against cooling water, partially condensed against three levels of propylene refrigerant and finally condensed against itself in the cold box. The condensed BR is sub-cooled against Demethanizer bottoms and further sub-cooled against highest level BR. A portion of the sub-cooled BR stream is then let down to a lower pressure and fully vaporized by the process users on each level. The remaining BR stream flows to the next lowest level where it is again further sub-cooled and partially let down. Since the system has a constant composition, it is not subject to the fluctuations in refrigeration temperature that can be the case with other mixed refrigeration systems. Makeup ethylene liquid is provided from HP ethylene storage while liquid methane is provided from the Demethanizer Reflux Drum. In addition, ethylene vapor is provided from the LP ethylene product header while makeup methane vapor is provided from the Demethanizer Reflux Drum. The binary refrigeration system also provides cooling to the ROG unit.

Page 27 of 31

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2.4.3

HMEL (HPCL Mittal Energy Ltd) Petrochemical Complex

222334

Process Description

Proj. No.

DOCUMENT NAME

Total Hydrogenation Unit (THU)

The Total Hydrogenation Unit is designed to operate in two modes. For Design Case-1, the THU will totally hydrogenate the mixed C4’s from the Debutanizer, the C4+ from the ROG Depentanizer and the C5’s from the Pyrolysis Gasoline Hydrogenation (PGH) unit Depentanizer. For Design Case-2, the THU will partially hydrogenate only the mixed C4’s from the Debutanizer and the C4+ from the ROG Depentanizer; the C5’s are recycled directly to the Cracking Heaters. The mixed C4’s and C4+ feedstock flows to the C4/C5 Feed Surge Drum, where it is combined with C5 recycle from the PGH Unit (only for Design Case-1). In the feed surge drum, any entrained water, if present, is separated. The feed is then pumped by the C4/C5 Feed Pump to reactor pressure and mixed with liquid recycle stream prior to entering the C4/C5 Hydrogenation Reactor. The THU consists of two reactors; one operating and one spare. A single reactor may operate up to 1 year between regenerations. When End-of-Run conditions are reached, the catalyst is regenerated insitu using a conventional steam and air procedure. During the catalyst regeneration period, the spare reactor may be used for processing the feed. The recycle liquid from the C4/C5 HP Flash Drum is heated against liquid effluent from the reactor in the C4/C5 Reactor Feed/Effluent Exchanger prior to mixing with the feed. This recycle liquid is required to limit vaporization and temperature rise across the reactor. The reactor inlet temperature is controlled by relative amounts of hot and cold recycle by bypassing the effluent exchanger. A feed preheater, using MP Steam is provided for start-up only. The majority of the hydrogen from the PSA Unit is added to the top bed on flow control while interbed hydrogen injection is added on pressure control. The mixed phase feed passes downward through the top catalyst bed where most of the butadiene and other diolefins are hydrogenated. The remaining olefins are hydrogenated in the second bed. The exothermic heat of reaction causes the temperature to rise. Liquid effluent from the reactor is cooled in the C4/C5 Reactor Feed/Effluent Exchanger. After combining with the vapor effluent from the reactor, the mixture is partially condensed against cooling water in the C4/C5 Reactor Effluent Condenser. Effluent from the condenser passes to the C4/C5 HP Flash Drum where liquid recycle is separated and returned to be mixed with fresh feed to the reactor. The C4/C5 HP Flash Drum vapor is chilled against Propylene Refrigerant in a vent condenser. Liquid from the vent condenser flows back to the flash drum and non-condensables are recycled upstream of the Caustic Tower Effluent Cooler for recovery. The net liquid product is withdrawn from the C4/C5 HP Flash Drum and recycled back to the C4/C5 Feed Vaporizer Drum, where it is co-cracked in the Cracking Heaters with the Propane Recycle from the Propylene Fractionator No.2 bottoms.

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CONFIDENTIAL

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Lummus Petrochemicals Bloomfield, NJ CLIENT PROJECT

2.4.4

HMEL (HPCL Mittal Energy Ltd) Petrochemical Complex

222334

Process Description

Proj. No.

DOCUMENT NAME

Pyrolysis Gasoline Hydrogenation Unit (PGH)

The Pyrolysis Gasoline Hydrogenation Unit (PGH) is designed to hydrotreat and fractionate raw pygas from the SCU and to produce the following products: 

C5 Cut Product



C6 Cut – Light Pygas to Aromatics Extraction Unit



C7-C8 Cut – Heavy Pygas Product



C9+ Cut – Heavy Product

2.4.4.1

First Stage PGH Reaction

Raw Pyrolysis Gasoline from the Debutanizer bottoms and Quench Tower after cooling through the Pyrolysis Gasoline Cooler is fed via filters, for the removal of solids, to the Pyrolysis Gasoline Coalescer, for removal of any free water. The Raw Pyrolysis Gasoline is then fed to the Pyrolysis Gasoline Surge Drum where it is then pumped by the PGH First Stage Reactor Feed Pumps to the PGH First Stage Reactor. The PGH First Stage Reactor system consists of two catalyst reactors, one operating and one spare. The fresh feed is mixed with recycle liquid before entering the reactor. Make-up high purity hydrogen from the PSA Unit, required for reaction, is charged separately to the reactor and enters the top of the reactor under pressure control and travels down through the catalyst bed in intimate contact with the liquid phase. The principal reactions occurring are the selective hydrogenation of diolefin, styrene, and indene compounds to olefins, alkyl benzene, and indane, respectively. A portion of the olefins present are also hydrogenated. Pressure drop across the reactor increases from Start-of-Run to End-of-Run. In addition, catalyst activity decreases with time, requiring raising the reactor inlet temperature. Reactor inlet temperature is set by controlling the ratio of hot and cold recycle flow in accordance with a fixed total recycle flow by bypassing the PGH First Stage Reactor Heater. The total quantity of recycle is controlled to limit the exothermic temperature rise across the reactor. The total quantity of recycle flow also serves to control fouling. When the upper limit of operating temperature or pressure drop is reached and product quality can no longer be maintained, the catalyst is regenerated in-situ using the reactor regeneration system (common with the SCU) by a conventional steam/air procedure. The off-line reactor can be regenerated while the other reactor is on-stream. Each reactor system has its dedicated recycle pump, recycle cooler and recycle heater. The reactor net effluent is cooled by the PGH First Stage Reactor Offgas Cooler against cooling water and sent to the PGH First Stage HP Flash Drum where hydrogen-rich gas is separated from the liquid product. Hydrogen-rich gas from this flash drum is sent to the PGH Recycle Compressor Suction Drum in the PGH second stage system providing part of the hydrogen make-up requirements for the PGH Second Stage Reactor. The liquid flows to the PGH First Stage LP Flash Drum where additional hydrogen-rich gas is separated from the liquid product. Hydrogen-rich gas from this flash drum is combined with Page 29 of 31

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Lummus Petrochemicals Bloomfield, NJ CLIENT PROJECT

HMEL (HPCL Mittal Energy Ltd) Petrochemical Complex

222334

Process Description

Proj. No.

DOCUMENT NAME

Depentanizer vent gas and LP Offgas from the H2S Stripper prior to being sent to the Charge Gas nd Compressor 2 Stage Suction Drum. The product liquid flows from the LP Flash Drum to the Depentanizer for recovery of the C5 fraction. 2.4.4.2

First Stage PGH Fractionation

PGH first stage effluent flows to the Depentanizer where the partially hydrogenated feed is separated into a C5 cut product stream and a C6+ stream. The tower is reboiled using MP steam in the Depentanizer Reboiler, which is desuperheated to reduce fouling, and the overhead is condensed against cooling water by the Depentanizer Condenser. The duty of the reboiler is controlled by a tray temperature controller where the bottoms temperature is maintained below 150C to minimize fouling. The net C5 overhead product is pumped by the Depentanizer Reflux Pumps and cooled by the C5 Product Cooler against cooling water before being recycled to the Naphtha cracking heaters in the SCU. A portion of the net C5 overhead is recycled to the Total Hydrogenation Unit (THU). The balanced overhead product is recycled back to the tower as reflux. Pressure in the Depentanizer Reflux Drum is controlled by purging of noncondensables to the SCU CGC system. The C6+ bottoms product flows to the BTX Tower. Depentanized PGH first stage effluent contains a high concentration of gum-forming compounds which must be removed prior to hydrogenation in order to prevent fouling. These compounds are removed in the BTX Tower. In the BTX Tower, the C6+ from the bottom of the Depentanizer is fractionated into two cuts: a C6-C8 heart cut and a C9+ stream. The C9+ stream is cooled against cooling water in the C9 Plus Product Cooler and sent to battery limits. The BTX Tower is reboiled using MP steam in the BTX Tower Reboiler, which is desuperheated to minimize fouling, and the tower overhead is condensed with cooling water by the BTX Tower Condenser. A forced-circulation reboiler is used in order to limit fouling of the reboiler tubes. The BTX Tower is operated under vacuum to lower the bottom temperature in order to minimize fouling. Additionally, bottoms temperature is maintained below 160C to minimize fouling. Non-condensable off gases are boosted using an ejector system, using MP steam as motive fluid, to a pressure high enough to send the off gas the thermal oxidizer. The net C6-C8 overhead heart cut product from the overhead of the BTX Tower is pumped to the discharge of the PGH Recycle Compressor just before the PGH Second Stage Feed/Effluent Exchanger. The balanced C6-C8 overhead is recycled back to the tower as reflux. 2.4.4.3

Second Stage PGH Reaction

First stage treated C6-C8 heart cut from the PGH Second Stage Reactor Feed Pumps is mixed with hydrogen-rich recycle gas from the PGH Recycle Compressor. The two-phase mixture is heated by heat exchange against the PGH Second Stage Reactor effluent in the PGH Second Stage Feed/Effluent Exchanger to the required reactor inlet temperature. An HP steam exchanger is provided for start-up and supplemental feed heating for EOR operation. Feed to the PGH Second Stage Reactor is 100% vapor. In the PGH Second Stage Reactor, the olefins present in the feed are hydrogenated, and the sulfur compounds are converted to hydrocarbons and H2S over the catalyst. The reactions are exothermic resulting in a temperature rise across the reactor which is moderated by the recycle gas. The reactor effluent preheats the reactor feed before finally being cooled and partially condensed against cooling water in the PGH Second Stage Reactor Effluent Condenser. Page 30 of 31

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HMEL (HPCL Mittal Energy Ltd) Petrochemical Complex

222334

Process Description

Proj. No.

DOCUMENT NAME

Pressure drop across the reactor increases from Start-of-Run to End-of-Run. In addition, catalyst activity decreases with time, requiring raising the reactor inlet temperature. When the upper limit of the operating temperature or pressure drop range is attained, the catalyst is regenerated in-situ, using the reactor regeneration system (common with the SCU) by a conventional steam/air procedure. The PGH Second Stage Reactor system consists of two catalyst reactors, one operating and one spare. The off-line reactor can be regenerated while the other reactor is on-stream. The cooled vapor/liquid reactor effluent mixture is separated in the PGH Second Stage HP Flash Drum. The major portion of the vapor leaving this drum is mixed with the hydrogen vent gas from the PGH First Stage Reactor section and additional high purity hydrogen from the PSA Unit which is then sent to the PGH Recycle Compressor Suction Drum. Vapor from this drum is compressed in the PGH Recycle Compressor and mixed with the C6-C8 heart cut from the PGH first stage. A small net vent flow from the PGH Second Stage HP Flash Drum is sent upstream of the Caustic Tower Effluent Cooler to purge inerts and maintain an optimum hydrogen balance. The liquid leaving the PGH Second Stage HP Flash Drum is fed to the H2S Stripper via the H2S Stripper Feed/Bottoms Exchanger. 2.4.4.4

Second Stage PGH Fractionation

Second stage treated C6-C8 heart cut from the PGH Second Stage HP Flash Drum flows to the H2S Stripper where H2S and light gasses are stripped from the heart cut product. The H2S Stripper operates at sufficient pressure to send the stripped C6-C8 product to the Dehexanizer. The overhead from the H2S Stripper is partially condensed against cooling water in the H2S Stripper Condenser. The tower is reboiled using MP steam. The duty of the H2S Stripper Reboiler is set by the flow control of the overhead stream. H2S and light gases are removed in the H2S Stripper and are vented nd from the H2S Stripper Reflux Drum to the Charge Gas Compressor 2 Stage Suction Drum. The condensed overhead is recycled back to the stripper as reflux via the H2S Stripper Reflux Pumps. The bottoms product of the H2S Stripper is cooled by preheating the H2S Stripper feed which then flows to the Dehexanizer. In the Dehexanizer, treated C6-C8 heart cut is fractionated into two cuts: C6 product and C7-C8 product. The Dehexanizer is reboiled using MP steam and the tower overhead is condensed with cooling water in the Dehexanizer Condenser. The duty of Dehexanizer Reboiler is controlled by a tray temperature controller. The net overhead C6 product is pumped by the Dehexanizer Reflux/Product Pumps, cooled in the C6 Product Cooler against cooling water and then sent to the Aromatics Extraction Unit (AEU). Provisions are made to send the C6 cut product to OSBL storage and to send a portion as diluent for the PGH Antioxidant Injection Package. The balanced C6 overhead product is recycled back to the tower as reflux. The bottoms product is pumped by the Dehexanizer Bottom Pumps, cooled against cooling water in the C7-C8 Product Cooler, and then sent to OSBL storage. Provisions are made for antioxidant injection into the C6 cut and C7-C8 cut products sent to OSBL.

Page 31 of 31

CONFIDENTIAL

2/14/2017

Lummus Petrochemicals Bloomfield, NJ CLIENT PROJECT

2.5

HMEL (HPCL Mittal Energy Ltd) Petrochemical Complex

222334

Process Flow Diagrams

Proj. No.

DOCUMENT NAME

Process Flow Diagrams

PFD NO. A1-222334-1200A A1-222334-1200B A1-222334-1200C A1-222334-1200D A1-222334-1200E A1-222334-1200F A1-222334-1200G

AREA ROG Amine System ROG Caustic Water Wash ROG Oxygen Converter ROG Dryer/Treater ROG Chilling & Demethanizer ROG Depropanizer ROG DGA Storage

A1-222334-2000A A1-222334-2000B A1-222334-2000C A1-222334-2000D A1-222334-2100A A1-222334-2100B A1-222334-2100C A1-222334-2100D A1-222334-2200A A1-222334-2200B A1-222334-2200C A1-222334-2200D A1-222334-2200E A1-222334-2200F A1-222334-2200G A1-222334-2200H A1-222334-2200J A1-222334-2300A A1-222334-2300B A1-222334-2300C A1-222334-2300D A1-222334-2400A A1-222334-2400B A1-222334-2400C A1-222334-2400D A1-222334-2400E A1-222334-2500A A1-222334-2500B A1-222334-2600A A1-222334-2600B

Cracking Heater Feed System SRT-VI Cracking Heaters F-20001 SRT-VII Cracking Heaters F-20002 thru F-20007 Cracking Heater Steam Drum Blowdown System Gasoline Fractionator and Pyrolysis Fuel Oil Stripper Quench Tower Process Water Stripper and Dilution Steam Generation Flux Oil/Wash Oil Storage Charge Gas Compression Stages 1 & 2 Acid Gas Removal – Amine System Acid Gas Removal – Caustic Water Wash Charge Gas Compression Stage 3 Spent Caustic Pretreatment Charge Gas Drying and Regeneration Front-End High Pressure Depropanizer Front-End Low Pressure Depropanizer SCU MEA Storage Charge Gas Chilling Train (Part 1 of 2) Charge Gas Chilling Train (Part 2 of 2) Demethanizer Hydrogen Purification & Fuel Gas System Deethanizer Ethylene Fractionation and Ethylene Product System Propylene Fractionation Debutanizer Propylene Product System Propylene Refrigeration System (Part 1 of 2) Propylene Refrigeration System (Part 2 of 2) Binary Refrigeration System (Part 1 of 2) Binary Refrigeration System (Part 2 of 2)

A1-222334-2700A

C4/C5 Hydrogenation Unit

A1-222334-2800A A1-222334-2800B A1-222334-2800C A1-222334-2800D

PGH First Stage Reactor PGH Depentanizer PGH Second Stage Reactor and H2S Stripper PGH Dehexanizer and BTX Columns

A1-222334-3100A

ISBL Flare Knockout Drums

Page 1 of 1

CONFIDENTIAL

2/14/2017

1

2

3

5

4

A

6

C-12001

E-12024

ROG DGA/WATER WASH COLUMN

LEAN DGA COOLER

7

8

9

10

11

12

13

E-12020

E-12021A/B

C-12020

E-12023

E-12022

V-12020

V-12021

LEAN DGA/RICH DGA EXCHANGER

DGA REGENERATOR REBOILER

DGA REGENERATOR

DGA REGENERATOR CONDENSER

DGA RECLAIMER

DGA REGENERATOR REFLUX DRUM

DGA REGENERATOR HP FLASH DRUM

14

15

16

NOTES:

A

1. TEMPERATURES & PRESSURES ARE SHOWN FOR CASE 1 OPERATION UNLESS OTHERWISE INDICATED. 2. FLOW MEASUREMENTS PRESSURE AND TEMPERATURE COMPENSATED.

TO WET FLARE

B

B PC PC PC

C kg/cm²g

C

48 9.0

C

FC ACID GAS FLARE

CW

N2

TC LC

D

D C kg/cm2g

E

E LC

FC SP FC

F

F C kg/cm²g

LC

54 9.3

SP

G

FC

TO AMINE DRAIN SYSTEM LP STEAM

DESUPERHEATED MP STEAM

LC

LP COND.

H

G

FC

H NNF

TC

MP COND.

CW NNF

J NNF

J

MP STEAM

CONDENSATE

K

LC

LC FC

REV

A H2S CO2 C1 C2H4 C2H6 C3H6 C3H8 C4+

TO OSBL

C kg/cm²g

WASH WATER FROM E-20014

L

40 9.5

DWG. 2000D

M

DESCRIPTION

CAD

PROC LPE PDM ENG

CLIENT

PM

"THIS DOCUMENT IS THE PROPERTY OF LUMMUS TECHNOLOGY INC. (LUMMUS). IT CONTAINS CONFIDENTIAL INFORMATION DESCRIBING TECHNOLOGY OWNED BY LUMMUS. IT IS TO BE USED ONLY IN CONNECTION WITH WORK PERFORMED BY LUMMUS. REPRODUCTION IN WHOLE OR IN PART FOR ANY PURPOSE OTHER THAN WORK PERFORMED BY LUMMUS IS FORBIDDEN EXCEPT BY EXPRESS WRITTEN PERMISSION OF LUMMUS. IT IS TO BE SAFEGUARDED AGAINST BOTH DELIBERATE AND INADVERTENT DISCLOSURE TO ANY THIRD PARTY."

REFINERY OFF GAS FROM

HYDROCARBON TO C-21003

VENT TO K-12001

MAKEUP AMINE FROM T-12001

20% CAUSTIC SOLUTION FROM P-22008A/B

DWG. 1200B

DWG. 2200C

OSBL

DWG. 2100B

DWG. 1200C

DWG. 1200G

DWG. 2200C

DGA SLUDGE TO DRUMS

5

6

7

8

9

10

M

DOC. No:

6

4

11

L

PROCESS FLOW DIAGRAM REFINERY OFF GAS (ROG) UNIT AMINE SYSTEM

BL

WASH WATER TO NEUTRALIZATION

3

RK

LUMMUS PETROCHEMICALS

BL

2

ISSUE DATE

FC

REFINERY OFF GAS TO C-12002

1

K

FEB 0 2017 FOR PROPOSAL

12

13

14

SCALE:

NONE

DWG. No:

15

REV:

A1-222334-1200A 16

0

1

2

3

5

4

A

6

7

8

9

10

11

12

13

C-12002

E-12003

V-12005

ROG CAUSTIC/WATER WASH TOWER

ROG DRYER/TREATER FEED CHILLER

ROG DRYER/TREATER FEED GAS KO DRUM

14

15

16

NOTES: A

1. TEMPERATURES & PRESSURES ARE SHOWN FOR CASE 1 OPERATION UNLESS OTHERWISE INDICATED.

B

B TC

C kg/cm²g

TO TCV ON E-12003 C3R INLET DWG. 2500B

9°C C3R DWG. 2500B

FC

C kg/cm²g

C

C LC LC

D

D

LC

LC C kg/cm²g

E

E

C kg/cm²g

FC

#2 LC

A

#1

FI

G

F

LOW LEVEL OVERRIDE

CO2 H2S

F

G

LC PV

FFC

"A"

NNF

C kg/cm²g

NNF

H

H

FI "B" NNF

J

J

FC

NNF

K

P-12001A/B

P-12002A/B

ROG WEAK CAUSTIC CIRCULATION PUMPS

ROG STRONG CAUSTIC CIRCULATION PUMPS

K

FEB 0 2017 FOR PROPOSAL REV

ISSUE DATE

RK

DESCRIPTION

CAD

PROC LPE PDM ENG

CLIENT

PM

LUMMUS PETROCHEMICALS "THIS DOCUMENT IS THE PROPERTY OF LUMMUS TECHNOLOGY INC. (LUMMUS). IT CONTAINS CONFIDENTIAL INFORMATION DESCRIBING TECHNOLOGY OWNED BY LUMMUS. IT IS TO BE USED ONLY IN CONNECTION WITH WORK PERFORMED BY LUMMUS. REPRODUCTION IN WHOLE OR IN PART FOR ANY PURPOSE OTHER THAN WORK PERFORMED BY LUMMUS IS FORBIDDEN EXCEPT BY EXPRESS WRITTEN PERMISSION OF LUMMUS. IT IS TO BE SAFEGUARDED AGAINST BOTH DELIBERATE AND INADVERTENT DISCLOSURE TO ANY THIRD PARTY."

L

PROCESS FLOW DIAGRAM REFINERY OFF GAS (ROG) UNIT CAUSTIC/WATER WASH

NNF

M

REFINERY OFF GAS FROM E-12006

REFINERY OFF GAS TO E-12004

REFINERY OFF GAS FROM C-12001

SPENT CAUSTIC TO TREATMENT M-22002

20% CAUSTIC SOLUTION FROM P-22008A/B

WASTE WATER TO SPENT CAUSTIC NEUTRALIZATION

WASH WATER FROM E-20014

REFINERY OFF GAS TO V-12006A/B

DWG. 1200C

DWG. 1200C

DWG. 1200A

DWG. 2200E

DWG. 2200C

DWG. 2200C

DWG. 2000D

DWG. 1200D

2

3

4

5

6

7

8

9

10

11

12

13

M

DOC. No:

5

1

14

L

SCALE:

NONE

DWG. No:

15

REV:

A1-222334-1200B 16

0

1

2

3

5

4

A

6

7

8

9

10

K-12001A/B

E-12006

E-12004

E-12005

R-12001A/B

RECYCLE GAS COMPRESSOR

ROG OXYGEN CONVERTER EFFLUENT COOLER

ROG OXYGEN CONVERTER FEED/EFFLUENT EXCHANGER

ROG OXYGEN CONVERTER FEED HEATER

ROG OXYGEN CONVERTER

11

12

13

14

15

16

NOTES: A

1. TEMPERATURES & PRESSURES ARE SHOWN FOR CASE 1 OPERATION UNLESS OTHERWISE INDICATED.

B

B

NNF

C

TO WET FLARE

C

EOR 240 8.4

NNF

START-UP

kg/cm²g

SOR 221 8.4

C

NNF

TO ATM.

D

D

TC

HP COND.

HS

E

E DMDS INJECTION FROM ME-12001

C

SOR 235

EOR 260

REGENERATION

C kg/cm²g

500 1.0

F

F DMDS INJECTION FROM ME-12001

G

G

CWS

H

H

#2

#1

A C2H2 C2H4 CO O2 NOX

J

J

NNF

K

K

FEB 0 2017 FOR PROPOSAL REV

ISSUE DATE

RK

DESCRIPTION

CAD

PROC LPE PDM ENG

CLIENT

PM

LUMMUS PETROCHEMICALS C kg/cm²g

L

AMB 3.0

C kg/cm²g

AMB 3.0

C kg/cm²g

BL VENT FROM V-12021

M

LDPE/HDPE RECYCLE

"THIS DOCUMENT IS THE PROPERTY OF LUMMUS TECHNOLOGY INC. (LUMMUS). IT CONTAINS CONFIDENTIAL INFORMATION DESCRIBING TECHNOLOGY OWNED BY LUMMUS. IT IS TO BE USED ONLY IN CONNECTION WITH WORK PERFORMED BY LUMMUS. REPRODUCTION IN WHOLE OR IN PART FOR ANY PURPOSE OTHER THAN WORK PERFORMED BY LUMMUS IS FORBIDDEN EXCEPT BY EXPRESS WRITTEN PERMISSION OF LUMMUS. IT IS TO BE SAFEGUARDED AGAINST BOTH DELIBERATE AND INADVERTENT DISCLOSURE TO ANY THIRD PARTY."

AMB 3.5

BL

PROCESS FLOW DIAGRAM REFINERY OFF GAS (ROG) UNIT OXYGEN CONVERTER

BL

HDPE RECYCLE

PP RECYCLE

DWG. 1200A

PP RECYCLE TO V-2202

REFINERY OFF GAS TO C-12002

REFINERY OFF GAS FROM C-12002

REACTOR REGEN. GAS FROM E-22031

PURGE GAS TO C-21003

DWG. 2200A

DWG. 1200B

DWG. 1200B

DWG. 2200F

DWG. 2100B

2

3

4

5

6

7

8

9

10

11

12

13

M

DOC. No:

3

1

L

14

SCALE:

NONE

DWG. No:

15

REV:

A1-222334-1200C 16

0

1

2

3

5

4

6

7

8

9

10

11

V-12006A/B

V-12012A/B

ROG DRYER/ TREATER

LPG TREATER

A

12

13

14

15

16

NOTES: A

1. TEMPERATURES & PRESSURES ARE SHOWN FOR CASE 1 OPERATION UNLESS OTHERWISE INDICATED. 2. ONLY USED IF KOG UNIT IS SOWN.

B

B

PC

TO FUEL GAS DWG. 2300D TO WET FLARE

REGENERATION

C

C PRESSURIZING REGENERATION

D

D

#3

E

A

#2

E H2O

#1

#2

F

#1

F

#3

A H2O CO2 H2S NOX NH3

A C2H4 C2H6 C3H6 C3H8 BD C4's C5+

G START-UP

G

FC BULK DRAIN

H

H

P-12008A/B TO FUEL GAS DWG. 23001D

LPG TREATER DRAIN PUMPS

TO WET FLARE

J

J NNF PC

TC FC

PC

NNF

K

FC

L

REGEN GAS FROM ME-23000-E06

REGEN GAS FROM E-24018

REGEN GAS TO E-22009

MIXED LPG TO C-12004

MIXED LPG FROM

MIXED LPG TO ME-12000-E01

REGENERATION GAS TO E-22009

HEEL DRAIN TO C-21003

REGENERATION GAS FROM E-24018

DWG. 1200B

DWG. 1200E

DWG. 2200F

DWG. 2200F

DWG. 2200F

DWG. 1200F

OSBL

DWG. 1200E

DWG. 2200F

DWG. 2100B

DWG. 2200F

4

5

6

7

PROC LPE PDM ENG

CLIENT

PM

8

9

10

11

12

13

L

M

DOC. No:

5

3

CAD

PROCESS FLOW DIAGRAM REFINERY OFF GAS (ROG) UNIT DRYING AND TREATING

BL

TREATED OFF GAS TO ME-12000-E01

2

DESCRIPTION

"THIS DOCUMENT IS THE PROPERTY OF LUMMUS TECHNOLOGY INC. (LUMMUS). IT CONTAINS CONFIDENTIAL INFORMATION DESCRIBING TECHNOLOGY OWNED BY LUMMUS. IT IS TO BE USED ONLY IN CONNECTION WITH WORK PERFORMED BY LUMMUS. REPRODUCTION IN WHOLE OR IN PART FOR ANY PURPOSE OTHER THAN WORK PERFORMED BY LUMMUS IS FORBIDDEN EXCEPT BY EXPRESS WRITTEN PERMISSION OF LUMMUS. IT IS TO BE SAFEGUARDED AGAINST BOTH DELIBERATE AND INADVERTENT DISCLOSURE TO ANY THIRD PARTY."

REFINERY OFF GAS FROM V-12005

1

ISSUE DATE

RK

LUMMUS PETROCHEMICALS

NOTE 2

HEATING GAS

COOLING GAS

SP

HEEL DRAIN

REV

M

K

FEB 0 2017 FOR PROPOSAL

14

SCALE:

NONE

DWG. No:

15

REV:

A1-222334-1200D 16

0

1

2

3

5

4

A

6

7

8

9

10

11

E-12007

ME-12000-E03

V-12007

ROG COLD BOX EXCHANGER No. 1

ROG COLD BOX EXCHANGER No. 2

ROG DEMETHANIZER

ROG DEMETHANIZER REBOILER

ROG DEMETHANIZER CONDENSER

ROG DEMETHANIZER REFLUX DRUM

(PART OF ME-12000)

9°C C3R FROM V-25010 DWG. 2500B

-10°C C3R FROM V-25011 DWG. 2500B

-27°C C3R FROM V-25012 DWG. 2500A

-40°C C3R FROM V-25013 DWG. 2500A

(PART OF ME-12000)

16

1.

A

TEMPERATURES & PRESSURES ARE SHOWN FOR CASE 1 OPERATION UNLESS OTHERWISE INDICATED.

B

TO TCV ON ME-12000-E03 INLET DWG. 2600B

BR FROM V-26004 DWG. 2600B

C BR FROM DWG. 2600B

ME-12000-E01

ME-12000-E02 BR FROM DWG. 2600B

D

ME-12000-E03 D LC

BR FROM DWG. 2600B

OVERRIDE

TO LCV ON V-25010 DWG. 2500B LOW TEMP.

15

NOTES:

C-12003

TC

TC

14

ME-12000-E02

B

E

13

ME-12000-E01 (PART OF ME-12000)

C

12

SP

E

FC

A °C

C2H4 C2H6 C3H8

°C

TO TV DWG. 2600B

°C C

°C

TC

FC

°C

P-12003A/B

B

F

RDG DEMETHANIZER REFLUX PUMPS

°C

F

°C

METHANOL INJECTION ME-12002

A

TO FCV ON E-12007 DWG. 2500B

TC

G

G

PC LC °C

°C

H

H 48° C3R DWG. 2500B

E-12007 METHANOL INJECTION ME-12002

J

J

K

SP A

FC

K

FEB 0 2017 FOR PROPOSAL REV

CH4

ISSUE DATE

RK

DESCRIPTION

CAD

PROC LPE PDM ENG

CLIENT

PM

LUMMUS PETROCHEMICALS P-12004A/B

L

M

"THIS DOCUMENT IS THE PROPERTY OF LUMMUS TECHNOLOGY INC. (LUMMUS). IT CONTAINS CONFIDENTIAL INFORMATION DESCRIBING TECHNOLOGY OWNED BY LUMMUS. IT IS TO BE USED ONLY IN CONNECTION WITH WORK PERFORMED BY LUMMUS. REPRODUCTION IN WHOLE OR IN PART FOR ANY PURPOSE OTHER THAN WORK PERFORMED BY LUMMUS IS FORBIDDEN EXCEPT BY EXPRESS WRITTEN PERMISSION OF LUMMUS. IT IS TO BE SAFEGUARDED AGAINST BOTH DELIBERATE AND INADVERTENT DISCLOSURE TO ANY THIRD PARTY."

NNF

ROG FUEL GAS TO REGENERATION FUEL GAS

ROG HEAVIES

DWG. 2300D

DWG. 1200F

FROM C-12004

MIXED LPG FROM V-12012A/B

TREATED OFF GAS FROM V-12006A/B

DWG. 1200D

DWG. 1200D

ROG DEMETHANIZER BOTTOMS PUMPS

PROCESS FLOW DIAGRAM REFINERY OFF GAS (ROG) UNIT CHILLING & DEMETHANIZER

TREATED C2+ TO C-12004

LIGHTS FROM V-12008

DWG. 1200F

2

3

4

M

DOC. No:

DWG. 1200F

5

1

5

6

7

8

9

10

11

L

12

13

14

SCALE:

NONE

DWG. No:

15

REV:

A1-222334-1200E 16

0

1

2

3

5

4

A

B

6

7

8

9

10

11

12

C-12004

E-12008

E-12009

V-12008

ROG DEPROPANIZER

ROG DEPROPANIZER REBOILER

ROG DEPROPANIZER CONDENSER

ROG DEPROPANIZER REFLUX DRUM

13

14

15

16

NOTES: 1.

A

TEMPERATURES & PRESSURES ARE SHOWN FOR CASE 1 OPERATION UNLESS OTHERWISE INDICATED.

B

TO PCV ON C3R DWG. 2500A

PC PC

C

C

C kg/cm²g

D

TO COLD FLARE

D

HC

NNF

-27°C C3R DWG. 2500A

E

E NNF C kg/cm²g

LC

F

F

TC

C kg/cm²g LC METHANOL INJECTION ME-12002

SP FC

G LPS

G

NNF

LP COND.

#2

H

A

#1

H

CH4 C2H4 C2H6 C3H6 C3H8

FC

J

J

P-12027A/B

P-12005A/B

ROG DEPROPANIZER BOTTOMS PUMPS

ROG DEPROPANIZER REFLUX PUMPS

LOW LEVEL OVERRIDE

K

FC FC

SP

REV

SP

K

FEB 0 2017 FOR PROPOSAL ISSUE DATE

FC

RK

DESCRIPTION

CAD

PROC LPE PDM ENG

CLIENT

PM

LUMMUS PETROCHEMICALS "THIS DOCUMENT IS THE PROPERTY OF LUMMUS TECHNOLOGY INC. (LUMMUS). IT CONTAINS CONFIDENTIAL INFORMATION DESCRIBING TECHNOLOGY OWNED BY LUMMUS. IT IS TO BE USED ONLY IN CONNECTION WITH WORK PERFORMED BY LUMMUS. REPRODUCTION IN WHOLE OR IN PART FOR ANY PURPOSE OTHER THAN WORK PERFORMED BY LUMMUS IS FORBIDDEN EXCEPT BY EXPRESS WRITTEN PERMISSION OF LUMMUS. IT IS TO BE SAFEGUARDED AGAINST BOTH DELIBERATE AND INADVERTENT DISCLOSURE TO ANY THIRD PARTY."

L

M

TREATED C2+ BOTTOMS FROM P-12004A/B

MIXED LPG

ROG HEAVIES TO THU

ROG HEAVIES WASH TO ME-12000-E01

TREATED C2's/C3's TO C-24001

LIGHTS TO ME-12000-E01

DWG. 1200E

DWG. 1200D

DWG. 2700A

DWG. 1200E

DWG. 2400A

DWG. 1200E

PROCESS FLOW DIAGRAM REFINERY OFF GAS (ROG) UNIT DEPROPANIZER

2

3

4

5

6

7

8

9

10

11

12

M

DOC. No:

3

1

L

13

14

SCALE:

NONE

DWG. No:

15

REV:

A1-222334-1200F 16

0

1

2

3

4

A

5

6

7

8

9

10

11

T-12001

V-12025

DGA STORAGE TANK

DGA DRAIN DRUM

12

13

14

15

16

NOTES:

A

1. TEMPERATURES & PRESSURES ARE SHOWN FOR CASE 1 OPERATION UNLESS OTHERWISE INDICATED. 2. INITIAL DGA FILL FROM TRUCK.

B

B

C

C

D

D

TO ACID GAS FLARE

"B"

E

E

N2

V-12025

"A" PC

LC

ON/OFF

DGA MAKE-UP FROM DRUMS

PM

F

F PC

N2

T-12001 G

G

FC

P-12025

H PM

H

DGA SUMP PUMPS

P-12026A/B DGA MAKEUP PUMPS

FC

J

J TRUCK UNLOADING (NOTE 2)

K

K

FEB 0 2017 FOR PROPOSAL REV

ISSUE DATE

RK

DESCRIPTION

CAD

PROC LPE PDM ENG

CLIENT

PM

LUMMUS PETROCHEMICALS "THIS DOCUMENT IS THE PROPERTY OF LUMMUS TECHNOLOGY INC. (LUMMUS). IT CONTAINS CONFIDENTIAL INFORMATION DESCRIBING TECHNOLOGY OWNED BY LUMMUS. IT IS TO BE USED ONLY IN CONNECTION WITH WORK PERFORMED BY LUMMUS. REPRODUCTION IN WHOLE OR IN PART FOR ANY PURPOSE OTHER THAN WORK PERFORMED BY LUMMUS IS FORBIDDEN EXCEPT BY EXPRESS WRITTEN PERMISSION OF LUMMUS. IT IS TO BE SAFEGUARDED AGAINST BOTH DELIBERATE AND INADVERTENT DISCLOSURE TO ANY THIRD PARTY."

L

M

WATER / DGA MAKEUP TO C-12020

WATER MAKEUP FROM E-20014

DWG. 1200A

DWG. 2000D

PROCESS FLOW DIAGRAM REFINERY OFF GAS (ROG) UNIT DGA STORAGE

DGA DRAIN

2

3

4

5

6

M

DOC. No:

2

1

7

8

L

9

10

11

12

13

14

SCALE:

NONE

DWG. No:

15

REV:

A1-222334-1200G 16

0

1

PROPANE FEED

A

3

2

5

4

PROPANE FEED

VAPORIZER

6

7

ETHANE FEED

HEATER

PREHEATER

8

9

10

11

13

12

E-20018

V-21001

E-20019

E-20025

E-20026

C4/C5 FEED HEATER

C4/C5 FEED VAPORIZER DRUM

C4/C5 FEED VAPORIZER

NAPHTHA FEED PREHEATER

KERO FEED PREHEATER

15

14

16

1. TEMPERATURES & PRESSURES ARE SHOWN FOR CASE 1 OPERATION UNLESS OTHERWISE INDICATED. 2. SIX CRACKING HEATERS ARE IN OPERATION, ONE CRACKING HEATER IS STANDBY.

A

3. SPILLOVER OF PROPANE RECYCLE FOR BALANCING IN CASE 1.

WET FLARE PC

B

MW

TO FC ON C2 FEED DWG. 2000B/2000C

C kg/cm²g

60 8.0

MW

TO FC ON C3 FEED DWG. 2000B/2000C

C kg/cm²g

60 8.0

A

B

PC

A

C

ETHANE

WET FLARE NOTE 2

C

F-20001 DWG. 2000B

D

TO FC ON C4 FEED DWG. 2000B/2000C

A

TC

MW SP FC

SP FC QW DWG. 2100B

C3'S C4'S C5'S

QW DWG. 2100B

C kg/cm²g

F-20002

85 8.0

DWG. 2000C

SP FC

C4/C5

TC

PROPANE

TC

D

F-20003 DWG. 2000C

A C kg/cm²g

LPS

60 8.0

F-20004 DWG. 2000C

TO FC ON NAPHTHA MIX FEED DWG. 2000B/2000C

A DENSITY PIONA

PC

E

F-20005 DWG. 2000C

KEROSENE

TO WET FLARE

NAPHTHA

E

F-20006 DWG. 2000C

F

F

PC PC

PC

C kg/cm²g

G

F-20007

82 8.3

DWG. 2000C C kg/cm²g

TC SP FC SP FC

HIGH LEVEL OVERRIDE

G

TC

LC

H

60 8.0

SP FC QW DWG. 2100B

QW DWG. 2100B

H LPS

TO FC ON C4/C5 RECYCLE DWG. 2700A

FC PC

J

J LC

NOTE 3

NNF

K

NNF

HIGH LEVEL OVERRIDE

QW DWG. 2100B

FC

REV

TO FC ON PROPANE RECYCLE DWG. 2400C

C kg/cm²g

40 9.0

C kg/cm²g

45 12

C kg/cm²g

BL

40 6.0

CAD

PROC LPE PDM ENG

CLIENT

PM

PROPANE RECYCLE FROM C-24004

HYDROGENATED C4/C5's FROM THU

HEAVY LIQUID TO C-21003

NAPHTHA FROM STORAGE

START-UP NAPHTHA TO V-28002

C6 RAFFINATE FROM BZEU (VIA STORAGE)

C5 RECYCLE FROM PGH UNIT

KERO/HEAVY NAPHTHA

DWG. 2300A

DWG. 2400C

DWG. 2700A

DWG. 2100B

OSBL

DWG. 2800A

OSBL

DWG. 2800B

OSBL

3

4

5

6

7

8

9

10

11

12

L

PROCESS FLOW DIAGRAM STEAM CRACKER UNIT CRACKING HEATER FEED SYSTEM

BL

ETHANE RECYCLE FROM ME-23000-E06

2

DESCRIPTION

"THIS DOCUMENT IS THE PROPERTY OF LUMMUS TECHNOLOGY INC. (LUMMUS). IT CONTAINS CONFIDENTIAL INFORMATION DESCRIBING TECHNOLOGY OWNED BY LUMMUS. IT IS TO BE USED ONLY IN CONNECTION WITH WORK PERFORMED BY LUMMUS. REPRODUCTION IN WHOLE OR IN PART FOR ANY PURPOSE OTHER THAN WORK PERFORMED BY LUMMUS IS FORBIDDEN EXCEPT BY EXPRESS WRITTEN PERMISSION OF LUMMUS. IT IS TO BE SAFEGUARDED AGAINST BOTH DELIBERATE AND INADVERTENT DISCLOSURE TO ANY THIRD PARTY."

M

DOC. No:

11

1

ISSUE DATE

RK

LUMMUS PETROCHEMICALS

L

M

K

FEB 0 2017 FOR PROPOSAL

13

14

SCALE:

NONE

DWG. No:

15

REV:

A1-222334-2000A 16

0

1

2

3

A

NOTE 2,3 TO OTHER "B" COILS

B

BIAS

10

11

12

13

14

FC B

TO ATMOSPHERE

FC A PV

16

HC SP

BIAS

SP SP

A

3. CASE 1: SPLIT CRACKING ETHANE (2 COILS) AND PROPANE (2 COILS) IN CELL "A" AND 100% ETHANE CRACKING IN CELL "B" CASE 2: 100% ETHANE CRACKING IN BOTH CELLS.

FROM TDC A

FC A

TO OTHER COIL "A" FC's

SP

FC A

SP

PV

TO OTHER "A" COILS NOTE 2

TO NAPHTHA FC A

PV

SP

O2,NOx, CO

FROM ANALYZER ON FEED LINES DWG. 2000A

6. PURGE STEAM FOR QUENCH FITTINGS, PRESSURE & SAMPLE CONNECTIONS, TLV, DECOKE VALVES. 7. IN OPERATION DURING DECOKING ONLY.

FROM FC B SP

FC A

B

5. ETHANE/PROPANE CRACKED GAS TO VISCOSITY CONTROL FOR F-20001 ONLY. FLOW CONTROL VALVE REQUIRED FOR F-20001 ONLY.

TO OTHER "B" COILS NOTE 2

A

BIAS

SP

4. ONE SAMPLE CONDITIONING SYSTEM PER CELL. MAXIMUM FIVE CONNECTIONS PER ANALYZER.

TO ATMOSPHERE

FFC A

FROM FC's ON OTHER "A" COILS

NNF

SP

15

2. 8 COILS PER HEATER. 4 COILS PER CELL.

NOTE 7

FROM ANALYZER ON FEED LINES DWG. 2000A

C

9

PC

FROM TDC B

PV NOTE 2,3 TO OTHER "A" COIL

8

1. TEMPERATURES & PRESSURES ARE SHOWN FOR CASE 1 OPERATION UNLESS OTHERWISE INDICATED.

FROM FC's ON OTHER "A" COILS TO OTHER COIL "A" FC's

7

TO FFC B

SP

PV

6

NOTES:

FROM FC's ON OTHER "B" COILS PV TO OTHER SP FC SP "B" COIL FC's B FROM ANALYZER ON FEED LINES DWG. 2000A

5

4

FFC B

UFP BFW LFP UMP USSH MSSH LSSH LMP

UFP

= = = = = = = =

UPPER FEED PREHEAT BOILER FEED WATER LOWER FEED PREHEAT UPPER MIXED PREHEAT UPPER STEAM SUPERHEAT MIDDLE STEAM SUPERHEAT LOWER STEAM SUPERHEAT LOWER MIXED PREHEAT

C

BFW NOTE 2,3 TO OTHER "A" COILS

D

D

LFP

AT SUPERHEATER OUTLET UMP FI

E

E DECOKE AIR FROM ME-20001

AT VHP STEAM HEADER

USSH FC

FC

F

F

MSSH TC NOTE 2 TO OTHER "B" COILS

GF

LSSH

NOTE 2 TO OTHER "A" COILS

TDC A

LC LC

TC A

NNF

A

A

O2

O2

TI

CELL "A"

BLOWDOWN TO V-20014 DWG. 2000D

AIR DAMPER

HC HC

ME-20001

QC A

A A

F-20002

NNF

NOTE 5

ME-20002

HC

FROM WOBBE METER DWG. 2300D

REV

ISSUE DATE

DMDS INJECTION FROM ME-12001

QC

QC

PHOSPHATE FREE BFW FROM P-32005A-C

PURGE STEAM FROM E-21010

CRACKED GAS TO C-21001

CRACKED GAS TO C-21002

PHOSPHATE TO F-20002 THRU F-20007

FUEL GAS FROM V-23005

DWG. 2000A

DWG. 2000A

DWG. 2000C

DWG. 3200A

DWG. 2100C

DWG. 2100A

DWG. 2100A

DWG. 2000C

DWG. 2300D

6

7

8

9

10

CAD

PROC LPE PDM ENG

CLIENT

PM

13

L

PROCESS FLOW DIAGRAM STEAM CRACKER UNIT SRT VI CRACKING HEATER F-20001

VHP STEAM TO HEADER

12

DESCRIPTION

"THIS DOCUMENT IS THE PROPERTY OF LUMMUS TECHNOLOGY INC. (LUMMUS). IT CONTAINS CONFIDENTIAL INFORMATION DESCRIBING TECHNOLOGY OWNED BY LUMMUS. IT IS TO BE USED ONLY IN CONNECTION WITH WORK PERFORMED BY LUMMUS. REPRODUCTION IN WHOLE OR IN PART FOR ANY PURPOSE OTHER THAN WORK PERFORMED BY LUMMUS IS FORBIDDEN EXCEPT BY EXPRESS WRITTEN PERMISSION OF LUMMUS. IT IS TO BE SAFEGUARDED AGAINST BOTH DELIBERATE AND INADVERTENT DISCLOSURE TO ANY THIRD PARTY."

DILUTION STEAM FROM E-21010

11

RK

LUMMUS PETROCHEMICALS

M

DOC. No:

7

5

H

K

FEB 0 2017 FOR PROPOSAL

QC

DECOKING AIR TO F-20002 THRU F-20007

4

F-20007

J

QC B

ETHANE RECYCLE FROM E-20021

3

F-20006

QC

PROPANE RECYCLE FROM E-20022

2

F-20005

TO TLE'S

DWG. 2100C

1

F-20004

AIR DAMPER

DECOKE EFFLUENT

FC

L

M

F-20003

AVG

HC

SEC.

PRIM.

TC B

F-20001

C02

NOTE 5

C1 C2 C2 C3 C3 NOTE 6

FROM TI'S ON OTHER "B" COILS

TI

CELL "B"

SEC.

PRIM.

FROM OTHER TLE'S NOTE 4

FC

AVG

TO V-20015 DWG. 2000D

CONDUCTIVITY

K

AVG.

TDC B

FROM TI's ON OTHER "A" COILS

pH

TO OTHER HEATERS

TO FCB

A

A

J

PC

INTEGRAL

H

LMP

G

INTEGRAL

G

PFO

TC

14

SCALE:

NONE

DWG. No:

15

REV:

A1-222334-2000B 16

0

1

2

3

5

4

6

7

8

9

10

11

12

13

14

(NOTE 7)

B

TO FFC B

FC B

BIAS

NOTE 7

TO ATMOSPHERE

FROM ANALYZER ON FEED LINES DWG. 2000A

C

SP

BIAS

SP

PV

SP

FROM TDC A

FC A

TO OTHER COIL "A" FC's

SP

FC A

SP SP

D

FROM ANALYZER ON FEED LINES DWG. 2000A

SP

TO ATMOSPHERE TO OTHER "A" COILS NOTE 4 O2,NOx, CO

FC A

FC B

B

3. ONE SAMPLE CONDITIONING SYSTEM PER CELL. MAXIMUM FIVE CONNECTIONS PER ANALYZER.

FROM FC B SP

4. 14 COILS PER HEATER, 7 COILS PER CELL, 2 CELLS PER HEATER.

FFC B

5. CASE 1: SPLIT CRACKING C4/C5 FEED (4 COILS) AND NAPHTHA (3 COILS) IN CELL "A" AND 100% NAPHTHA CRACKING IN CELL "B" IN ONE HEATER (F-20003 OR F-20004). CASE 2: SPLIT CRACKING C4/C5 FEED (4 COILS) AND NAPHTHA (3 COILS) IN CELL "A" AND 100% NAPHTHA CRACKING IN CELL "B" IN ONE HEATER (F-20003 OR F-20004). SPLIT CRACKING NAPHTHA (3 COILS) AND KERO (4 COILS) IN CELL "A" AND 100% KERO CRACKING IN CELL "B" IN ONE HEATER (F-20006 OR F-20007).

UFP

BFW

TO FFC B

BIAS

TO OTHER "B" COILS NOTE 4

A

BIAS

SP

FROM ANALYZER ON FEED LINES DWG. 2000A

NOTE 4,5 TO OTHER "A" COILS

TO NAPHTHA FC A

PV

PV

FROM FC's ON OTHER "B" COILS PV TO OTHER SP FC SP B "B" COIL FC's

FFC A

FROM FC's ON OTHER "A" COILS

HC

NNF

NOTE 4,5 TO OTHER "A" COILS

FC A

2. F-20002 WILL HAVE THE FLEXIBILITY TO CRACK ETHANE/PROPANE RECYCLE AND C4/C5 FEED. F-20003 WILL HAVE THE FLEXIBILITY TO CRACK C4/C5 FEED RECYCLE AND NAPHTHA+C5/C6 RECYCLE. F-20004 WILL HAVE THE FLEXIBILITY TO CRACK ETHANE/PROPANE RECYCLE, C4/C5 FEED, NAPHTHA+C5/C6 RECYCLE AND KEROSENE. F-20005 WILL HAVE THE FLEXIBILITY TO CRACK NAPHTHA+C5/C6 RECYCLE AND KEROSENE. F-20006 WILL HAVE THE FLEXIBILITY TO CRACK NAPHTHA+C5/C6 RECYCLE AND KEROSENE. F-20007 WILL HAVE THE FLEXIBILITY TO CRACK NAPHTHA+C5/C6 RECYCLE AND KEROSENE.

PC

FROM TDC B

PV SP

A

1. TEMPERATURES & PRESSURES ARE SHOWN FOR CASE 1 OPERATION UNLESS OTHERWISE INDICATED.

FROM FC's ON OTHER "A" COILS TO OTHER COIL "A" FC's

16

NOTES:

FROM FC's ON OTHER "B" COILS PV TO OTHER SP FC SP NOTE 4,5 "B" COIL FC's B TO OTHER SP PV "B" COILS FROM ANALYZER ON FEED LINES DWG. 2000A

A

15

C

6. PURGE STEAM FOR QUENCH FITTINGS, PRESSURE & SAMPLE CONNECTIONS, TLV, DECOKE VALVES.

D

7. IN OPERATION DURING DECOKING ONLY.

FROM TDC B

UFP BFW LFP UMP DSSH USSH MSSH LSSH LMP

LFP

UMP

= = = = = = = = =

UPPER FEED PREHEAT BOILER FEED WATER LOWER FEED PREHEAT UPPER MIXED PREHEAT DILUTION STEAM SUPERHEAT UPPER STEAM SUPERHEAT MIDDLE STEAM SUPERHEAT LOWER STEAM SUPERHEAT LOWER MIXED PREHEAT

FI

E

E DSSH

AT SUPERHEATER OUTLET

USSH FC

FC

AT VHP STEAM HEADER

DECOKE AIR FROM ME-20001

F

F

MSSH TC NOTE 4,5 TO OTHER "B" COILS

NOTE 4 TO OTHER "B" COILS

PFO

LC TDC A

LC

TC A

A

LMP

FROM TO V-20015 OTHER DWG. 2000D TLE

CONDUCTIVITY

A

O2

O2

TI

CELL "A"

BLOWDOWN TO V-20014 DWG. 2000D

AIR DAMPER

FROM TI'S ON OTHER "B" COILS

HC

SEC.

PRIM.

HC

SEC.

PRIM.

TC B

H F-20001

NAPHTHA FROM E-20025

ETHANE RECYCLE FROM E-20021

PROPANE RECYCLE FROM E-20022

DWG. 2000A NOTE 2

DWG. 2000A

DWG. 2000A NOTE 2

F-20005

F-20006

F-20007

J

AIR DAMPER HC

C1 C2C2 C3C3

C02

A NNF

DECOKE EFFLUENT

REV

NOTE 6

CRACKED GAS TO M-20001A/B

PURGE STEAM FROM E-21010

PHOSPHATE FROM ME-20002

FUEL GAS FROM V-23005

DWG. 2000A

DWG. 2000B

DWG. 2000A

DWG. 2000A

DWG. 2100A

DWG. 2000C

DWG. 2000B

DWG. 2300D

VHP STEAM TO HEADER

7

8

9

10

PROC LPE PDM ENG

CLIENT

PM

11

12

13

L

M

DOC. No:

6

6

CAD

PROCESS FLOW DIAGRAM STEAM CRACKER UNIT SRT VII CRACKING HEATERS F-20002 THRU F-20007

NOTE 2

5

DESCRIPTION

"THIS DOCUMENT IS THE PROPERTY OF LUMMUS TECHNOLOGY INC. (LUMMUS). IT CONTAINS CONFIDENTIAL INFORMATION DESCRIBING TECHNOLOGY OWNED BY LUMMUS. IT IS TO BE USED ONLY IN CONNECTION WITH WORK PERFORMED BY LUMMUS. REPRODUCTION IN WHOLE OR IN PART FOR ANY PURPOSE OTHER THAN WORK PERFORMED BY LUMMUS IS FORBIDDEN EXCEPT BY EXPRESS WRITTEN PERMISSION OF LUMMUS. IT IS TO BE SAFEGUARDED AGAINST BOTH DELIBERATE AND INADVERTENT DISCLOSURE TO ANY THIRD PARTY."

DWG. 2100C

PHOSPHATE FREE BFW FROM P-32005A-C

RK

LUMMUS PETROCHEMICALS DILUTION STEAM FROM E-21010

C4/C5 FEED FROM E-20018

4

ISSUE DATE

QC

FROM WOBBE METER DWG. 2300D

K

FEB 0 2017 FOR PROPOSAL

DMDS INJECTION FROM A-130 DWG. ME-12001

DECOKING AIR FROM ME-20001

3

F-20004

TO TLE'S

QC B

KEROSENE FROM E-20026

2

F-20003

AVG

QC A

NOTE 2

1

F-20002

QC

TO OTHER HEATERS

NOTE 3

M

FC

TI

CELL "B"

A

L

AVG.

AVG

HC

K

TO FCB

TDC B

FROM TI's ON OTHER "A" COILS

NNF

A

TO OTHER HEATERS

PC

A

pH

J

G

INTEGRAL

H

TO OTHER HEATERS

GF

LSSH

NOTE 4 TO OTHER "A" COILS

INTEGRAL

G

TC

14

SCALE:

NONE

DWG. No:

15

REV:

A1-222334-2000C 16

0

1

2

3

4

5

A

6

7

8

9

10

11

13

12

V-20014

E-20014

V-20015

E-20015

VHP STEAM CONTINUOUS BLOWDOWN DRUM

CONTINUOUS BLOWDOWN COOLER

VHP STEAM INTERMITTENT BLOWDOWN DRUM

INTERMITTENT BLOWDOWN COOLER

15

14

16

NOTES:

A

1. TEMPERATURES & PRESSURES ARE SHOWN FOR CASE 1 OPERATION UNLESS OTHERWISE INDICATED.

B

B

C

C PC

ATM

D

D

E

E

LC LC

F

F

CWS

NNF CWS

G

G TC BFW

H

H

J

J

K 0 REV

K

FEB FOR PROPOSAL 2017

RK

ISSUE DATE

CAD

DESCRIPTION

PROC LPE PDM ENG

CLIENT

PM

L

MP STEAM TO HEADER

M

"THIS DOCUMENT IS THE PROPERTY OF LUMMUS TECHNOLOGY INC. (LUMMUS). IT CONTAINS CONFIDENTIAL INFORMATION DESCRIBING TECHNOLOGY OWNED BY LUMMUS. IT IS TO BE USED ONLY IN CONNECTION WITH WORK PERFORMED BY LUMMUS. REPRODUCTION IN WHOLE OR IN PART FOR ANY PURPOSE OTHER THAN WORK PERFORMED BY LUMMUS IS FORBIDDEN EXCEPT BY EXPRESS WRITTEN PERMISSION OF LUMMUS. IT IS TO BE SAFEGUARDED AGAINST BOTH DELIBERATE AND INADVERTENT DISCLOSURE TO ANY THIRD PARTY."

NNF

NNF

LUMMUS PETROCHEMICALS

CONTINUOUS BLOWDOWN FROM V-20001

CONTINUOUS BLOWDOWN FROM V-20002 - 7

WASH WATER TO C-22002

WASH WATER TO C-12001

WASH WATER TO C-12002

WASH WATER TO C-22001

WASH WATER TO T-12001

WASH WATER TO T-22001

INTERMITTENT BLOWDOWN FROM V-20002 - 7

INTERMITTENT BLOWDOWN FROM V-20001

WASTE WATER TO COOLING TOWER BASIN

DWG. 2000B

DWG. 2000C

DWG. 2200B

DWG. 1200A

DWG. 1200B

DWG. 2200C

DWG. 1200G

DWG. 2200J

DWG. 2000C

DWG. 2000B

OSBL

PROCESS FLOW DIAGRAM STEAM CRACKER UNIT BLOWDOWN SYSTEM

SCALE:

2

3

4

5

6

7

8

9

10

11

12

13

M

DOC. No:

6

1

L

14

DWG. No:

A1-222334-2000D 15

REV:

0

16

1

2

3

5

4

6

7

8

9

10

11

12

13

14

15

16

A

A 1. TEMPERATURES & PRESSURES ARE SHOWN FOR CASE 1 OPERATION UNLESS OTHERWISE INDICATED. 2. HP STEAM FOR VISCOSITY CONTROL STRIPPING WHEN F-20001 IS UNAVAILABLE. 3. PFO STRIPPER BYPASS. C kg/cm²g

B

111 0.33

4. TWO TRANSFER LINES. ONE COMMON QUENCH FITTING PER TRANSFER LINE LOCATED AT MINIMUM DISTANCE FROM C-21001.

FC

B

5. QUENCH FITTING LOCATED IN HORIZONTAL MINIMUM DISTANCE FROM C-21002 AND SLOPING TO C-21002. FC

6. MINIMUM FLOW CONTROL. 7. NORMALLY NO FLOW, DESIGN FLOW = 1-3% OF TOTAL QUENCH OIL FLOW. 8. INCLUDES V-2100G QUENCH OIL DRAIN DRUM VENT SEAL POT.

TC

RESET

FC

C

C

C kg/cm²g

TC

265 0.43

D

D LC

PROCESS WATER STRIPPER FEED DWG. 2100C

E

E

HC

LI 190 0.43

F FC MP STEAM NNF

F

LOW LEVEL OVERRIDE

C kg/cm²g

C kg/cm²g

LC

G

208 0.54

G

FC DILUTION STEAM DRUM FEED DWG. 2100C

FC

TC

NNF

MISC. QO. DRAINS

H FC

NOTE 4

A

H NNF

PM

MP STM

RETURN TO PURGE OIL FOR C-21001 INSTRUMENT FLUSH AND PUMP SEAL

FC

NOTE 3 NNF

LP STM VISC NOTE 10

J DILUTION STEAM

J

SP FC

PROCESS WATER DWG. 2100C

NOTE 5 SP FC

FC

TC

FC

K

NNF

ME-21000

NNF

REV

C kg/cm²g

DRYCOKE

CHARGE GAS TO C-21003

CRACKED GAS FROM E-20002A-N THRU E-20007A-N

DWG. 2100B

DWG. 2000C FLUX OIL FROM P-21009A/B

TANK/TRUCK LOADING

DWG. 2200E

DWG. 2100B

DWG. 2000B

DWG. 2100D

OSBL

4

CAD

PROC LPE PDM ENG

CLIENT

PM

5

6

CRACKED GAS FROM E-20001A-H

BTX TOWER BOTTOM FROM

DWG. 2000B

DWG. 2800D

PFO TO STORAGE

8

9

10

11

12

OSBL

SCALE:

7

13

M

DOC. No:

P-28006A/B

7

L

PROCESS FLOW DIAGRAM STEAM CRACKER UNIT GASOLINE FRACTIONATOR AND PYROLYSIS FUEL OIL STRIPPER

BL

QUENCH OIL TO

CRACKED GAS FROM E-20001A-H

3

DESCRIPTION

LUMMUS PETROCHEMICALS

BL

GASOLINE FROM P-21006A/B

2

RK

"THIS DOCUMENT IS THE PROPERTY OF LUMMUS TECHNOLOGY INC. (LUMMUS). IT CONTAINS CONFIDENTIAL INFORMATION DESCRIBING TECHNOLOGY OWNED BY LUMMUS. IT IS TO BE USED ONLY IN CONNECTION WITH WORK PERFORMED BY LUMMUS. REPRODUCTION IN WHOLE OR IN PART FOR ANY PURPOSE OTHER THAN WORK PERFORMED BY LUMMUS IS FORBIDDEN EXCEPT BY EXPRESS WRITTEN PERMISSION OF LUMMUS. IT IS TO BE SAFEGUARDED AGAINST BOTH DELIBERATE AND INADVERTENT DISCLOSURE TO ANY THIRD PARTY."

SPENT GASOLINE FROM V-22009

1

ISSUE DATE

90 4.1

NNF

L

K

FEB 0 2017 FOR PROPOSAL

QW DWG. 2100B

TO OTHER USERS

M

NOTE 2 HP STEAM

14

DWG. No:

NONE

15

REV:

A1-222334-2100A

0 16

1

2

3

5

4

6

7

8

9

10

11

12

13

14

15

16

A

A 1. TEMPERATURES & PRESSURES ARE SHOWN FOR CASE 1 OPERATION UNLESS OTHERWISE INDICATED.

WET FLARE

B

B PC

CW

FC

C

38

C

C CW TO E-21005A-D TC

FC

C

54

D

D FUEL GAS FROM DWG. 2100B PC CW FROM E-21006A-D

E

E

INTERFACE LI

F

F

PDC A

E-21004A-D DWG. 2100A

KNOCK OUT LIQUID FROM V-28012

LIQUID FROM V-12021

HEEL DRAIN FROM V-12012A/B

DWG. 2300D

DWG. 2200A

DWG. 2800C

DWG. 1200A

DWG. 1200D

SPENT GASOLINE FROM V-22009

HEAVY LIQUID FROM V-20012

LIQUID FROM WET FLARE DRUM

LIQUID FROM V-22018

PROCESS WATER STRIPPER OVERHEAD FROM C-21004

DWG. 2200E

DWG. 2000A

DWG. 2900A

DWG. 2200B

DWG. 2100C

H

REGENERATION

NNF

NNF

PDC

E-20026 DWG. 2000A

K

FC E-20021 DWG. 2000A

REV

ISSUE DATE

DESCRIPTION

CAD

PROC LPE PDM ENG

CLIENT

PM

WASH GASLINE TO E-22008

OILY WATER FROM V-22004/V-22005

WATER FROM P-22001A/B

DWG. 2200E

DWG. 2200D

DWG. 2200A

"THIS DOCUMENT IS THE PROPERTY OF LUMMUS TECHNOLOGY INC. (LUMMUS). IT CONTAINS CONFIDENTIAL INFORMATION DESCRIBING TECHNOLOGY OWNED BY LUMMUS. IT IS TO BE USED ONLY IN CONNECTION WITH WORK PERFORMED BY LUMMUS. REPRODUCTION IN WHOLE OR IN PART FOR ANY PURPOSE OTHER THAN WORK PERFORMED BY LUMMUS IS FORBIDDEN EXCEPT BY EXPRESS WRITTEN PERMISSION OF LUMMUS. IT IS TO BE SAFEGUARDED AGAINST BOTH DELIBERATE AND INADVERTENT DISCLOSURE TO ANY THIRD PARTY."

CONDENSATE FROM S-23001A/B

CHARGE GAS FROM C-21001

GASOLINE TO E24015

GASOLINE TO C-21001

PROCESS WATER STRIPPER FEED TO E-21008

GASOLINE FROM V-22004

CONDENSATE FROM V-22011

LIQUID FROM P-3101A/B

DWG. 2200A

DWG. 2100A

DWG. 2400D

DWG. 2100A

DWG. 2100C

DWG. 2200D

DWG. 2200F

DWG. 3100A

5

6

7

8

9

10

11

M

DOC. No:

6

4

L

PROCESS FLOW DIAGRAM STEAM CRACKER UNIT QUENCH TOWER

DWG. 2300D

CHARGE GAS TO V-22001

3

RK

LUMMUS PETROCHEMICALS

L

2

K

FEB 0 2017 FOR PROPOSAL

PDC

1

PURGE GAS FROM R-12001A/B R-24001A/B, R-27001A/B, R-28001A/B & 28002A/B DWG. 2001G

J

E-20025 DWG. 2000A

M

G

E-20022 DWG. 2000A

NNF

J

GASOLINE FROM V-22002

pH

E-24002 DWG. 2400A

E-20020 DWG. 2000A

LIQUID FROM V-23005

RESET

H

REGENERATION NNF

NNF

E-22003 DWG. 2200B

NNF

AMINE INJECTION ME-21002

E-24012A/B DWG. 2400C

G

LC

NNF

E-24011A/B DWG. 2400C

TC

NNF

RESET

12

13

14

SCALE:

NONE

DWG. No:

15

REV:

A1-222334-2100B 16

0

1

2

3

5

4

6

7

8

9

10

11

12

13

14

15

16

A

A 1.

TEMPERATURES & PRESSURES ARE SHOWN FOR CASE 1 OPERATION UNLESS OTHERWISE INDICATED.

B

B

FC C kg/cm²g

C

109 0.38

C kg/cm²g

176 8.3

C

D

D

E

E FC

PO DWG. 2100A LP STEAM

NNF

QO DWG. 2100A

SP FC

LC

F

LP COND.

C kg/cm²g

LC

F

LP STEAM

111 0.47

MP STEAM

MP COND.

QO DWG. 2100A

G

G NNF FC

FC

FC

SP

SP

AMINE INJECTION ME-21002

PC

H

PC

NNF A

LOW PRESSURE BACK UP

H

pH NNF CW

J

J A PH

FC PC

PC

K

K

FEB 0 2017 FOR PROPOSAL REV

ISSUE DATE

RK

DESCRIPTION

CAD

PROC LPE PDM ENG

CLIENT

PM

LUMMUS PETROCHEMICALS C kg/cm²g

L

"THIS DOCUMENT IS THE PROPERTY OF LUMMUS TECHNOLOGY INC. (LUMMUS). IT CONTAINS CONFIDENTIAL INFORMATION DESCRIBING TECHNOLOGY OWNED BY LUMMUS. IT IS TO BE USED ONLY IN CONNECTION WITH WORK PERFORMED BY LUMMUS. REPRODUCTION IN WHOLE OR IN PART FOR ANY PURPOSE OTHER THAN WORK PERFORMED BY LUMMUS IS FORBIDDEN EXCEPT BY EXPRESS WRITTEN PERMISSION OF LUMMUS. IT IS TO BE SAFEGUARDED AGAINST BOTH DELIBERATE AND INADVERTENT DISCLOSURE TO ANY THIRD PARTY."

45 3.1

PROCESS FLOW DIAGRAM STEAM CRACKER UNIT PROCESS WATER STRIPPING AND DILUTION STEAM GENERATION

BL

M

PROCESS WATER STRIPPER OVHD TO C-21003

PROCESS WATER STRIPPER FEED FROM P-21005A/B

DWG. 2100B

DWG. 2100B

BFW INJECTION TO K-22001 STAGES 1 & 2 DWG. 2200A

MAKEUP WATER FROM P-32005A/B/C (PHOSPHATE FREE) DWG. 3200A

BFW INJECTION TO K-22001 STAGE 3 DWG. 2200D

BLOWDOWN TO WWTP

WASH WATER TO M-22003 DWG. 2200E

PURGE STEAM TO F-20001

PURGE STEAM TO F-20002 THRU F-20007

DILUTION STEAM TO F-20001

DILUTION STEAM TO F-20002 THRU F-20007

DWG. 2000B

DWG. 2000C

DWG. 2000B

DWG. 2000C

2

3

4

5

6

7

8

9

10

11

12

13

M

DOC. No:

6

1

L

14

SCALE:

NONE

DWG. No:

15

REV:

A1-222334-2100C 16

0

1

2

3

5

4

6

A

7

8

T-21001

T-21002

FLUX OIL STORAGE TANK

WASH OIL STORAGE TANK

9

10

11

12

13

14

15

16

NOTES:

A

1. TEMPERATURES & PRESSURES ARE SHOWN FOR CASE 1 OPERATION UNLESS OTHERWISE INDICATED.

B

B

C

C LI

N2

D

D

E

E TRUCK UNLOADING

LI

N2

F

F

G

G TRUCK UNLOADING

P-21010

P-21010A/B

WASH OIL PUMP

FLUX OIL PUMPS

H

H

J

J

K 0 REV

K

FEB FOR PROPOSAL 2017

RK

ISSUE DATE

CAD

DESCRIPTION

PROC LPE PDM ENG

CLIENT

PM

LUMMUS PETROCHEMICALS "THIS DOCUMENT IS THE PROPERTY OF LUMMUS TECHNOLOGY INC. (LUMMUS). IT CONTAINS CONFIDENTIAL INFORMATION DESCRIBING TECHNOLOGY OWNED BY LUMMUS. IT IS TO BE USED ONLY IN CONNECTION WITH WORK PERFORMED BY LUMMUS. REPRODUCTION IN WHOLE OR IN PART FOR ANY PURPOSE OTHER THAN WORK PERFORMED BY LUMMUS IS FORBIDDEN EXCEPT BY EXPRESS WRITTEN PERMISSION OF LUMMUS. IT IS TO BE SAFEGUARDED AGAINST BOTH DELIBERATE AND INADVERTENT DISCLOSURE TO ANY THIRD PARTY."

L BL

M

PROCESS FLOW DIAGRAM STEAM CRACKER UNIT FLUX OIL/ WASH OIL STORAGE

BL

FLUX OIL FROM

WASH OIL FROM

WASH OIL FROM E-28020

WASH OIL TO K-22001 1ST, 2ND & 3RD STAGE

FLUX OIL TO C-21001

OSBL

OSBL

DWG. 2800D

DWG. 2200A/D

DWG. 2100A

M

DOC. No: SCALE:

DWG. No:

6

1

2

3

4

5

6

7

8

9

10

11

12

13

L

14

15

REV:

A1-222334-2100D

0

16

1

A

3

2

5

4

6

7

8

9

10

11

13

12

V-22001

K-22001

E-22001A/B

V-22002

E-22002A/B

V-22003

CHARGE GAS COMPRESSOR 1ST STAGE SUCTION DRUM

CHARGE GAS COMPRESSOR 1ST AND 2ND STAGE

CHARGE GAS COMPRESSOR 1ST STAGE AFTERCOOLER

CHARGE GAS COMPRESSOR 2ND STAGE SUCTION DRUM

CHARGE GAS COMPRESSOR 2ND STAGE AFTERCOOLER

CHARGE GAS COMPRESSOR 2ND STAGE DISCHARGE DRUM

15

14

16

NOTES:

A

1. TEMPERATURES & PRESSURES ARE SHOWN FOR CASE 1 OPERATION UNLESS OTHERWISE INDICATED.

MIN. FLOW BYPASS

B

B

WET FLARE

C

C

PC PC

SC

D

D

LC

E

E

INTERFACE LC

LC

LC

F

F

G

G

H

CWS

H

CWS

WASH OIL INJECTION DWG. 2100D

WASH OIL INJECTION DWG. 2100D

FC

FC 1ST STAGE

2ND STAGE

J

J VHP

P-22001A/B CGC 1ST STAGE SUCTION DRUM PUMPS

K

WASH OIL INJECTION DWG. 2100D

WASH OIL INJECTION DWG. 2100D

HP BFW INJECTION DWG. 2100C

HP BFW INJECTION DWG. 2100C 0

START-UP NATURAL GAS FROM ME-23000-E06

WATER TO C-21003

VENT FROM V-22018

VENT FROM V-28006/V-28013

VENT FROM V-22015

RECYCLE FROM V-22014A/B

VENT FROM V-25005

VENT FROM THU

PP RECYCLE FROM OSBL

GASOLINE TO C-21003

PROPYLENE VENT FROM E-24010

CHARGE GAS TO C-22004

DWG. 2100B

DWG. 2300A

DWG. 2100B

DWG. 2200B

DWG. 2800B

DWG. 2200H

DWG. 2200G

DWG. 2500B

DWG. 2700A

DWG. 1200C

DWG. 2100B

DWG. 2400C

DWG. 2200B

DESCRIPTION

PROC LPE PDM ENG

CLIENT

PM

3

4

5

6

7

8

9

10

11

12

13

L

PROCESS FLOW DIAGRAM STEAM CRACKER UNIT CHARGE GAS

COMPRESSION STAGES 1 & 2 M

DOC. No:

5

2

CAD

NNF

NNF

NNF

CHARGE GAS FROM C-21003

1

ISSUE DATE

"THIS DOCUMENT IS THE PROPERTY OF LUMMUS TECHNOLOGY INC. (LUMMUS). IT CONTAINS CONFIDENTIAL INFORMATION DESCRIBING TECHNOLOGY OWNED BY LUMMUS. IT IS TO BE USED ONLY IN CONNECTION WITH WORK PERFORMED BY LUMMUS. REPRODUCTION IN WHOLE OR IN PART FOR ANY PURPOSE OTHER THAN WORK PERFORMED BY LUMMUS IS FORBIDDEN EXCEPT BY EXPRESS WRITTEN PERMISSION OF LUMMUS. IT IS TO BE SAFEGUARDED AGAINST BOTH DELIBERATE AND INADVERTENT DISCLOSURE TO ANY THIRD PARTY."

L

M

RK

LUMMUS PETROCHEMICALS

NNF

NNF

REV

K

FEB FOR PROPOSAL 2017

14

SCALE:

DWG. No:

A1-222334-2200A 15

REV:

0

16

1

3

2

A

5

4

6

7

8

9

10

11

13

12

E-22003

C-22004

E-22018

E-22019

E-22022A/B

C-22005

E-22020

E-22021

V-22017

V-22018

AMINE CHARGE GAS FEED HEATER

SCU MEA//WATER WASH COLUMN

LEAN MEA COOLER

LEAN MEA/RICH MEA EXCHANGER

MEA REGENERATOR REBOILER

MEA REGENERATOR

MEA REGENERATOR CONDENSER

MEA RECLAIMER

MEA REGENERATOR REFLUX DRUM

MEA REGENERATOR HP FLASH DRUM

15

14

16

NOTES:

A

1. TEMPERATURES & PRESSURES ARE SHOWN FOR CASE 1 OPERATION UNLESS OTHERWISE INDICATED. 2. FLOW MEASUREMENTS PRESSURE AND TEMPERATURE COMPENSATED.

TO WET FLARE

B

B PC PC PC

C kg/cm²g

C

45 7.0

C

FC TO ACID GAS FLARE

CW

N2

TC LC

D

D C kg/cm2g TC

E

E LC

FC

SP FC

F

F C kg/cm²g

LC

54 7.2

SP

G

FC

TO AMINE DRAIN SYSTEM LP STEAM

DESUPERHEATED MP STEAM

LC

LP COND.

H

G

FC

H NNF

TC

MP COND.

CW

QW DWG. 2100B

NNF

J NNF

J

MP STEAM

TDC CONDENSATE

K

LC

LC

REV

ISSUE DATE

FC

CAD

PROC LPE PDM ENG

CLIENT

PM

WASH WATER TO NEUTRALIZATION

CHARGE GAS FROM V-22003

HYDROCARBON TO C-21003

VENT TO K-22001 2ND STAGE

MAKEUP AMINE FROM T-22001

20% CAUSTIC SOLUTION FROM P-22008A/B

DWG. 2200C

DWG. 2200C

DWG. 2200A

DWG. 2100B

DWG. 2200A

DWG. 2200J

DWG. 2200C

MEA SLUDGE TO DRUMS

3

4

5

6

7

8

9

10

M

DOC. No:

6

2

11

L

PROCESS FLOW DIAGRAM STEAM CRACKER UNIT ACID GAS REMOVAL AMINE TREATMENT SYSTEM

BL

CHARGE GAS TO C-22001

1

DESCRIPTION

"THIS DOCUMENT IS THE PROPERTY OF LUMMUS TECHNOLOGY INC. (LUMMUS). IT CONTAINS CONFIDENTIAL INFORMATION DESCRIBING TECHNOLOGY OWNED BY LUMMUS. IT IS TO BE USED ONLY IN CONNECTION WITH WORK PERFORMED BY LUMMUS. REPRODUCTION IN WHOLE OR IN PART FOR ANY PURPOSE OTHER THAN WORK PERFORMED BY LUMMUS IS FORBIDDEN EXCEPT BY EXPRESS WRITTEN PERMISSION OF LUMMUS. IT IS TO BE SAFEGUARDED AGAINST BOTH DELIBERATE AND INADVERTENT DISCLOSURE TO ANY THIRD PARTY."

DWG. 2000D

M

RK

LUMMUS PETROCHEMICALS

WASH WATER FROM E-20014

L

K

FEB 0 2017 FOR PROPOSAL

12

13

14

SCALE:

NONE

DWG. No:

15

REV:

A1-222334-2200B 16

0

1

A

3

2

5

4

6

7

E-22003

V-22032

C-22001

CAUSTIC CHARGE GAS FEED HEATER

20% CAUSTIC SURGE DRUM

CAUSTIC/WATER WASH TOWER

8

9

10

11

12

13

15

14

16

NOTES:

A

1. TEMPERATURES & PRESSURES ARE SHOWN FOR CASE 1 OPERATION UNLESS OTHERWISE INDICATED. 2. P-22003A IS A COMMON SPARE FOR P-22003B AND P-22002.

B

B

A CO2 H2S FC

C

C LC

D

D

E

E

A

F

CO2 H2S

F

LC FI WASH WATER DWG. 2000D

FI

LC

G

NNF

LC NNF

H

NNF

NNF

FC PV

FFC

OVERRIDE

NNF

NNF LOW LEVEL

G

FI

H

NNF NNF

J

J

P-22008A/B

P-22002

P-22003A/B

P-22004A/B

20% CAUSTIC FEED PUMPS

WEAK CAUSTIC CIRCULATION PUMP

MEDIUM CAUSTIC CIRCULATION PUMPS

STRONG CAUSTIC CIRCULATION PUMPS

K 0 REV

NNF

K

FEB FOR PROPOSAL 2017

RK

ISSUE DATE

CAD

DESCRIPTION

PROC LPE PDM ENG

CLIENT

PM

NNF

LUMMUS PETROCHEMICALS

NNF

"THIS DOCUMENT IS THE PROPERTY OF LUMMUS TECHNOLOGY INC. (LUMMUS). IT CONTAINS CONFIDENTIAL INFORMATION DESCRIBING TECHNOLOGY OWNED BY LUMMUS. IT IS TO BE USED ONLY IN CONNECTION WITH WORK PERFORMED BY LUMMUS. REPRODUCTION IN WHOLE OR IN PART FOR ANY PURPOSE OTHER THAN WORK PERFORMED BY LUMMUS IS FORBIDDEN EXCEPT BY EXPRESS WRITTEN PERMISSION OF LUMMUS. IT IS TO BE SAFEGUARDED AGAINST BOTH DELIBERATE AND INADVERTENT DISCLOSURE TO ANY THIRD PARTY."

L

PROCESS FLOW DIAGRAM STEAM CRACKER UNIT ACID GAS REMOVAL

BL

M

CHARGE GAS FROM C-22004

20% CAUSTIC SOLUTION FROM

20% CAUSTIC SOLUTION TO E-22021

20% CAUSTIC SOLUTION TO P-12002A/B

20% CAUSTIC SOLUTION TO E-12022

SPENT CAUSTIC TO V-22008

WASH WATER TO SPENT CAUSTIC NEUTRALIZATION

SPENT WASH WATER FROM C-12001

SPENT WASH WATER FROM C-12002

SPENT WASH WATER FROM C-22004

WASH WATER FROM V-20007

CHARGE GAS TO E-22005

DWG. 2200B

OSBL

DWG. 2200B

DWG. 1200B

DWG. 1200A

DWG. 2200E

DWG. 3000B

DWG. 1200A

DWG. 1200B

DWG. 2200B

DWG. 2000D

DWG. 2200D

CAUSTIC WATER WASH SYSTEM

2

3

4

5

6

7

8

9

10

11

12

M

DOC. No:

5

1

L

13

14

SCALE:

DWG. No:

15

REV:

A1-222334-2200C

0

16

1

A

3

2

5

4

6

7

8

9

E-22005

V-22004

K-22001

E-22006A/B

E-22007

V-22005

ME-22002

CAUSTIC TOWER EFFLUENT COOLER

CHARGE GAS COMPRESSOR 3RD STAGE SUCTION DRUM

CHARGE GAS COMPRESSOR 3RD STAGE

CHARGE GAS COMPRESSOR 3RD STAGE AFTERCOOLER No. 1

CHARGE GAS COMPRESSOR 3RD STAGE AFTERCOOLER No. 2

CHARGE GAS COMPRESSOR 3RD STAGE DISCHARGE DRUM

LIQUID CONDENSATE COALESCER PACKAGE

10

11

V-22017

13

12

15

14

16

V-22007A/B

CHARGE GAS COMPRESSOR LIQUID CONDENSATE CASING DRAIN DRUM DRYERS

A 1.

TEMPERATURES & PRESSURES ARE SHOWN FOR CASE 1 OPERATION UNLESS OTHERWISE INDICATED.

MIN. FLOW BYPASS

B

B

WET FLARE TO LCV ON E-22005 C3R INLET DWG. 2500B

TC

PC

TO LCV ON E-22007 C3R INLET DWG. 2500B

A CO

TC

C

C

REGENERATION

D

D LC

9°C C3R DWG. 2500B

LC

A

A H2O

LC

H2O

LC

E

INTERFACE

INTERFACE

LC

LC

E

INTERFACE

9°C C3R DWG. 25001B

F

F

A

CWS

H2O FC

G

G

TO WET FLARE

OVERRIDE

LOW LEVEL

WASH OIL INJECTION DWG. 2100D

PC

H

H

SP FC

3RD STAGE

FC

FC

J

J WASH OIL INJECTION DWG. 2100D

P-22006A/B CGC 3RD STAGE SUCTION DRUM PUMPS

P-22007A/B CGC 3RD STAGE DISCHARGE DRUM PUMPS

HP BFW INJECTION DWG. 2100C

K 0 REV

NNF

RK

ISSUE DATE

CAD

K-22001 CASING DRAINS

OFF GAS FROM V-27002

NNF

DWG. 2200D

M

DESCRIPTION

REGEN GAS FROM E-22011

CHARGE GAS TO V-22010A/B/C

DWG. 2200F

DWG. 2200F

CHARGE GAS FROM C-22001

HP OFF GAS FROM V-28011

OILY WATER TO C-21003

GASOLINE TO C-21003

CRACKED CONDENSATE TO C-22002

REGEN GAS TO E-22009

DWG. 2200C

DWG. 2800C

DWG. 2100B

DWG. 2100B

DWG. 2200G

DWG. 2200F

3

4

5

6

7

8

9

10

11

12

13

L

PROCESS FLOW DIAGRAM STEAM CRACKER UNIT CHARGE GAS

COMPRESSION STAGE 3

M

DOC. No: SCALE:

2

CLIENT

PM

"THIS DOCUMENT IS THE PROPERTY OF LUMMUS TECHNOLOGY INC. (LUMMUS). IT CONTAINS CONFIDENTIAL INFORMATION DESCRIBING TECHNOLOGY OWNED BY LUMMUS. IT IS TO BE USED ONLY IN CONNECTION WITH WORK PERFORMED BY LUMMUS. REPRODUCTION IN WHOLE OR IN PART FOR ANY PURPOSE OTHER THAN WORK PERFORMED BY LUMMUS IS FORBIDDEN EXCEPT BY EXPRESS WRITTEN PERMISSION OF LUMMUS. IT IS TO BE SAFEGUARDED AGAINST BOTH DELIBERATE AND INADVERTENT DISCLOSURE TO ANY THIRD PARTY."

DWG. No:

6

1

PROC LPE PDM ENG

LUMMUS PETROCHEMICALS

NNF

L

K

FEB FOR PROPOSAL 2017

14

15

REV:

A1-222334-2200D

0

16

1

2

3

5

4

A

6

7

8

9

10

11

12

E-22008

V-22008

V-22009

SPENT CAUSTIC WASH GASOLINE COOLER

SPENT CAUSTIC COALESCER

SPENT GASOLINE COALESCER

TO WET FLARE

B

C

13

14

15

16

A 1. TEMPERATURES & PRESSURES ARE SHOWN FOR CASE 1 OPERATION UNLESS OTHERWISE INDICATED.

TO WET FLARE

PC

PC

PC

PC

NITROGEN

B

C

NITROGEN

D

D C kg/cm²g

LC

45 4.3

C kg/cm²g

LC

LC

67 3.2

LC

E

E

F

F

FC

G

G

H

H

J

PV

J

FFC PV

FI

FFC

K 0

CWS

C kg/cm²g

REV

55 2.5

K

FEB FOR PROPOSAL 2017

RK

ISSUE DATE

CAD

DESCRIPTION

PROC LPE PDM ENG

CLIENT

PM

NNF

LUMMUS PETROCHEMICALS "THIS DOCUMENT IS THE PROPERTY OF LUMMUS TECHNOLOGY INC. (LUMMUS). IT CONTAINS CONFIDENTIAL INFORMATION DESCRIBING TECHNOLOGY OWNED BY LUMMUS. IT IS TO BE USED ONLY IN CONNECTION WITH WORK PERFORMED BY LUMMUS. REPRODUCTION IN WHOLE OR IN PART FOR ANY PURPOSE OTHER THAN WORK PERFORMED BY LUMMUS IS FORBIDDEN EXCEPT BY EXPRESS WRITTEN PERMISSION OF LUMMUS. IT IS TO BE SAFEGUARDED AGAINST BOTH DELIBERATE AND INADVERTENT DISCLOSURE TO ANY THIRD PARTY."

L

M

SPENT CAUSTIC FROM C-22001

SPENT CAUSTIC FROM ROG C-12002

WASH GASOLINE FROM P-21006A/B

WASH WATER FROM P-21007A/B

SPENT GASOLINE TO C-21001

SPENT GASOLINE TO C-21003

SPENT CAUSTIC TO WAO UNIT

DWG. 2200C

DWG. 1200B

DWG. 2100B

DWG. 2100C

DWG. 2100A

DWG. 2100B

DWG. 3000A

PROCESS FLOW DIAGRAM STEAM CRACKER UNIT SPENT CAUSTIC PRETREATMENT

2

3

4

5

6

7

8

9

10

11

12

M

DOC. No:

5

1

L

13

14

SCALE:

DWG. No:

15

REV:

A1-222334-2200E

0

16

1

2

3

A

5

4

6

7

8

9

10

11

12

13

14

15

16

NOTES:

V-22010A/B/C

E-22011

V-22011

E-22009

E-22010

E-22031

E-24018

CHARGE GAS DRYERS

REGEN GAS HEATER

REGENERATION GAS K.O. DRUM

REGENERATION FEED EFFLUENT EXCHANGER

REGENERATION GAS COOLER

REACTOR REDUCTION GAS HEATER

TREATER REGENERATION GAS ELETRIC HEATER

TEMPERATURES & PRESSURES ARE SHOWN FOR CASE 1 OPERATION UNLESS OTHERWISE INDICATED.

1.

A

REGEN.

C kg/cm²g

C kg/cm²g

12 24.4

232 5.9

B

LIQ. COND. DRYER REGENERATION GAS TO/FROM V-22007A/B

ACET. CONV. DRYER REGENERATION GAS TO/FROM V-22014A/B

ROG DRYER / TREATER REGENERATION GAS TO/FROM V-12012A/B

LPG TREATER REGENERATION GAS TO/FROM V-12006A/B

PG PROPYLENE TREATER

REGENERATION GAS TO FROM V-24006A/B

PGH REACTOR REGENERATION GAS TO/FROM R-28001A/B, R-28002A/B

C4/C5 HYDRO REACTOR REGENERATION GAS TO/FROM R-27001A/B

MAPD CONVERTER REGENERATION GAS TO/FROM R-24001A/B

DWG. 2200D

DWG. 2200G

DWG. 1200D

DWG. 1200D

DWG. 2400E

DWG. 2800A & C

DWG. 2700A

DWG. 2400C

TC

TC FC

TC FC

TC FC

TC

TC

FC

FC

TC FC

B

REACTOR REGENERATION GAS TO R-12001A/B

TC

DWG. 1200C

FC

FC

A H2O

C SP

FC

SP

FC

SP

FC

SP

FC

SP

FC

SP

FC

SP

FC

SP

TC

SP

FC

C

REACTOR PRE-REDUCTION GAS TO R-22001A/B/C

FC

DWG. 2200G

FC

D

D COOLING HEATING A

TC

RETURN

H2O

E

E

HP COND TC

HEATING GAS

HS

F

F C kg/cm²g

45 5.4

CWS

A H2 C1 C2C2 C3C3 CO2 H2S

G

G TC

A H2O

LC

MPS

H

H MP COND

TC

(REGENERATION ONLY)

J

(REGENERATION ONLY)

FC

PDC

J

PLANT AIR

SP FC

FC

PC

VHS

K 0 REV

LPS

RK

ISSUE DATE

CAD

NNF

FC

M

CHARGE GAS FROM V-22005

REGEN OFFGAS TO FUEL GAS SYSTEM

CONDENSATE TO C-21003

DWG. 2200D

DWG. 2300D

DWG. 2300A

DWG. 2300D

DWG. 2100B

HYDROGEN DWG. 2300D

2

3

4

5

6

7

8

9

10

11

12

13

14

L

M

DOC. No:

6

1

CLIENT

PM

PROCESS FLOW DIAGRAM STEAM CRACKER UNIT CHARGE GAS DRYING & REGENRATION

FC DWG. 2200G METHANE OFFGAS FROM ME-23000-E06

PROC LPE PDM ENG

"THIS DOCUMENT IS THE PROPERTY OF LUMMUS TECHNOLOGY INC. (LUMMUS). IT CONTAINS CONFIDENTIAL INFORMATION DESCRIBING TECHNOLOGY OWNED BY LUMMUS. IT IS TO BE USED ONLY IN CONNECTION WITH WORK PERFORMED BY LUMMUS. REPRODUCTION IN WHOLE OR IN PART FOR ANY PURPOSE OTHER THAN WORK PERFORMED BY LUMMUS IS FORBIDDEN EXCEPT BY EXPRESS WRITTEN PERMISSION OF LUMMUS. IT IS TO BE SAFEGUARDED AGAINST BOTH DELIBERATE AND INADVERTENT DISCLOSURE TO ANY THIRD PARTY."

CHARGE GAS TO C-22002

EXCESS HYDROGEN FROM ME-23001 BYPASS

DESCRIPTION

LUMMUS PETROCHEMICALS NITROGEN

L

K

FEB FOR PROPOSAL 2017

SCALE:

DWG. No:

15

REV:

A1-222334-2200F

0

16

1

3

2

A

5

4

6

E-22020A/B

E-22021

C-22002

HP DEPROPANIZER REBOILER

HP DEPROPANIZER BOTTOMS COOLER

HP DEPROPANIZER

7

E-22012

8

E-22015

9

E-22016

10

E-22017

11

E-22014

V-22014

ACETYLENE CONVERTER FEED/ EFFLUENT EXCHANGER NO. 2

ACETYLENE CONVERTER DRYER

15

14

R-22001A/B/C

E-22018

V-22012

ACETYLENE CONVERTER

HP DEPROPANIZER CONDENSER

HP DEPROPANIZER REFLUX DRUM

ACETYLENE CONVERTER FEED/ ACETYLENE CONVERTER ACETYLENE CONVERTER ACETYLENE CONVERTER ACETYLENE CONVERTER EFFLUENT EXCHANGER NO. 1 INTERCOOLER No. 1 INTERCOOLER No. 2 AFTERCOOLER HEATER

E-22013

13

12

16

A 1. TEMPERATURES & PRESSURES ARE SHOWN FOR CASE 1 OPERATION UNLESS OTHERWISE INDICATED.

TO COLD FLARE

B

A

TC

A

MPS

C4'S

CO

B

-27°C C3R DWG. 25001A

PC

PC

C

C MP COND

FC

D

D

NNF TC

NNF

CO INJECTION FROM BOTTLES

NNF

START-UP A

NNF

NITROGEN & HYDROGEN DWG. 2200F

E

A

C2H2 C2H6 MAPD

C

SOR 66

EOR 116

C

SOR 78

EOR 131 NNF

A

C2H2 C2H6 MAPD CO

START-UP

NNF

START-UP

LC

C2H2 C2H6 MAPD

TC

TC

TO COLD FLARE PC

G TC

F

C

SOR 69

EOR 117

C

SOR 75

EOR 128

C

SOR 69

EOR 118

G

CWS TC

NNF

RESET

METHANOL INJECTION ME-12002

NNF

CWS

F

E

TO LCV ON E-22018 INLET DWG. 2500A

TC

LC

FC

H

H DS LPS RESET

NOTE 4

C

LP COND

SOR 74

EOR 125

CWS

J

J

K

A

NNF

START-UP

A

H2O

H2O

CWS

0

NNF FC

REV

RK

ISSUE DATE

CAD

FC

NNF

NNF

L

OFF SPEC ETHYLENE FROM OSBL

M

DWG. 2400B

REGENERATION ONLY

POLYMERIZATION C2's INHIBITOR INJECTION A ME-22000

CRACKED CONDENSATE FROM V-22007A/B DWG. 2200D

CHARGE GAS FROM V-22010A/B/C DWG. 2200F

HP DEPROPANIZER BOTTOMS TO C-22003

LP DEPROPANIZER OVERHEAD FROM P-22011A/B

RECYCLE TO V-22002

DWG. 2200H

DWG. 2200H

DWG. 2200A

REGEN GAS FROM E-22011

HP DEPROPANIZER REFLUX PUMPS

2

3

4

5

6

7

8

DWG. 2400E START-UP PROPYLENE VAPOR FROM C-24003

CHARGE GAS TO E-23001

DWG. 2400C

DWG. 2300C

DWG. 2200F

9

10

CLIENT

PM

11

12

M

DOC. No:

13

L

PROCESS FLOW DIAGRAM STEAM CRACKER UNIT FRONT-END HIGH PRESSURE DEPROPANIZER

11

1

PROC LPE PDM ENG

"THIS DOCUMENT IS THE PROPERTY OF LUMMUS TECHNOLOGY INC. (LUMMUS). IT CONTAINS CONFIDENTIAL INFORMATION DESCRIBING TECHNOLOGY OWNED BY LUMMUS. IT IS TO BE USED ONLY IN CONNECTION WITH WORK PERFORMED BY LUMMUS. REPRODUCTION IN WHOLE OR IN PART FOR ANY PURPOSE OTHER THAN WORK PERFORMED BY LUMMUS IS FORBIDDEN EXCEPT BY EXPRESS WRITTEN PERMISSION OF LUMMUS. IT IS TO BE SAFEGUARDED AGAINST BOTH DELIBERATE AND INADVERTENT DISCLOSURE TO ANY THIRD PARTY."

START-UP PROPYLENE FILL FROM OSBL

P-22010A/B

REGEN GAS TO E-22009

DWG. 2200F

DESCRIPTION

LUMMUS PETROCHEMICALS

REGENERATION ONLY

FC

K

FEB FOR PROPOSAL 2017

14

SCALE:

DWG. No:

A1-222334-2200G 15

REV:

0

16

1

2

3

5

4

A

6

7

8

9

10

E-22023A/B

C-22003

E-22022

V-22015

LP DEPROPANIZER REBOILER

LP DEPROPANIZER

LP DEPROPANIZER CONDENSER

LP DEPROPANIZER REFLUX DRUM

B

11

12

13

14

15

16

NOTES:

A

1. TEMPERATURES & PRESSURES ARE SHOWN FOR CASE 1 OPERATION UNLESS OTHERWISE INDICATED. 2. ONE OPERATING, ONE STAND BY.

B

TO LCV ON E-22022 INLET DWG. 2500A

PC

PC

C

C

-27° C3R DWG. 2500A

TO COLD FLARE

D

D

HC

E

E

LC POLYMERIZATION INHIBITOR INJECTION ME-22000 RESET

F

TC

F

FC LC DS LPS

G

LP COND

G

METHANOL INJECTION ME-12002

NOTE 2

POLYMERIZATION INHIBITOR INJECTION ME-22000

H

H

A

FC

FC

C3's

AI C4's

J

P-22012A/B

J

P-22011A/B FC

K 0 REV

K

FEB FOR PROPOSAL 2017

RK

ISSUE DATE

CAD

DESCRIPTION

PROC LPE PDM ENG

CLIENT

PM

NNF

LUMMUS PETROCHEMICALS "THIS DOCUMENT IS THE PROPERTY OF LUMMUS TECHNOLOGY INC. (LUMMUS). IT CONTAINS CONFIDENTIAL INFORMATION DESCRIBING TECHNOLOGY OWNED BY LUMMUS. IT IS TO BE USED ONLY IN CONNECTION WITH WORK PERFORMED BY LUMMUS. REPRODUCTION IN WHOLE OR IN PART FOR ANY PURPOSE OTHER THAN WORK PERFORMED BY LUMMUS IS FORBIDDEN EXCEPT BY EXPRESS WRITTEN PERMISSION OF LUMMUS. IT IS TO BE SAFEGUARDED AGAINST BOTH DELIBERATE AND INADVERTENT DISCLOSURE TO ANY THIRD PARTY."

L

HP DEPROPANIZER BOTTOMS FROM E-22021

LP DEPROPANIZER BOTTOMS TO C-24005

LP DEPROPANIZER OVERHEAD TO C-22002

VENT TO V-22002

DWG. 2200G

DWG. 2400D

DWG. 2200G

DWG. 2200A

M

PROCESS FLOW DIAGRAM STEAM CRACKER UNIT FRONT-END LOW PRESSURE DEPROPANIZER

2

3

4

5

6

7

8

9

10

11

12

M

DOC. No:

6

1

L

13

14

SCALE:

DWG. No:

A1-222334-2200H 15

REV:

0

16

1

2

3

4

A

5

6

7

8

9

10

11

T-22001

V-22019

MEA STORAGE TANK

MEA DRAIN DRUM

12

13

14

15

16

NOTES:

A

1. TEMPERATURES & PRESSURES ARE SHOWN FOR CASE 1 OPERATION UNLESS OTHERWISE INDICATED. 2. INITIAL MEA FILL FROM TRUCK.

B

B

C

C

D

D

TO ACID GAS FLARE

"B"

E

E

N2

V-22019

"A" PC

LC

ON/OFF

MEA MAKE-UP FROM DRUMS

PM

F

F PC

N2

T-12001 G

G

FC

P-22015

H PM

H

MEA SUMP PUMPS

P-22016A/B MEA MAKEUP PUMPS

FC

J

J TRUCK UNLOADING (NOTE 2)

K

K

FEB 0 2017 FOR PROPOSAL REV

ISSUE DATE

RK

DESCRIPTION

CAD

PROC LPE PDM ENG

CLIENT

PM

LUMMUS PETROCHEMICALS "THIS DOCUMENT IS THE PROPERTY OF LUMMUS TECHNOLOGY INC. (LUMMUS). IT CONTAINS CONFIDENTIAL INFORMATION DESCRIBING TECHNOLOGY OWNED BY LUMMUS. IT IS TO BE USED ONLY IN CONNECTION WITH WORK PERFORMED BY LUMMUS. REPRODUCTION IN WHOLE OR IN PART FOR ANY PURPOSE OTHER THAN WORK PERFORMED BY LUMMUS IS FORBIDDEN EXCEPT BY EXPRESS WRITTEN PERMISSION OF LUMMUS. IT IS TO BE SAFEGUARDED AGAINST BOTH DELIBERATE AND INADVERTENT DISCLOSURE TO ANY THIRD PARTY."

L

M

WATER / DGA MAKEUP TO C-22005

WATER MAKEUP FROM E-20014

DWG. 2200B

DWG. 2000D

PROCESS FLOW DIAGRAM STEAM CRACKER UNIT MEA STORAGE

MEA DRAIN

2

3

4

5

6

M

DOC. No:

2

1

7

8

L

9

10

11

12

13

14

SCALE:

NONE

DWG. No:

15

REV:

A1-222334-2200J 16

0

1

2

3

5

4

6

A

7

8

9

10

11

12

ME-23000-E06

E-23005

ME-23000-E05

ME-23000-E04

OFFGAS EXCHANGER No. 6 (PART OF ME-23000)

ETHYLENE PRODUCT VAPORIZER

OFFGAS EXCHANGER No. 5 (PART OF ME-23000)

OFFGAS EXCHANGER No. 4 (PART OF ME-23000)

13

14

15

16

NOTES: A

1. TEMPERATURES & PRESSURES ARE SHOWN FOR CASE 1 OPERATION UNLESS OTHERWISE INDICATED. 2. START-UP ETHYLENE WILL BE BACKED IN.

B

48°C C3R FROM V-25005 DWG. 2500B

9°C C3R FROM V-25004 DWG. 2500B

-11°C C3R FROM V-25003 DWG. 2500A

B

-28°C C3R FROM V-25002 DWG. 2500A

BR DWG. 2600A

C

A

PC

D

PC

COLD FLARE

COLD FLARE

A

CH4 C2H4

C

H A

A

A

B

B

B

F

F

E

E

C2H4

J

G

C

C

G

G

C

C

DWG. 2300B

D BR DWG. 2600A

J FROM PC ON C-23001 DWG. 2300C

E

D

D

BR DWG. 2600A

J

F

J

D

E -40°C C3R FROM V-25009 DWG. 2600A

E

FROM PC ON V-23003 DWG. 2300B

F

F HIGH LEVEL OVERRIDE

NNF

LC

9°C C3R FROM V-25004 DWG. 2500B

FC SP

G

G FFC

FC

FROM LC ON C-23001 BOTTOMS DWG. 2300C

PC

H

PV

COLD FLARE

H

J

J

PC

K NNF

NNF

NNF

NNF

0 REV

K

FEB FOR PROPOSAL 2017

RK

ISSUE DATE

CAD

DESCRIPTION

PROC LPE PDM ENG

CLIENT

PM

LUMMUS PETROCHEMICALS L

M

START-UP NATURAL GAS TO V-22001

START-UP ETHYLENE VAPOR TO E-24001

ETHYLENE MAKE UP TO V-26003

DWG. 2200A

DWG. 2400A

DWG. 2600A

RAW HYDROGEN TO K-23001 DWG. 2300D

"THIS DOCUMENT IS THE PROPERTY OF LUMMUS TECHNOLOGY INC. (LUMMUS). IT CONTAINS CONFIDENTIAL INFORMATION DESCRIBING TECHNOLOGY OWNED BY LUMMUS. IT IS TO BE USED ONLY IN CONNECTION WITH WORK PERFORMED BY LUMMUS. REPRODUCTION IN WHOLE OR IN PART FOR ANY PURPOSE OTHER THAN WORK PERFORMED BY LUMMUS IS FORBIDDEN EXCEPT BY EXPRESS WRITTEN PERMISSION OF LUMMUS. IT IS TO BE SAFEGUARDED AGAINST BOTH DELIBERATE AND INADVERTENT DISCLOSURE TO ANY THIRD PARTY."

NOTE 2

PROCESS FLOW DIAGRAM STEAM CRACKER UNIT CHARGE GAS CHILLING TRAIN

BL

METHANE OFFGAS TO REGENERATION/ FUEL GAS

START-UP ETHYLENE VAPOR TO E-24003

HP ETHYLENE PRODUCT VAPOR TO

DWG. 2200F

DWG. 2400B

OSBL

ETHANE RECYCLE TO E-20021 DWG. 2000A

DEETHANIZER LOWER FEED TO C-24001

DEETHANIZER UPPER FEED TO C-24001

HP ETHYLENE FROM SPHERES

DWG. 2400A

DWG. 2400A

DWG. 2400D

ETHANE RECYCLE FROM C-24002

(PAGE 1 OF 2)

DEMETHANIZER BOTTOMS FROM P-23002A/B

DWG. 2400B

2

3

4

5

6

7

8

9

10

11

DWG. 2300C

12

13

M

DOC. No:

3

1

L

14

SCALE:

DWG. No:

15

REV:

A1-222334-2300A

0

16

1

2

3

A

4

5

6

7

8

9

10

11

12

ME-23000-E03

V-23001

ME-23000-E02

V-23002

ME-23000-E01

M-23001

V-23003

OFFGAS EXCHANGER No. 3 (PART OF ME-23000)

DEMETHANIZER FEED SEPARATOR No. 1

OFFGAS EXCHANGER No. 2 (PART OF ME-23000)

DEMETHANIZER FEED SEPARATOR No. 2

OFFGAS EXCHANGER No. 1 (PART OF ME-23000)

DEMETHANIZER FEED/ METHANE WASH MIXER

DEMETHANIZER FEED SEPARATOR No. 3

13

14

15

16

NOTES:

A

1. TEMPERATURES & PRESSURES ARE SHOWN FOR CASE 1 OPERATION UNLESS OTHERWISE INDICATED.

B

B

A

A

A

B

B

B

DWG. 2300A

C

C

BR

D

BR

D

BR

G

BR

BR

BR

TC

E

BR

TC METHANOL INJECTION ME-23002

TC

PC

TO BR TCV ON ME-23000-E01 INLET DWG. 2600A

TO PCV ON H2 TO REGEN. DWG. 2300A

E

METHANOL INJECTION ME-23002

TO BR TCV ON ME-23000-E03 INLET DWG. 2600A

TO BR TCV ON ME-23000-E02 INLET DWG. 2600A

HC

HC

F

F NNF

NNF

G

G

LC

LC

LC

H

H

FC

FC

FC

J

J

METHANOL INJECTION ME-12002 DWG. 27001A

K

0 REV

K

FEB FOR PROPOSAL 2017

RK

ISSUE DATE

CAD

DESCRIPTION

PROC LPE PDM ENG

CLIENT

PM

LUMMUS PETROCHEMICALS "THIS DOCUMENT IS THE PROPERTY OF LUMMUS TECHNOLOGY INC. (LUMMUS). IT CONTAINS CONFIDENTIAL INFORMATION DESCRIBING TECHNOLOGY OWNED BY LUMMUS. IT IS TO BE USED ONLY IN CONNECTION WITH WORK PERFORMED BY LUMMUS. REPRODUCTION IN WHOLE OR IN PART FOR ANY PURPOSE OTHER THAN WORK PERFORMED BY LUMMUS IS FORBIDDEN EXCEPT BY EXPRESS WRITTEN PERMISSION OF LUMMUS. IT IS TO BE SAFEGUARDED AGAINST BOTH DELIBERATE AND INADVERTENT DISCLOSURE TO ANY THIRD PARTY."

L

CHARGE GAS FROM E-23001/E-23002

M

DWG. 2300C

DEMETHANIZER BOTTOMS FEED TO C-23001

DEMETHANIZER MIDDLE FEED TO C-23001

METHANE WASH LIQUID FROM P-23001A/B

DEMETHANIZER TOP FEED TO C-23001

DEMETHANIZER NET OVERHEAD FROM V-23004

DWG. 2300C

DWG. 2300C

DWG. 2300C

DWG. 2300C

DWG. 2300C

PROCESS FLOW DIAGRAM STEAM CRACKER UNIT CHARGE GAS CHILLING TRAIN

(PART 2 OF 2)

2

3

4

5

6

7

8

9

10

11

12

13

M

DOC. No:

4

1

L

14

SCALE:

DWG. No:

A1-222334-2300B 15

REV:

0

16

1

2

3

5

4

6

A

7

8

9

10

11

12

13

14

C-23001

E-23002

E-23001

V-23004

ME-23000-E07

DEMETHANIZER

DEMETHANIZER REBOILER

DEMETHANIZER FEED CHILLER

DEMETHANIZER REFLUX DRUM

DEMETHANIZER CONDENSER

15

16

NOTES: 1.

(PART OF ME-23000)

A

TEMPERATURES & PRESSURES ARE SHOWN FOR CASE 1 OPERATION UNLESS OTHERWISE INDICATED.

BR DWG. 2600A

B

B

FC

C

C

D

D

METHANOL INJECTION ME-23002

TC

E

E

LC

F

F PC

LC

TO PCV ON HP METHANE DOWNSTREAM OF ME-23000-E06 DWG. 2300A

G

TO BR LCV ON ME-23000-E07 INLET DWG. 2600A

TO FC ON ME-23000-E04 INLET DWG. 2300A

G

METHANOL INJECTION ME-23002

FC

H

H -40°C C3R DWG. 2500A A CH4

J

J

P-23002A/B

P-23001A/B FC

K 0

M

DEMETHANIZER MIDDLE FEED FROM V-23002

DWG. 2300B

DWG. 2300B

DEMETHANIZER BOTTOM FEED FROM V-23001 DWG. 2300B

BR DRAIN FROM V-26004 / V-26005 DWG. 2600A

ETHYLENE VENT FROM V-24002 DWG. 2400B

2

3

4

5

CAD

DESCRIPTION

PROC LPE PDM ENG

CLIENT

PM

"THIS DOCUMENT IS THE PROPERTY OF LUMMUS TECHNOLOGY INC. (LUMMUS). IT CONTAINS CONFIDENTIAL INFORMATION DESCRIBING TECHNOLOGY OWNED BY LUMMUS. IT IS TO BE USED ONLY IN CONNECTION WITH WORK PERFORMED BY LUMMUS. REPRODUCTION IN WHOLE OR IN PART FOR ANY PURPOSE OTHER THAN WORK PERFORMED BY LUMMUS IS FORBIDDEN EXCEPT BY EXPRESS WRITTEN PERMISSION OF LUMMUS. IT IS TO BE SAFEGUARDED AGAINST BOTH DELIBERATE AND INADVERTENT DISCLOSURE TO ANY THIRD PARTY."

BINARY REFRIG. VENT FROM V-26004 / 26006

DEMETHANIZER BOTTOMS TO ME-23000-E04

CHARGE GAS FROM V-22012 OVERHEAD

CHARGE GAS TO ME-23000-E03

METHANE WASH LIQUID TO V-23003

DEMETHANIZER NET OVERHEAD TO ME-23000-E01

METHANE MAKEUP TO V-26001

LIQUID METHANE MAKEUP TO BR SYSTEM

DWG. 2600A

DWG. 2300A

DWG. 2200G

DWG. 2300B

DWG. 2300B

DWG. 2300B

DWG. 2600A

DWG. 2600A

6

7

8

9

10

11

12

13

L

PROCESS FLOW DIAGRAM STEAM CRACKER UNIT DEMETHANIZER M

DOC. No:

3

1

ISSUE DATE

LUMMUS PETROCHEMICALS

L

DEMETHANIZER TOP FEED FROM V-23003

RK

NNF

NNF

NNF

NNF

NNF

REV

K

FEB FOR PROPOSAL 2017

14

SCALE:

DWG. No:

A1-222334-2300C 15

REV:

0

16

1

A

3

2

5

4

6

7

8

9

10

11

12

13

15

14

16

NOTES:

K-23001

E-23003

E-23004

ME-23001

V-23005

HYDROGEN COMPRESSOR

HYDROGEN COMPRESSOR INTERCOOLER

HYDROGEN COMPRESSOR AFTERCOOLER

HYDROGEN PSA UNIT

FUEL GAS KNOCK-OUT DRUM

A

1. TEMPERATURES & PRESSURES ARE SHOWN FOR CASE 1 OPERATION UNLESS OTHERWISE INDICATED.

B

B

C

C

WET FLARE

PC

PC

A

CO CH4 C2H2 C2H4

PC

D

D FUEL GAS TO F-20001 DWG. 2000B

TO WET FLARE

E

PC

PC

FUEL GAS TO F-20002

A

E

DWG. 2000C

WOBBE

GC

FUEL GAS TO F-20003

AC

DWG. 2000C

MINIMUM FLOW

F

CWS

F

FUEL GAS TO F-20004 DWG. 2000C

LC

SP

FC

G

FC

G

FUEL GAS TO F-20005 DWG. 2000C

M FUEL GAS TO F-20006

H

H

DWG. 2000C

FUEL GAS TO VACUUM BREAKER DWG. 2100B

CWS

FUEL GAS TO F-20007 DWG. 2000C

J

J

START UP

K 0 REV

K

FEB FOR PROPOSAL 2017

RK

ISSUE DATE

CAD

DESCRIPTION

PROC LPE PDM ENG

CLIENT

PM

NNF

ROG FUEL GAS

EXCESS HYDROGEN TO REGENERATION /FUEL GAS

HYDROGEN FROM ME-23000-E06

REGEN OFFGAS FROM REGEN SYSTEM

DWG. 2200F

DWG. 2300A

DWG. 2200F

BL

LIQUID TO C-21003

CONDENSATE TO C-21003

DWG. 2100B

DWG. 2100B

FUEL GAS TO OSBL

"THIS DOCUMENT IS THE PROPERTY OF LUMMUS TECHNOLOGY INC. (LUMMUS). IT CONTAINS CONFIDENTIAL INFORMATION DESCRIBING TECHNOLOGY OWNED BY LUMMUS. IT IS TO BE USED ONLY IN CONNECTION WITH WORK PERFORMED BY LUMMUS. REPRODUCTION IN WHOLE OR IN PART FOR ANY PURPOSE OTHER THAN WORK PERFORMED BY LUMMUS IS FORBIDDEN EXCEPT BY EXPRESS WRITTEN PERMISSION OF LUMMUS. IT IS TO BE SAFEGUARDED AGAINST BOTH DELIBERATE AND INADVERTENT DISCLOSURE TO ANY THIRD PARTY."

HYDROGEN TO E-22031

BL

DWG. 1200E

M

CONDENSATE

NNF

L

NNF

LUMMUS PETROCHEMICALS

PROCESS FLOW DIAGRAM STEAM CRACKER UNIT HYDROGEN PURIFICATION

DWG. 2200F

HYDROGEN EXPORT TO OSBL

HYDROGEN TO R-27001A/B

HYDROGEN TO R-24001A/B

HYDROGEN TO R-28001A/B & R-28002A/B

DWG. 2700A

DWG. 2400C

DWG. 2800A

FUEL GAS SYSTEM

2

3

4

5

6

7

8

9

10

11

12

13

M

DOC. No:

6

1

L

14

SCALE:

DWG. No:

A1-222334-2300D 15

REV:

0

16

1

2

5

6

E-24002

C-24001

E-24016

DEETHANIZER REBOILER

DEETHANIZER

DEETHANIZER LP STEAM REBOILER

3

A

4

7 (NOTE 2)

8

9

10

11

E-24001

V-24001

DEETHANIZER CONDENSER

DEETHANIZER REFLUX DRUM

12

13

14

15

16

NOTES:

A

1. TEMPERATURES & PRESSURES ARE SHOWN FOR CASE 1 OPERATION UNLESS OTHERWISE INDICATED. 2. STARTUP/ SPARE REBOILER. 3. EXCHANGER UTILIZED AS START UP PROPYLENE VAPORIZER.

B

B

PC

PC

C

C TO COLD FLARE

-27°C C3R DWG. 2500A FC NNF

METHANOL INJECTION ME-12002

D

D C2H4 C3H6 C3H8

A

E

E

LC TC

F

F

TO FC ON E-24002 INLET DWG. 2100B

TO LCV ON E-24001 DWG. 2500A

NOTE 2,3

METHANOL INJECTION ME-12002

FC

LC

G

LP COND

G

NNF

LPS

QW DWG. 2100B

NNF

H

H A C2H4 C2H6 C3H4 FC

J

J

P-24002A/B

P-24001A/B

FC

FC

K

TO FFC ON HYDROGEN TO R-24001A/B DWG. 2400C

ISSUE DATE

CAD

DEETHANIZER UPPER FEED FROM ME-23000-E06

OFF SPEC PROPYLENE FROM OSBL

DEETHANIZER LOWER FEED FROM ME-23000-E06

TREATED C2/C3'S FROM C-12004

DEETHANIZER BOTTOMS TO E-24008

PROPYLENE FROM OSBL

START UP PROPYLENE VAPOR TO E-25001A-D

START UP PROPYLENE VAPOR TO C-24004

DEETHANIZER OVERHEAD TO C-24002

STARTUP ETHYLENE VAPOR FROM ME-23000-E06

DWG. 2300A

DWG. 2400E

DWG. 2300A

DWG. 1200F

DWG. 2400C

DWG. 2400E

DWG. 2500B

DWG. 2400C

DWG. 2400B

DWG. 2300A

CLIENT

PM

2

3

4

5

6

7

8

9

10

11

12

13

L

PROCESS FLOW DIAGRAM STEAM CRACKER UNIT DEETHANIZER M

DOC. No:

5

1

PROC LPE PDM ENG

"THIS DOCUMENT IS THE PROPERTY OF LUMMUS TECHNOLOGY INC. (LUMMUS). IT CONTAINS CONFIDENTIAL INFORMATION DESCRIBING TECHNOLOGY OWNED BY LUMMUS. IT IS TO BE USED ONLY IN CONNECTION WITH WORK PERFORMED BY LUMMUS. REPRODUCTION IN WHOLE OR IN PART FOR ANY PURPOSE OTHER THAN WORK PERFORMED BY LUMMUS IS FORBIDDEN EXCEPT BY EXPRESS WRITTEN PERMISSION OF LUMMUS. IT IS TO BE SAFEGUARDED AGAINST BOTH DELIBERATE AND INADVERTENT DISCLOSURE TO ANY THIRD PARTY."

BL

M

DESCRIPTION

LUMMUS PETROCHEMICALS

NNF

L

RK

NNF

START-UP

REV

NNF

START-UP

NNF

START-UP

0

K

FEB FOR PROPOSAL 2017

14

SCALE:

DWG. No:

A1-222334-2400A 15

REV:

0

16

1

A

2

3

5

4

6

7

8

9

10

E-24006

C-24002

E-24007

E-24003A/B

V-24002

ME-24000

ETHYLENE FRACTIONATOR SIDE REBOILER

ETHYLENE FRACTIONATOR

ETHYLENE FRACTIONATOR REBOILER

ETHYLENE FRACTIONATOR CONDENSER

ETHYLENE FRACTIONATOR REFLUX DRUM

ETHYLENE RUNDOWN CHILLER

11

12

13

14

15

16

A

B

B TO PV ON E-24003 C3R INLET DWG. 2500A

PC

PC

C

C

-40°C C3R DWG. 2500A

VAPOR BALANCE

TO COLD FLARE

D HC

D

E

E LC METHANOL INJECTION ME-12002 OSBL FC

F

F

OFFSPEC HP LIQUID ETHYLENE STORAGE

ONSPEC HP LIQUID ETHYLENE STORAGE PV

AC

G

FFC

NOTE 2 C2H4

G

NNF A -10°C C3R DWG. 2500A

TO FC ON C3R TO E-24007 DWG. 2500B

LC

CH4 C2H2 C2H4 C2H6 CO2 C3H6

LC FC

H

H OVERRIDE

NNF

9°C C3R DWG. 2500B

HIGH LEVEL

A H2 CH4 C2H2 C2H4 C2H6 C3H6 H2O CO CO2 CH3OH TOTAL S O2 NH3

P-24003A/B J

BR DWG. 2600B A C2H4 BR DWG. 2600B TC

K

FC

J

BR DWG. 2600B 0

FC START-UP

REV

NNF

RK

ISSUE DATE

CAD

BL

DESCRIPTION

PROC LPE PDM ENG

CLIENT

PM

NNF

NNF

"THIS DOCUMENT IS THE PROPERTY OF LUMMUS TECHNOLOGY INC. (LUMMUS). IT CONTAINS CONFIDENTIAL INFORMATION DESCRIBING TECHNOLOGY OWNED BY LUMMUS. IT IS TO BE USED ONLY IN CONNECTION WITH WORK PERFORMED BY LUMMUS. REPRODUCTION IN WHOLE OR IN PART FOR ANY PURPOSE OTHER THAN WORK PERFORMED BY LUMMUS IS FORBIDDEN EXCEPT BY EXPRESS WRITTEN PERMISSION OF LUMMUS. IT IS TO BE SAFEGUARDED AGAINST BOTH DELIBERATE AND INADVERTENT DISCLOSURE TO ANY THIRD PARTY."

NNF

START-UP

LUMMUS PETROCHEMICALS

NNF

L

K

FEB FOR PROPOSAL 2017

L

PROCESS FLOW DIAGRAM STEAM CRACKER UNIT ETHYLENE FRACTIONATION AND M

DEETHANIZER OVERHEAD FROM V-24001

ETHANE RECYCLE TO ME-23000-E05

STARTUP ETHYLENE VAPOR FROM ME-23000-E06

ETHYLENE RUNDOWN TO STORAGE

OFF-SPEC PRODUCT FROM P-24001A/B

DWG. 2400A

DWG. 2300A

DWG. 2300A

OSBL

DWG. 2400A

ETHYLENE FILL TO V-26004 DWG. 2600A

HP ETHYLENE PRODUCT TO ME-23000-E06

OFFSPEC ETHYLENE TO C-22002

DWG. 2300A

DWG. 2200G

ETHYLENE PRODUCT SYSTEM

ETHYLENE VENT TO C-23001 DWG. 2300C 5

1

2

3

4

5

6

7

8

9

10

11

M

DOC. No:

12

13

14

SCALE:

DWG. No:

A1-222334-2400B 15

REV:

0

16

1

2

A

3

5

4

6

7

8

9

10

11

12

13

E-24008

R-24001A/B

E-24012A/B

C-24004

C-24003

E-24011A/B

E-24009A/B/C/D

V-24003

E-24010

MAPD TRIM REACTOR FEED COOLER

MAPD CONVERTER

PROPYLENE FRACTIONATOR No. 2 REBOILER

PROPYLENE FRACTIONATOR No. 2

PROPYLENE FRACTIONATOR No. 1

PROPYLENE FRACTIONATOR No. 1 REBOILER

PROPYLENE FRACTIONATOR CONDENSER

PROPYLENE FRACTIONATOR REFLUX DRUM

PROPYLENE FRACTIONATOR VENT CONDENSER

14

15

16

NOTES:

A

1. TEMPERATURES & PRESSURES ARE SHOWN FOR CASE 1 OPERATION UNLESS OTHERWISE INDICATED. 2. LOCATE TC CLOSE TO REACTOR R-24001A/B INLET.

PC

3. CONTINUOUS ANALYSER. 4. E-24011 B IS A SPARE REBOILER. LOW PRESSURE OVERRIDE

PC

B

FC

B

CWS

C NOTE 2

TC

C

NNF

CWS HC

C kg/cm²g

SOR 37.7 23.7

EOR

D

TO COLD FLARE

D

A MAPD C3H8 LC PdC NOTE 3 AI FC

E

E

C3H6 LC

NNF

LC

FC

LC

NOTE 4

FC QW TO

QW DWG. 2100B

NOTE 4 QW DWG. 2100B

QW FROM E-24012A/B

E-24011A/B

F

START-UP NNF

F

QW DWG. 2100B

G A FC

MAPD C3H6

FFC

START-UP

SETPOINT

G

H

TO ATM.

P-24006A/B

P-24007A/B

H

P-24005A/B

NNF

P-24004A/B

TO WET FLARE

A MAPD C3H8

J

J

FC

FROM FC ON C-24001 BTMS DWG. 2400A

DWG. 2000A

H2 CH4 C2H4 C2H6 MAPD C3H8

0

REGENERATION ONLY

CWS

FFC

REGENERATION ONLY

K

A HIGH LEVEL OVERRIDE FROM E-20020

FC

REV

M

REGENERATION EFFLUENT TO E-22009

DWG. 2200F

DWG. 2200F

START UP PROPYLENE VAPOR TO C-22002 AND R-22001A/B/C

REGEN GAS FROM E-22011

PROPANE RECYCLE TO E-20020

START-UP PROPYLENE VAPOR FROM E-24016

PROPYLENE PRODUCT TO E-24017

PRESSURIZATION GAS TO V-24006A/B

START UP PROPYLENE FILL FROM OSBL

DEINVENTORY FROM V-24006A/B

PROPYLENE VENT TO V-22003

DWG. 2300D

DWG. 2400A

DWG. 2200F

DWG. 2200F

DWG. 2000A

DWG. 2400A

DWG. 2400E

DWG. 2400E

DWG. 2400E

DWG. 24000E

DWG. 2200A

PROC LPE PDM ENG

CLIENT

PM

5

6

7

8

9

10

11

L

12

13

M

DOC. No:

6

4

DESCRIPTION

PROCESS FLOW DIAGRAM STEAM CRACKER UNIT PROPYLENE FRACTIONATION

REACTOR REGEN GAS FROM HEADER

3

CAD

DWG. 2200G

DEETHANIZER BOTTOMS FROM P-24002A/B

2

ISSUE DATE

"THIS DOCUMENT IS THE PROPERTY OF LUMMUS TECHNOLOGY INC. (LUMMUS). IT CONTAINS CONFIDENTIAL INFORMATION DESCRIBING TECHNOLOGY OWNED BY LUMMUS. IT IS TO BE USED ONLY IN CONNECTION WITH WORK PERFORMED BY LUMMUS. REPRODUCTION IN WHOLE OR IN PART FOR ANY PURPOSE OTHER THAN WORK PERFORMED BY LUMMUS IS FORBIDDEN EXCEPT BY EXPRESS WRITTEN PERMISSION OF LUMMUS. IT IS TO BE SAFEGUARDED AGAINST BOTH DELIBERATE AND INADVERTENT DISCLOSURE TO ANY THIRD PARTY."

HYDROGEN FROM HYDROGEN PSA

1

RK

LUMMUS PETROCHEMICALS

L REACTOR REDUCTION GAS FROM E-22031

K

FEB FOR PROPOSAL 2017

14

SCALE:

DWG. No:

A1-222334-2400C 15

REV:

0

16

1

2

3

A

5

6

E-24014A/B

C-24005

E-24015

E-24013

V-24004

DEBUTANIZER REBOILER

DEBUTANIZER

PYROLYSIS GASOLINE COOLER

DEBUTANIZER CONDENSER

DEBUTANIZER REFLUX DRUM

4

7

8

9

10

11

12

13

14

15

16

NOTES:

A

1. TEMPERATURES & PRESSURES ARE SHOWN FOR CASE 1 OPERATION UNLESS OTHERWISE INDICATED. 2. ONE OPERATING, ONE STAND BY.

B

B

PC

PC

C

C

TO WET FLARE

D

D

HC

CWS

E

E

LC POLYMERIZATION INHIBITOR INJECTION ME-22000 TC

F

F

FC LC LP COND

DS LPS

G

G

NOTE 2

A

H

C4's

H

FC

FC

A

J

C3'S C5'S

J

FC

P-24008A/B

CWS

K 0

NNF

NNF GASOLINE POLYNIERIZATION INHIBITOR INJECTION ME-21001

REV

TBC INHIBITOR INJECTION ME-24002

M

BL

2

NNF

GASOLINE FROM P-21006A/B

RAW PYROLYSIS GASOLINE TO PGH UNIT

RAW PYROLYSIS GASOLINE

MIXED C4S TO/FROM STORAGE

MIXED C4's TO V-27001

VENT TO V-22002

DWG. 2200H

DWG. 2100B

DWG. 2800A

OSBL

OSBL

DWG. 2700A

DWG. 2100B

4

5

6

CAD

7

8

DESCRIPTION

PROC LPE PDM ENG

CLIENT

PM

9

10

11

12

L

PROCESS FLOW DIAGRAM STEAM CRACKER UNIT DEBUTANIZER

BL

LP DEPROPANIZER BOTTOMS FROM C-22003

3

ISSUE DATE

"THIS DOCUMENT IS THE PROPERTY OF LUMMUS TECHNOLOGY INC. (LUMMUS). IT CONTAINS CONFIDENTIAL INFORMATION DESCRIBING TECHNOLOGY OWNED BY LUMMUS. IT IS TO BE USED ONLY IN CONNECTION WITH WORK PERFORMED BY LUMMUS. REPRODUCTION IN WHOLE OR IN PART FOR ANY PURPOSE OTHER THAN WORK PERFORMED BY LUMMUS IS FORBIDDEN EXCEPT BY EXPRESS WRITTEN PERMISSION OF LUMMUS. IT IS TO BE SAFEGUARDED AGAINST BOTH DELIBERATE AND INADVERTENT DISCLOSURE TO ANY THIRD PARTY."

M

DOC. No:

5

1

RK

LUMMUS PETROCHEMICALS

L BL

K

FEB FOR PROPOSAL 2017

13

14

SCALE:

DWG. No:

A1-222334-2400D 15

REV:

0

16

1

2

A

3

5

4

6

7

8

V-24006A/B

ME-24001

PG PROPYLENE TREATERS

PROPYLENE RUNDOWN CHILLER PACKAGE

9

10

11

12

13

14

15

16

NOTES: A

1. TEMPERATURES & PRESSURES ARE SHOWN FOR CASE 1 OPERATION UNLESS OTHERWISE INDICATED.

B

B

C

C

D

D

A COS OSBL

E

ONSPEC HP LIQUID PROPYLENE STORAGE

NOTE 2

E

OFFSPEC HP LIQUID PROPYLENE STORAGE

A

F

F

COS NNF

G NNF

G

H

H

CWS A

C3R DWG. 25001B

H2 CH4 C2H4 C2H6 MAPD C3H8 H2O COS CO CH3OH

C3R DWG. 25001B

J

J

FC

K NNF

0 REV

RK

ISSUE DATE

CAD

DWG. 24000C

NNF

DWG. 24000C

BL PROPYLENE PRODUCT FROM P-24007A/B

REGEN GAS FROM E-24018

REGEN GAS TO E-22009

PRESSURIZING GAS FROM C-24003

DWG. 24000C

DWG. 22000E

DWG. 22000E

DWG. 24000C

M

PROPYLENE REFRIG. PUMPOUT FROM P-25001

OSBL

DWG. 25000A

POLYMER GRADE PROYLENE PRODUCT

START UP PROPYLENE TO E-24016

OFFSPEC PROPYLENE TO C-24001

PROPYLENE FILL AND MAKEUP TO V-25004

START UP PROPYLENE FILL TO V-22012

DWG. 24000A

DWG. 24000A

DWG. 25000B

DWG. 22000F

2

3

4

5

6

7

8

9

10

11

12

13

L

M

DOC. No:

5

1

CLIENT

PM

PROCESS FLOW DIAGRAM STEAM CRACKER UNIT PROPYLENE PRODUCT SYSTEM

BL

PROPYLENE RUNDOWN TO STORAGE

PROC LPE PDM ENG

"THIS DOCUMENT IS THE PROPERTY OF LUMMUS TECHNOLOGY INC. (LUMMUS). IT CONTAINS CONFIDENTIAL INFORMATION DESCRIBING TECHNOLOGY OWNED BY LUMMUS. IT IS TO BE USED ONLY IN CONNECTION WITH WORK PERFORMED BY LUMMUS. REPRODUCTION IN WHOLE OR IN PART FOR ANY PURPOSE OTHER THAN WORK PERFORMED BY LUMMUS IS FORBIDDEN EXCEPT BY EXPRESS WRITTEN PERMISSION OF LUMMUS. IT IS TO BE SAFEGUARDED AGAINST BOTH DELIBERATE AND INADVERTENT DISCLOSURE TO ANY THIRD PARTY."

NNF

NNF

NNF NNF

L

START UP PROPYLENE FILL TO V-24003

DESCRIPTION

LUMMUS PETROCHEMICALS

BL DEINVENTORY TO V-24003

K

FEB FOR PROPOSAL 2017

14

SCALE:

DWG. No:

A1-222334-2400E 15

REV:

0

16

1

A

2

3

5

4

6

V-25001

V-25009

V-25013

V-25017

PROPYLENE REFRIG. COMPRESSOR 1ST STAGE SUCTION DRUM

LIQUID PROPYLENE ACCUMULATOR

LIQUID PROPYLENE ACCUMULATOR No. 4

LIQUID PROPYLENE ACCUMULATOR No. 4

FOR ME-23000-E05

FOR ME-12000-E01

7

8

V-25002

FOR ME-24001

9

V-25008

PROPYLENE REFRIG. COMPRESSOR LIQUID PROPYLENE 2ND STAGE SUCTION DRUM ACCUMULATOR FOR E-24006

10

11

12

13

K-25001

V-25003

V-25012

V-25016

PROPYLENE REFRIGERANT COMPRESSOR

PROPYLENE REFRIG. COMPRESSOR 3RD STAGE SUCTION DRUM

LIQUID PROPYLENE ACCUMULATOR No. 3

LIQUID PROPYLENE ACCUMULATOR No. 3

FOR ME-12000-E01

14

15

16

NOTES: A

1. TEMPERATURES & PRESSURES ARE SHOWN FOR CASE 1 OPERATION UNLESS OTHERWISE INDICATED.

FOR ME-24001

2. MULTI-POINT METHANOL INJECTION FROM ME-12002.

C3R VAPOR FROM V-25011/V-25015/ E-11003

B

HIGH LEVEL OVERRIDE

LC LC

C BR

D

D

G

G

C

C

DWG. 2400A

FROM LC ON V-24001 DWG. 2400A

C

DWG. 2300A

MeOH NOTE 2 DWG. 2200H

DWG. 24001B

HIGH LEVEL OVERRIDE

LC

FROM PC ON C-24002 DWG. 2400B

LC COLD FLARE

LC

E MeOH NOTE 2

PC

DWG. 2200G

PC

MeOH NOTE 2

MeOH NOTE 2

D

HIGH LEVEL OVERRIDE

F PC DWG. 2200D

DWG. 1200F

LC MeOH NOTE 2

COLD FLARE

E PC

DWG. 12001F LC

MeOH NOTE 2

FROM LC ON V-22012 DWG. 2200G

DWG. 23001C LC

MeOH NOTE 2

FROM PC ON LP DEC3 OVHD DWG. 2200H

DWG. 22001F

HIGH LEVEL OVERRIDE

DWG. 2400B

HIGH LEVEL OVERRIDE

LC MeOH NOTE 2

COLD FLARE

LC

LC

DWG. 22001G

D

B

DWG. 2500B

DWG. 24001A

MeOH NOTE 2

FROM PC ON C-12004 OVHD DWG. 1200F

F TC

PROPYLENE FROM V-25006/25007, ME-23000-E06

LC

MeOH NOTE 2

MeOH NOTE 2

DWG. 2500B

G

G FROM C3R ON ME-23000-E06 DWG. 2500B

HC

DWG. 2400B

TO P-25001

H

NNF

NNF

LC

TO P-25001

C2 SIDE DRAW DWG. 2400B

H

MeOH NOTE 2 C2 RECYCLE DEC2 FEED

OFFGASSES

MeOH NOTE 2

LC

DWG. 2300A

TC

C2 RECYCLE DEC2 FEED

FROM V-25002 V-25003 V-25004 FC

NNF

NNF

J

OFFGASSES

C3R QUENCH FROM V-25004

DWG. 2300A

DWG. 2500B

FY

FY

J

C3R FROM K-25001 DISCH. DWG. 2500B

NORMAL FC

K

STONEWALL FLOW

RUNDOWN FC

NNF

PROPYLENE TO V-25004

0 REV

TC

SC

PROPYLENE REFRIG. PUMPOUT TO STORAGE

DWG. 2500B

TO FCV ON V-25004 INLET DWG. 2500B

FC

3

4

SCALE:

5

6

7

8

9

10

11

12

13

L

M

DOC. No:

4

2

CLIENT

PM

SHEET 1 OF 2

DWG. 2500B

SHP STEAM

PROC LPE PDM ENG

PROCESS FLOW DIAGRAM STEAM CRACKER UNIT PROPYLENE REFRIGERATION SYSTEM

PROPYLENE TO E-25001A-D

DWG. 2400E

1

CAD

DESCRIPTION

"THIS DOCUMENT IS THE PROPERTY OF LUMMUS TECHNOLOGY INC. (LUMMUS). IT CONTAINS CONFIDENTIAL INFORMATION DESCRIBING TECHNOLOGY OWNED BY LUMMUS. IT IS TO BE USED ONLY IN CONNECTION WITH WORK PERFORMED BY LUMMUS. REPRODUCTION IN WHOLE OR IN PART FOR ANY PURPOSE OTHER THAN WORK PERFORMED BY LUMMUS IS FORBIDDEN EXCEPT BY EXPRESS WRITTEN PERMISSION OF LUMMUS. IT IS TO BE SAFEGUARDED AGAINST BOTH DELIBERATE AND INADVERTENT DISCLOSURE TO ANY THIRD PARTY."

FC

M

ISSUE DATE

LUMMUS PETROCHEMICALS

C3R VAPOR FROM V-25004

L

RK

DWG. 2500B

P-25001

K

FEB FOR PROPOSAL 2017

14

DWG. No:

A1-222334-2500A 15

REV:

0

16

1

3

2

V-25006

V-25007

LIQUID PROPYLENE ACCUMULATOR

A

V-25011

LIQUID PROPYLENE ACCUMULATOR

FOR E-24007

5

4 LIQUID PROPYLENE ACCUMULATOR No. 2

FOR E-23005

FOR ME-12000-E01

6

7

8

9

10

11

13

12

V-25015

E-28019

V-25004

V-25005

V-25014

V-25010

E-25001A-D

E-27003

LIQUID PROPYLENE ACCUMULATOR No. 2

BTX TOWER VENT CONDENSER

PROPYLENE REFRIG. COMPRESSOR 4TH STAGE SUCTION DRUM

PROPYLENE REFRIGERANT ACCUMULATOR

LIQUID PROPYLENE ACCUMULATOR No. 1

LIQUID PROPYLENE ACCUMULATOR No. 1

PROPYLENE REFRIGERATION CONDENSERS

C4/C5 HP FLASH VENT CONDENSER

FOR ME-24001

FOR ME-24001

FOR ME-12000-E01

15

14

16

NOTES: A

1. TEMPERATURES & PRESSURES ARE SHOWN FOR CASE 1 OPERATION UNLESS OTHERWISE INDICATED. 2. MULTI-POINT METHANOL INJECTION FROM ME-12002.

C3R VAPOR TO V-25003

B

B

DWG. 2500A LC LOW TEMP

LC

LC

C

OVERRIDE FC

TUBE SIDE DWG. 2800D

LC

FROM TC ON DWG. 1200E

C DWG. 12001B

HIGH LEVEL OVERRIDE

LC

DWG. 1200B

D

FROM TC ON C-12002 DWG.1200B

D

LC TUBE SIDE DWG. 2700A

COLD FLARE

FC

LC

E

E DWG. 2300A PC

LC

HIGH LEVEL OVERRIDE

LC

FC

DWG. 2400B

DWG. 2200D

LC

PROPYLENE TO V-25003

FROM TC ON V-22004 GC OUTLET DWG. 2200D

F

DWG. 2200D LC

C2 BOTTOMS DWG. 2400B

LI

TO LC ON V-25003 DWG. 2500A

DWG. 2200D

MeOH NOTE 2

TO P-25001 DWG. 2500A

HIGH LEVEL OVERRIDE

DWG. 2500A

NNF

G

OVERRIDE

LOW LEVEL

F

DWG. 2200D

DWG. 2300A

FROM AC ON C-24002 DWG. 2400B

FROM TC ON V-22005 GC OUTLET DWG. 2200D

G

MeOH NOTE 2

H

DEC2 FEED

C2 RECYCLE

J

DEC2 FEED

C3R VAPOR TO K-25001

OFFGASSES

C2 RECYCLE OFFGASSES

DWG. 2300A FC

FROM TC ON C-12003 DWG. 1200E

RDG DEC 1

C3R QUENCH TO V-25001/25002, 25003 FROM FC ON K-25001 DWG. 2500A

DWG. 2500A PROPYLENE FROM P-25001

DWG. 1200E

0

TO V-22002 DWG. 2200A

DWG. 2500A C3R MIN FLOW TO V-25001/25002/25003

REV

RK

ISSUE DATE

CAD

HC

PC

DWG. 2500A

M

2

3

4

5

STARTUP PROPYLENE VAPOR FROM E-24016

PROPYLENE FILL AND MAKE-UP FROM OSBL

DWG. 2400A

DWG. 2400E

6

7

CLIENT

PM

L

PROCESS FLOW DIAGRAM STEAM CRACKER UNIT PROPYLENE REFRIGERATION SYSTEM

NNF

PROPYLENE FROM K-25001

LC

OVERRIDE FC

PROC LPE PDM ENG

"THIS DOCUMENT IS THE PROPERTY OF LUMMUS TECHNOLOGY INC. (LUMMUS). IT CONTAINS CONFIDENTIAL INFORMATION DESCRIBING TECHNOLOGY OWNED BY LUMMUS. IT IS TO BE USED ONLY IN CONNECTION WITH WORK PERFORMED BY LUMMUS. REPRODUCTION IN WHOLE OR IN PART FOR ANY PURPOSE OTHER THAN WORK PERFORMED BY LUMMUS IS FORBIDDEN EXCEPT BY EXPRESS WRITTEN PERMISSION OF LUMMUS. IT IS TO BE SAFEGUARDED AGAINST BOTH DELIBERATE AND INADVERTENT DISCLOSURE TO ANY THIRD PARTY."

NNF

MIN. FLOW BYPASS

L

DESCRIPTION

LUMMUS PETROCHEMICALS

WET FLARE LOW LEVEL

K

FEB FOR PROPOSAL 2017

HC

DWG. 2500A

1

J

DWG. 2300A

DWG. 2500A

K

H

SHEET 2 OF 2

CWS

M

DOC. No: SCALE:

6

8

9

10

11

12

13

14

DWG. No:

A1-222334-2500B 15

REV:

0

16

1

V-26006 A

3

2

V-26007

5

4

K-26001

BINARY REFRIGERANT REFRIGERANT COMPRESSOR RETROGRADE CASING DRAIN POT

6

V-26005

7

V-26001

BINARY REFRIGERANT BINARY REFRIGERANT COMPRESSOR COMPRESSOR SUCTION DRUM BLOWCASE

8

9

E-26001

BINARY REFRIGERANT COMPRESSOR BINARY REFRIGERANT 1ST STAGE SUCTION DRUM COOLER

10

11

13

12

15

14

V-26002

V-26003

V-26004

BINARY REFRIGERANT COMPRESSOR 2ND STAGE SUCTION DRUM

BINARY REFRIGERANT COMPRESSOR 3RD STAGE SUCTION DRUM

BINARY REFRIGERANT ACCUMULATOR

NOTES:

CHARGE GAS TO V-23003

B

CHARGE GAS FROM V-23002

CHARGE GAS TO V-23002

CHARGE GAS FROM V-23001

CHARGE GAS TO V-23001 DWG. 2300D

DEMETHANIZER BOTTOMS DWG. 2300C

CHARGE GAS FROM E-23001 / E-23002 DWG. 2300C

TO V-23004

VENT TO C-23001 DWG. 2300C

HC

HC

HP ETHYLENE TO E-23005 DWG. 2300A

J

E

F

J

E

DWG. 2300B

F

DWG. 2300C

HYDROGEN FROM V-23003 METHANE FROM V-23004

NNF

C

DEC 1 OVERHEAD

DWG. 2300B

3. MULTI-POINT METHANOL INJECTION FROM ME-12002.

B

DWG. 2300B DWG. 2300B

2. DRUM SHARED WITH K-25001.

DEC1 BTMS TO C-24001 DWG. 2300A HP ETHYLENE FROM E-23005 DWG. 2300A

ETHANE RECYCLE DWG. 2300A

A

A

HYDROGEN TO K-23001

B

B

METHANE TO REGENERATION / FUEL GAS D J

Q

J

D

E

G FROM TC ON CHARGE GAS FROM ME-23000-E03 DWG. 2300B

NNF

FROM TC ON CHARGE GAS FROM ME-23000-E02 DWG. 2300B TI

C

C

G

G

METHANOL NOTE 3 TC

FROM TC ON CHARGE GAS FROM ME-23000-E01 DWG. 2300B

D G

G

-40°C C3R

TI

TI

TI

TC

FC

PC

TC

E

F

PC

TO COLD FLARE

TC HC

NNF

PC

48°C C3R

PC

NNF

PC

9°C C3R

-11°C C3R

DWG. 2300B

TI

TO COLD FLARE

TO COLD FLARE

-28°C C3R

TO C-23001 DWG. 2300C FC

METHANOL NOTE 3

DWG. 2300A

FY

F

HP ETHYLENE VAPOR TO OSBL DWG. 2300A

H

LI

TO COLD FLARE

C

ETHANE TO E-2001

NNF

FROM LC ON V-23004 DWG. 2300C

A

1. TEMPERATURES & PRESSURES ARE SHOWN FOR CASE 1 OPERATION UNLESS OTHERWISE INDICATED.

NOTE 2 HP ETHYLENE FROM STORAGE SPHERES DWG. 2300A

16

G

G PC

HC LOW LEVEL

LC

OVERRIDE NNF

MIN. FLOW

LIQUID QUENCH

NNF

NNF

LIQUID QUENCH

NNF

H

LC MIN. FLOW

LC MIN. FLOW

LI

LIQUID QUENCH

H

NNF LIQUID QUENCH

J

NNF

J

TO COLD FLARE NNF

TI

HC

LI

#2

FC

K 0

NNF

HC

RK

ISSUE DATE

CAD

NNF

METHANE MAKEUP FROM V-23004

BR FROM ME-24000/ ME-12000-E02

BR FROM ME-24000/ ME-12000-E02

VAPOR ETHYLENE MAKEUP FROM ME-23000-E06

BR TO ME-24000-E07

BR DRAIN TO C-23001

LIQUID ETHYLENE FILL FOR START-UP FROM OSBL STORAGE

DWG. 2300C

DWG. 2600B

DWG. 2600B

DWG. 2300A

DWG. 2600B

DWG. 2300C

DWG. 2400B

3

4

5

6

7

8

9

10

11

12

CLIENT

PM

L

PROCESS FLOW DIAGRAM STEAM CRACKER UNIT BINARY REFRIGERATION SYSTEM

(PART 1 OF 2)

K-25001

2

PROC LPE PDM ENG

"THIS DOCUMENT IS THE PROPERTY OF LUMMUS TECHNOLOGY INC. (LUMMUS). IT CONTAINS CONFIDENTIAL INFORMATION DESCRIBING TECHNOLOGY OWNED BY LUMMUS. IT IS TO BE USED ONLY IN CONNECTION WITH WORK PERFORMED BY LUMMUS. REPRODUCTION IN WHOLE OR IN PART FOR ANY PURPOSE OTHER THAN WORK PERFORMED BY LUMMUS IS FORBIDDEN EXCEPT BY EXPRESS WRITTEN PERMISSION OF LUMMUS. IT IS TO BE SAFEGUARDED AGAINST BOTH DELIBERATE AND INADVERTENT DISCLOSURE TO ANY THIRD PARTY."

#1

NNF

COLD FLARE

DESCRIPTION

LUMMUS PETROCHEMICALS

A

CWS

HS

DWG. 2300C

1

H2 CH4 C2H4 C2H6

NNF

LIQUID METHANE MAKEUP FROM V-23004

M

PC

FC

NNF

L

FC

MIN. FLOW

MIN. FLOW

NNF

SC

VAPOR

REV

K

FEB FOR PROPOSAL 2017

M

DOC. No:

4

13

14

SCALE:

DWG. No:

15

REV:

A1-222334-2600A

0

16

1

2

3

4

5

6

7

8

9

10

11

12

13

14

15

16

NOTES: A

A

TEMPERATURES & PRESSURES ARE SHOWN FOR CASE 1 OPERATION UNLESS OTHERWISE INDICATED.

1.

B

B

C

C PC

ETHYLENE RUNDOWN DWG. 2400B

DWG. 2400B

D

TC DWG. 1200E

TC

D

TO V-12007 DWG. 1200E

ETHYLENE TO STORAGE

C-12003 OVERHEAD DWG. 1200E

TC

FROM TC ON MIXED LPG FEED TO C-12007 DWG. 1200E

E

E

FROM TC ON V-12007 OVERHEAD DWG. 1200E

F

F

G

FUEL GAS FROM V-12007 DWG. 1200E

C

FUEL GAS TO V-22011 DWG. 2200F

MIXED LPG TO C-12003 DWG. 1200E

B

MIXED LPG FROM V-12012A/B DWG. 1200E

TREATED DRY GAS TO C-12003 DWG. 1200E

A

TREATED DRY GAS FROM V-12006A/B DWG. 1200E

G

DWG. 1200E

H

H

J

J

K 0 REV

K

FEB FOR PROPOSAL 2017

RK

ISSUE DATE

CAD

DESCRIPTION

PROC LPE PDM ENG

CLIENT

PM

LUMMUS PETROCHEMICALS "THIS DOCUMENT IS THE PROPERTY OF LUMMUS TECHNOLOGY INC. (LUMMUS). IT CONTAINS CONFIDENTIAL INFORMATION DESCRIBING TECHNOLOGY OWNED BY LUMMUS. IT IS TO BE USED ONLY IN CONNECTION WITH WORK PERFORMED BY LUMMUS. REPRODUCTION IN WHOLE OR IN PART FOR ANY PURPOSE OTHER THAN WORK PERFORMED BY LUMMUS IS FORBIDDEN EXCEPT BY EXPRESS WRITTEN PERMISSION OF LUMMUS. IT IS TO BE SAFEGUARDED AGAINST BOTH DELIBERATE AND INADVERTENT DISCLOSURE TO ANY THIRD PARTY."

L

BR TO V-26001

M

BR TO V-26002

PROCESS FLOW DIAGRAM STEAM CRACKER UNIT BINARY REFRIGERATION SYSTEM

(PART 2 OF 2)

BR FROM V-26004

M

DOC. No:

DWG. 2600A

DWG. 2600A

DWG. 2600A 3

1

2

3

4

5

L

6

7

8

9

10

11

12

13

14

SCALE:

DWG. No:

15

REV:

A1-222334-2600B

0

16

1

2

3

4

5

6

7

8

9

10

11

12

13

14

15

16

NOTES:

A

A

1. TEMPERATURES & PRESSURES ARE SHOWN FOR CASE 1 OPERATION UNLESS OTHERWISE INDICATED.

B

B

PC NORMAL OPERATION SOR EOR C kg/cm²g

C

C TC

FC

SOR

EOR

C kg/cm²g MPS

WET FLARE

D

D HC

MP COND.

E

E NORMAL OPERATION SOR EOR C kg/cm²g

CW

LC

9°C C3R DWG. 2500B

LC

F

NNF

RESET

F

TO WET FLARE

TO ATM.

G

G

PC

C kg/cm²g

FC

LC

H

FC

NNF

FC

FC

HIGH LEVEL OVERRIDE

RESET

H

J

J

FROM LC ON V-21001 DWG. 2000A

FI

K

REV

REGENERATION GAS FROM E-22011 DWG. 2200F

M

HYDROGEN FROM ME-23001

REGEN. EFFLUENT TO C-21003 DWG. 2100B

DWG. 2300D

2

3

4

5

ROG HEAVIES FROM P-12027A/B

C5 RECYCLE FROM P-28003A/B

MIXED SATURATED LPG FROM

C4/C5 RECYCLE TO V-20012

OFFGAS TO V-22004

DWG. 2400D

DWG. 1200F

DWG. 2800B

OSBL

DWG. 2000A

DWG. 2200D

7

8

9

CAD

PROC LPE PDM ENG

CLIENT

PM

L

PROCESS FLOW DIAGRAM C4/C5 HYDROGENATION UNIT

MIXED C4'S FROM P-24008A/B

6

DESCRIPTION

"THIS DOCUMENT IS THE PROPERTY OF LUMMUS TECHNOLOGY INC. (LUMMUS). IT CONTAINS CONFIDENTIAL INFORMATION DESCRIBING TECHNOLOGY OWNED BY LUMMUS. IT IS TO BE USED ONLY IN CONNECTION WITH WORK PERFORMED BY LUMMUS. REPRODUCTION IN WHOLE OR IN PART FOR ANY PURPOSE OTHER THAN WORK PERFORMED BY LUMMUS IS FORBIDDEN EXCEPT BY EXPRESS WRITTEN PERMISSION OF LUMMUS. IT IS TO BE SAFEGUARDED AGAINST BOTH DELIBERATE AND INADVERTENT DISCLOSURE TO ANY THIRD PARTY."

10

11

12

13

M

DOC. No:

8

1

ISSUE DATE

RK

LUMMUS PETROCHEMICALS

START-UP ONLY

L

K

FEB 0 2017 FOR PROPOSAL

14

SCALE:

NONE

DWG. No:

15

REV:

A1-222334-2700A 16

0

1

2

3

5

4

6

7

8

9

10

11

12

13

14

15

16

A

A 1. TEMPERATURES & PRESSURES ARE SHOWN FOR CASE 1 OPERATION UNLESS OTHERWISE INDICATED. 2. TWO RECYCLE EXCHANGERS ARE PROVIDED. ONE FOR EACH REACTOR WITH ONLY ONE EXCHANGER IN OPERATION DURING NORMAL OPERATION. 3. P-28002A IS DEDICATED TO R-28001A, P-28003B IS DEDICATED TO R-28001B, P-28002C WILL BE A COMMON SPARE.

PC

B

TO OTHER REACTOR

C

NORMAL OPERATION SOR EOR C kg/cm²g

TC

REGENERATION C 480 kg/cm²g 1.0

"B" WET FLARE

C

FROM OTHER REACTOR

"A"

NORMAL OPERATION SOR EOR C kg/cm²g

NITROGEN

D

B

PC

TO WET FLARE

D

FC

HC LC

C kg/cm²g

C kg/cm²g

45 3.8 SOR

E

EOR

E

C kg/cm²g

CW LC

FC

F

F

"B"

LC

NOTE 2

OWS

G

"A"

HS

SP

HP COND.

G

FROM OTHER REACTOR

FC NOTE 2

H

H

REGENERATION

REGENERATION

CW

J

J

NOTE 3 FI

FI

K

REV

ISSUE DATE

NNF RAW PYROLYSIS GASOLINE FROM E-24015

HYDROGEN FEED FROM ME-23001

HYDROGEN TO V-28012

START-UP NAPHTHA TO C-28003

START-UP NAPHTHA FROM P-20001A/B

FIRST STAGE REACTOR EFFLUENT TO V-28005

OFFGAS TO V-28012

REACTOR REGEN GAS TO SCU

REACTOR REGEN GAS FROM SCU

DWG. 2400D

DWG. 2300D

DWG. 2800C

DWG. 2800C

DWG. 2000A

DWG. 2800B

DWG. 2800C

DWG. 2800C

DWG. 2800C

4

5

6

7

8

PROC LPE PDM ENG

CLIENT

PM

9

10

11

12

13

L

M

DOC. No:

5

3

CAD

PROCESS FLOW DIAGRAM PYROLYSIS GASOLINE HYDROGENATION UNIT PGH FIRST STAGE REACTOR

BL

2

DESCRIPTION

"THIS DOCUMENT IS THE PROPERTY OF LUMMUS TECHNOLOGY INC. (LUMMUS). IT CONTAINS CONFIDENTIAL INFORMATION DESCRIBING TECHNOLOGY OWNED BY LUMMUS. IT IS TO BE USED ONLY IN CONNECTION WITH WORK PERFORMED BY LUMMUS. REPRODUCTION IN WHOLE OR IN PART FOR ANY PURPOSE OTHER THAN WORK PERFORMED BY LUMMUS IS FORBIDDEN EXCEPT BY EXPRESS WRITTEN PERMISSION OF LUMMUS. IT IS TO BE SAFEGUARDED AGAINST BOTH DELIBERATE AND INADVERTENT DISCLOSURE TO ANY THIRD PARTY."

L

1

RK

LUMMUS PETROCHEMICALS

FC

M

K

FEB 0 2017 FOR PROPOSAL

14

SCALE:

NONE

DWG. No:

15

REV:

A1-222334-2800A 16

0

1

2

3

5

4

6

7

8

9

10

11

12

13

14

15

16

A

A 1. TEMPERATURES & PRESSURES ARE SHOWN FOR CASE 1 OPERATION UNLESS OTHERWISE INDICATED. 2. CASE 1: C5's TO C4/C5 HYDROGENATION UNIT. CASE 2: C5's TO CRACKING HEATERS.

PC

B

B

PC

C kg/cm²g

C

C C kg/cm²g CW

D

D

LC SP FC

"B"

E

E SP

TC C kg/cm²g

LC

FC

F DS MPS

F

LC

C kg/cm²g MP COND.

NNF

SP

LI

G FC

SP

G FC OWS

H

H

J

J

FC

K

K

FEB 0 2017 FOR PROPOSAL REV

ISSUE DATE

RK

DESCRIPTION

CAD

PROC LPE PDM ENG

CLIENT

PM

LUMMUS PETROCHEMICALS NOTE 2

"THIS DOCUMENT IS THE PROPERTY OF LUMMUS TECHNOLOGY INC. (LUMMUS). IT CONTAINS CONFIDENTIAL INFORMATION DESCRIBING TECHNOLOGY OWNED BY LUMMUS. IT IS TO BE USED ONLY IN CONNECTION WITH WORK PERFORMED BY LUMMUS. REPRODUCTION IN WHOLE OR IN PART FOR ANY PURPOSE OTHER THAN WORK PERFORMED BY LUMMUS IS FORBIDDEN EXCEPT BY EXPRESS WRITTEN PERMISSION OF LUMMUS. IT IS TO BE SAFEGUARDED AGAINST BOTH DELIBERATE AND INADVERTENT DISCLOSURE TO ANY THIRD PARTY."

L

PROCESS FLOW DIAGRAM PYROLYSIS GASOLINE HYDROGENATION UNIT DEPENTANIZER

NOTE 2

M

1

PGH FIRST STAGE REACTOR EFFLUENT FROM V-28003

C6+ TO C-28002

C5's TO F-20002/F-20007

C5 RECYCLE TO THU

LP OFFGAS FROM V-28013

LP OFFGAS TO V-22001

DWG. 2800A

DWG. 2800D

DWG. 2000A

DWG. 2700A

DWG. 2800C

DWG. 2200A

2

3

4

5

6

7

8

9

L

10

11

12

M

DOC. No:

3

13

14

SCALE:

NONE

DWG. No:

15

REV:

A1-222334-2800B 16

0

1

2

3

5

4

6

7

8

9

10

11

12

13

14

15

A

16

A

1. TEMPERATURES & PRESSURES ARE SHOWN FOR CASE 1 OPERATION UNLESS OTHERWISE INDICATED.

B

B TC PRESULFIDING INJECTION FROM ME-12001

SP

FC PGH CORROSION INHIBITOR INJECTION FROM ME-28002

C

C kg/cm²g

TO WET FLARE

NORMAL OPERATION SOR EOR C kg/cm²g

PGH CORROSION INHIBITOR INJECTION FROM ME-28002

144 4.5

C CW

TO WET FLARE

HC

HC CW

TI

PC

PC

REGENERATION C 480 kg/cm²g 1.0

C kg/cm²g C kg/cm²g

E

45 4.0

E

MINIMUM FLOW BYPASS

FC LC

LC

COND.

F

MPS OWS

SP

REGENERATION

TO MP STEAM

REGENERATION

HS STEAM

C kg/cm²g

45 25.2

NORMAL OPERATION SOR EOR C kg/cm²g

F

161 4.7

D

NNF

D

G

G

FC FC

H A

LP OFFGAS TO SCU

HP OFFGAS TO V-22004

DWG. 2800B

DWG. 2200D

H

H2S

FC

J

J

M FC

SP

FC

NNF

K

ME-28002

REV

PGH CORROSION INHIBITOR INJECTION PACKAGE

REACTOR REDUCTION GAS FROM SCU DWG. 2200F

L

M

REACTOR REGEN/ HEATING/COOLING GAS TO R-28001A/B DWG. 2800A

REACTOR REGEN/ HEATING/COOLING GAS FROM SCU DWG. 2200F

DWG. 2800A

C6-C8 CUT FROM P-28005A/B

HYDROGEN FROM ME-23001

DWG. 2800D

2

3

4

DWG. 2800A

5

6

CAD

PROC LPE PDM ENG

CLIENT

PM

HYDROGEN RICH GAS FROM V-28003 DWG. 2800A

PGH SECOND STAGE REACTOR EFFLUENT TO C-28004

START-UP NAPHTHA FROM STORAGE

DWG. 2800D

DWG. 2800A

7

8

9

10

L

PROCESS FLOW DIAGRAM PYROLYSIS GASOLINE HYDROGENATION UNIT PGH SECOND STAGE REACTOR AND H2S STRIPPER M

DOC. No:

5

1

DESCRIPTION

"THIS DOCUMENT IS THE PROPERTY OF LUMMUS TECHNOLOGY INC. (LUMMUS). IT CONTAINS CONFIDENTIAL INFORMATION DESCRIBING TECHNOLOGY OWNED BY LUMMUS. IT IS TO BE USED ONLY IN CONNECTION WITH WORK PERFORMED BY LUMMUS. REPRODUCTION IN WHOLE OR IN PART FOR ANY PURPOSE OTHER THAN WORK PERFORMED BY LUMMUS IS FORBIDDEN EXCEPT BY EXPRESS WRITTEN PERMISSION OF LUMMUS. IT IS TO BE SAFEGUARDED AGAINST BOTH DELIBERATE AND INADVERTENT DISCLOSURE TO ANY THIRD PARTY."

DWG. 2100B REACTOR REGEN GAS FROM R-28001A/B

ISSUE DATE

RK

LUMMUS PETROCHEMICALS

KNOCK OUT LIQUID TO C-21003

REACTOR REGENERATION GAS EFFLUENT TO SCU DWG. 2200F

K

FEB 0 2017 FOR PROPOSAL

11

12

13

14

SCALE:

NONE

DWG. No:

15

REV:

A1-222334-2800C 16

0

1

2

3

5

4

6

7

8

9

10

11

12

13

14

15

16

A

A 1. TEMPERATURES & PRESSURES ARE SHOWN FOR CASE 1 OPERATION UNLESS OTHERWISE INDICATED.

NITROGEN

MPS

B

B PC

PC

C

C

CW C kg/cm²g

CW

D

72 -0.7

D

LP VENT C kg/cm²g

99 0.8

C kg/cm²g

90 0.5

HC

CW -11° C3R

C kg/cm²g

DWG. 2500B

42 -0.8

LC

E

FC

E

LC

FC

TC

F

F

TC LP VENT

SP FC

C kg/cm²g

LC

40 0.5

SP FC

LC

G MPS

LC

C kg/cm²g

157 -0.3

G DS MPS

MP COND. 150 1.4

MP COND. ON / OFF

C kg/cm²g

H

H

SP FC

M

J

FC

J SP

SP FC SP

K CW

FC

DILUENT TO ME-28003

NNF

K

FEB 0 2017 FOR PROPOSAL REV

ISSUE DATE

RK

DESCRIPTION

CAD

PROC LPE PDM ENG

CLIENT

PM

CW

ME-28003 PGH ANTIOXIDANT INJECTION PACKAGE

L

PGH ANTIOXIDANT INJECTION FROM ME-28003 C kg/cm²g

CW

C kg/cm²g

PGH ANTIOXIDANT INJECTION FROM ME-28003

42 4.0

C kg/cm²g BL

M

42 4.1

C kg/cm²g

BL

LUMMUS PETROCHEMICALS

40 3.5

PGH ANTIOXIDANT INJECTION FROM ME-28003

44 5.0

"THIS DOCUMENT IS THE PROPERTY OF LUMMUS TECHNOLOGY INC. (LUMMUS). IT CONTAINS CONFIDENTIAL INFORMATION DESCRIBING TECHNOLOGY OWNED BY LUMMUS. IT IS TO BE USED ONLY IN CONNECTION WITH WORK PERFORMED BY LUMMUS. REPRODUCTION IN WHOLE OR IN PART FOR ANY PURPOSE OTHER THAN WORK PERFORMED BY LUMMUS IS FORBIDDEN EXCEPT BY EXPRESS WRITTEN PERMISSION OF LUMMUS. IT IS TO BE SAFEGUARDED AGAINST BOTH DELIBERATE AND INADVERTENT DISCLOSURE TO ANY THIRD PARTY."

PROCESS FLOW DIAGRAM PYROLYSIS GASOLINE HYDROGENATION UNIT DEHEXANIZER AND BTX COLUMNS

BL

PGH SECOND STAGE REACTOR EFFLUENT FROM E-28012

C7-C8 PRODUCT TO STORAGE

C6 CUT TO STORAGE

C6 CUT TO BZEU

DWG. 2800C

OSBL

OSBL

(GTC)

EJECTOR CONDENSATE TO OSBL

C6 - C8 CUT TO E-28009

C6+ FROM C-28002

WASH OIL TO T-21002

C9+ CUT TO E-21004A/B

DWG. 2800C

DWG. 2800B

DWG. 2100A

DWG. 2100A

2

3

4

5

6

7

8

9

10

11

12

13

M

DOC. No:

7

1

L

14

SCALE:

NONE

DWG. No:

15

REV:

A1-222334-2800D 16

0

1

2

3

5

4

6

7

8

9

10

11

12

13

14

15

16

NOTES:

A

A

B

B HP FLARE FROM BZU

METHANOL

C

DESUPERHEATED LP STEAM

C

LP COND.

D

D

E

E

METHANOL

DESUPERHEATED LP STEAM

F

LP COND.

F

G

G

H

H

WET FLARE FROM C4 HYDRO & PGH

DRY FLARE FROM C4 HYDRO & PGH

J

J

COLD BLOWDOWN FROM C4 HYDRO & PGH

RO

RO

K

K

FEB 0 2017 FOR PROPOSAL REV

ISSUE DATE

RK

DESCRIPTION

CAD

PROC LPE PDM ENG

CLIENT

PM

LUMMUS PETROCHEMICALS "THIS DOCUMENT IS THE PROPERTY OF LUMMUS TECHNOLOGY INC. (LUMMUS). IT CONTAINS CONFIDENTIAL INFORMATION DESCRIBING TECHNOLOGY OWNED BY LUMMUS. IT IS TO BE USED ONLY IN CONNECTION WITH WORK PERFORMED BY LUMMUS. REPRODUCTION IN WHOLE OR IN PART FOR ANY PURPOSE OTHER THAN WORK PERFORMED BY LUMMUS IS FORBIDDEN EXCEPT BY EXPRESS WRITTEN PERMISSION OF LUMMUS. IT IS TO BE SAFEGUARDED AGAINST BOTH DELIBERATE AND INADVERTENT DISCLOSURE TO ANY THIRD PARTY."

L

PROCESS FLOW DIAGRAM STEAM CRACKER UNIT ISBL FLARE KNOCK OUT DRUMS

BL HP FLARE TO

WET FLARE HEADER

OSBL

M

C4 AND ROG DRAIN HEADER

LIQUID TO QUENCH TOWER C-21003

(LIQUID DRAIN)

DWG. 1001E

FUEL GAS SWEEP FROM FUEL GAS SYSTEM

COLD BLOWDOWN HEADER

DRY FLARE HEADER

(LIQUID DRAIN)

2

3

4

5

6

7

8

9

M

DOC. No:

3

1

10

11

12

13

L

14

SCALE:

NONE

DWG. No:

15

REV:

A1-222334-3100A

A1-222334-3100A

16

0

Last Revised: 2/7/2017 12:38 PM by rajkumar