contents auction qfpira0qbdqd qfpira0qjux8 !qfpira0q9k7htrgp process description

8/10/2019 Contents Auction Qfpira0qbdqd Qfpira0qjux8 !Qfpira0q9k7htrgp Process Description

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Table Rock Gas Plant Process Description

Table Rock Gas Plant utilizes an Inlet Gas System to bring gas from the sour field (Table Rock Unit) via

10 and 6 laterals. This gas is processed (water and liquid hydrocarbons removed by way of the

Ethylene Glycol and Refrigeration systems) and sweetened (Hydrogen Sulfide and Carbon Dioxideremoved by way of the Amine and Reflux Systems) so that the product gas will meet the pipeline quality

specifications outlined above.

Both the 10 and 6 field laterals can be pigged. Pigging is used to clean the pipelines, removing any

flow restrictions and purging the system of liquid pockets (thereby preventing the potential for slug

flow).

The pigs and any liquids contained in the laterals are pushed to the inlet piping system where the pigs

and process fluids can separate. The pigs are collected in the pig receiver for reuse as gas and liquids

continue to the Pig Trap Header (PV-002). Liquids drop from PV-002 to the Pig Traps (V-095 / V-095A)

where they will ultimately be drained to the Pig Liquids Holding Tank (V-122) via LV-140 for furtherprocessing. Should the need arise, the Pig Traps (V-095 / V-095A) and Pig Trap Header (PV-002) can be

isolated as an entire unit and completely bypassed through a 10 manual valve. However, when the Pig

trap is isolated, the 6 field lateral must be blocked in.

Sour gas exits the north end of the Pig Trap System (V-095 / V-095A / PV-002) and passes through the

Primary Inlet Separator (PV-001). PV-001 is a horizontal type separator that utilizes reduced gas

velocities and a 180 change in direction to remove entrained liquids. Liquids collected in the Primary

Inlet Separator are transferred to the Pig Liquids Holding Tank (V-122) via LV-159 for further processing.

The sour gas flows from PV-001, through the Inlet Block Valve (VO-101), to the Inlet Compression

Packages (K-901 and/or K-902 - reference the associated procedures for additional detail). Discharge

from the Inlet Compressor Packages flows to the Inlet Separator (V-123). V-123 is a vertical type

separator that utilizes reduced gas velocities and a 90 change in direction to remove any additional

liquids. Liquids collected in the Inlet Separator are dumped to the Pig Liquids Holding Tank (V-122) via

LV-102 for further processing.

From V-123, the gas continues on to the Inlet Filter / Separator (V-125). V-125 contains coalescing filters

which are used to remove additional liquids and filter the gas stream of particulate matter. Liquids that

are removed are dumped to the Pig Liquids Holding Tank (V-122) via LV-142 (West) and LV-141 (East) for

further processing. HCV-125, located at the outlet of the V-125, can used to isolate all of these

upstream systems from the Amine System; however, during normal operation, sour gas continues

through HCV-125 to the Amine Contactor (V-101)

These initial separation vessels are all used to prevent contamination of the amine system. Liquid

hydrocarbons or particulates, mixed with the amine solution, could cause foaming in the Amine

Contactor, ultimately resulting in amine losses due to carryover and reduced sweetening capacity.


2/19

Sour gas is introduced to the Amine Contactor (V-101) through a sparger near the bottom where the gas

is initially directed down toward an anti-swirl baffle (designed to prevent gas from channeling through

the tower). As gas flows up through the column, it will contact the liquid layer of amine solution held on

each bubble tray where a chemical reaction is used to remove H2S and CO2. The sweetened gas passes

through a demister (mist pad) at the top of V-101 to minimize amine solution losses.

Upon leaving the Amine Contactor, gas flows to the Amine Primary Residue Gas Scrubber (V-103) which

is a vertical separator that utilizes reduced gas velocities and a 90 change of direction in order to

remove any entrained liquids. Liquid is drained from V-103 to the Flash Tank (V-2) as the sweet gas

continues to the Off Gas Scrubber (V-124), followed by the Amine Contactor Residue Gas Scrubber (V-

105) which are both vertical separators utilizing reduced gas velocities and a 90 change in direction to

remove additional liquids. Liquids removed in V-124 drain back to V-103 while liquids removed in V-105

are returned to the Amine Drain Tank (V-816).

After exiting the Amine Contactor Residue Gas Scrubber, sweet gas flows through the tube side of the

upper Dew Point Exchanger (HE-105A). Ethylene Glycol is injected into the gas stream here to absorb

free water and prevent hydrate formation as gas is cross-exchanged with the cooler sales gas stream

(shell side). The cooled gas then goes through the tube side of the lower Dew Point Exchanger (HE-

105B). Additional Ethylene Glycol is injected into the gas stream to absorb free water and prevent

hydrate formation as gas is further cooled through cross exchange.

After these two stages of pre-cooling, the gas then flows to the tube side of the Gas Chiller (HE-106).

This kettle style heat exchanger is used to further cool the gas using liquid propane. Again, Ethylene

Glycol is injected into the gas flow to absorb any entrained water and prevent hydrate formation. The

function of this entire system is to lower the sales gas water dew point and increase the gass BTU

content to meet pipeline specifications.

The two-phase stream then passes to the Chiller Separator (V-116) where rich Ethylene Glycol and

hydrocarbon liquids are separated from the gas stream. Hydrocarbon liquids that are separated in V-

116 are transferred to the Stabilizer Feed Tank (V-121) via LV-129 while rich glycol flows back to the

glycol regeneration system (refer to associated procedure for additional details) via LV-130.

The chilled gas passes back to the shell side of the lower Dew Point Exchanger (HE-105B) and then the

upper Dew Point Exchanger (HE-105A), where it is warmed before leaving the processing area. These

two exchangers are used for heat conservation - recovering cold energy upstream of HE-106 while

reheating the chilled sales gas stream.

Sweet gas leaves the gas processing area via PV-127 (used to maintain a backpressure on the plant). Gas

then flows through the Outlet Block Valve (VO-102) and enters the CIG 12 lateral (113A-12"). This 12"

lateral ultimately ties into the main line north of Interstate 80.

Two analyzers are used to monitor the sales gas H2S concentration: AI-101A samples gas downstream

of the Dew Point Exchanger (HE-105A), while AI-101B (CIG Analyzer) samples sales gas downstream of

the Outlet Block Valve (VO-102).


3/19

Two analyzers are used to monitor the sales gas moisture content: MA-102 samples gas downstream of

the Dew Point Exchanger (HE-105A), while MA-102B (CIG Analyzer) samples sales gas downstream of

the Outlet Block Valve (VO-102).\

Sweet Fuel Gas Process Description

Table Rock Gas Plant utilizes a Main (Sweet) Fuel Gas System to supply the following users:

Main

H-310

SB-810A

SB-810B

Methanol Injection Pump

Startup / Shutdown

H-501

V-112

V-804

Pilot

H-108

H-310

H-501


4/19

Purge

F-4

HP Flare Header

K-901

K-902

LP Flare Header

V-121 & V-118A/B

Blanket Gas

T-101

T-103

V-1222

V-805

V-816

O.O.S.

HE-113

V-108

Stripping Gas

V-821

as well as the office building and maintenance shop / cold storage heaters.


5/19

During normal operation, a side stream from the sales gas header (taken immediately upstream of FI-

126) is used to maintain the HP Sweet Fuel Gas Header pressure by PIC-852A. In the event that this

source of fuel is insufficient (i.e. during startup), PIC-852 will provide sweet fuel gas from the buy-back

supply.

Note that the volume of sweet fuel gas used from sales gas is recorded by FI-885 while the volume of

sweet fuel gas used from buy-back is recorded by FI-175.

Fuel gas flows from the HP Sweet Fuel Gas Header to the Main Fuel Gas Scrubber (V-811). Given the

critical nature of this system, parallel self contained pressure regulators (PCV-852A / PCV-852B) are used

on the inlet side of V-811 to reduce the pressure and provide an uninterrupted source of fuel gas.

The Main Fuel Gas Scrubber is a vertical type separator that utilizes reduced gas velocities, a 90 change

in direction, and a mist pad to remove entrained liquids. Liquids collected in V-811 are dumped to the

Closed Gravity Drain Tank (V-820) via LV-845 for further processing.


6/19

Hydrocarbon liquids, produced water, Process Description

Hydrocarbon liquids, produced water, and other process fluids are collected from the sources indicated

by green shaded boxes in the below block flow diagram.

Pig Traps (V-95 / V-95A)

- LV-140

- LT / LG 140 Level Bridles (Manual)

Primary Inlet Separator (PV-001)

- LV-159

Inlet Compression (K-901)

Suction Scrubber (V-901)

- LV-901

- LIT-901 Level Bridle (Manual)

Interstage Suction Scrubber (V-903)- LV-903


Inlet Compression (K-902)

Suction Scrubber (V-902)

- LV-900


Interstage Suction Scrubber (V-904)

- LV-902


Pig Liquids Holding Tank (V-122)

Inlet Separator (V-123)

- LV-101 (Manual)

Amine Primary Residue Gas Scrubber (V-103)

- LV-109 (Manual)

Inlet Separator (V-123)

- LV-102

Inlet Filter Separator (V-125)- LV-142

- LV-141

Condensate Stabilizer Feed Tank (V-121)Chiller Separator (V-116)- LV-129

Dump Liquids Holding Tank (V-

815)

LV-143 (HC)

Amine Regenerator Reflux Accumulator (V-822)

- P-106A / B (Manual)

Chiller Separator (V-116)

- Manual

Chiller (HE-106)

- Manual (Shell Side from RP13-PO-1")

Glycol Flash Tank #1 (V-830)

-LV-836

Glycol Flash Tank #2 (V-804)- LV-812 (Manual)

Refrigerant Compressor Suction Scrubber (V-801)

- Manual

Refrigerant Receiver (V-802)

- Manual

North Amine Storage Tank (T-101)

- P-104 (Manual from 3"-LA-A1-11A01-S.R.)

Acid Gas Knockout Drum #1 (V-501)

- P-502A / B (Manual)

Amine Drain Tank (V-816)

- P-811 (Manual / Reconfiguration)

Inlet Filter Separator (V-125)

- Manual (West Liquid Boot)

- Manual (East Liquid Boot)

- LT-142 Level Bridle (Manual)

- LG-192 Level Bridle (Manual)

- LG-193 Level Bridle (Manual)

- LC-141 Level Bridle (Manual

Inlet Separator (V-123)- Manual

Amine Primary Residue Gas Scrubber (V-103)

- LV-110 (Manual / Reconfiguration)

Dump Liquids Holding Tank Booster Pump (P-819)

- Seal Flush

Sour Water Pumps (P-820A / B)

- Seal Flush

Flare Separator (V-814)

- P-808A / B via LIC-851

NNF / Reconfiguration

LV-134 (H2O)

Dump Liquids Holding Tank Booster Pump (P-819)

Dump Liquids Holding Tank Pump (P-810)

FV-138

NNF / Reconfiguratoin

Condensate Product Storage Tanks (V-118A / B)

Manual

Rich Glycol Trim Heater (HE-809)

Sour Water Handling System

Glycol Regenerator (V-806)

-Vent Line

Closed Gravity Drain Tank (V-820)

- P-809 (Manual)

LV-144 (H2O)

RERUN

Condensate Product Loading Pump (P-108) Sales

The primary sources of sour liquid production are initially routed to Pig Liquids Holding Tank (V-122) for

processing. This three phase separator utilizes a weir, residence time, and a steam heating coil

(regulated by TV-121) to improve hydrocarbon / water separation. The resulting sour hydrocarbon

phase is routed through LV-143 to the Condensate Stabilizer Feed Tank (V-121) while sour water flows

through LV-144 to Dump Liquids Holding Tank (V-815).


7/19

In Condensate Stabilizer Feed Tank (V-121), sour hydrocarbons from V-122 are combined with sweet

hydrocarbon liquid recovered in Chiller Separator (V-116). This particular vessel includes two liquid

boots separated by a weir, the first of which recovers entrained ethylene glycol from V-116 while the

second is used to remove any remaining sour water. Recovered ethylene glycol is manually drained (as

needed) back to the glycol system while sour water flows through LV-134 to Dump Liquids Holding Tank

(V-815). The purified liquid hydrocarbon phase flows from V-121, through FV-138, to Condensate

Product Storage Tanks (V-118A / B) where it will ultimately be pumped (as needed) by Condensate

Product Loading Pump (P-108) to tanker trucks for sale.

Sour water streams from V-122 and V-121 are combined with other, secondary sources of sour liquid in

Dump Liquids Holding Tank (V-815). V-815 utilizes a weir and residence time to separate the two liquid

phases. The resulting water phase is pumped via Sour Water Pumps (P-820A / B) to the Sour Water

System for further processing while recovered hydrocarbons are recycled to Pig Liquids Holding Tank (V-

122).

Note that in the event a significant amount of water is found in Condensate Product Storage Tanks (V-

118A / B), a rerun line couldbe utilized to further process the sour liquids.

Closed Gravity Drain System Process Description

(Out of service, BG tank V820 was removed 2012)

The Table Rock Gas Plant utilizes a Closed Gravity Drain System to collect liquids from the systems listed

below:

Vessels

V-501 (Acid Gas Knockout Drum #1) - LV-501

V-811 (Sweet Fuel Gas Scrubber) - LV-845

V-819 (Sour Fuel Gas Scrubber) - LV-847

V-121 (Condensate Stabilizer Feed Tank)

Level Bridles

V-123 (Inlet Separator)

V-125 (Inlet Filter Separator)

V-821 (Sour Water Stripper)

V-815 (Dump Liquids Holding Tank)


8/19

Pumps (Manual Drains)

P-819 (Dump Liquids Holding Tank Booster Pump)

P-820A / B (Sour Water Pumps)

P-106A / B (Amine Regenerator Reflux Pumps) Discharge

Other

AIX-100 (Gas Chromatograph)

Liquids drained from these systems are collected in the Closed Gravity Drain Tank (V-820). Accumulated

liquid is then pumped to the Dump Liquids Holding Tank (V-815) via the Closed Gravity Drain Tank Pump

(P-809).

Overhead product from the Amine Regenerator (V-112)

The overall function of this system is to condense / recover water while at the same time providing a

reflux stream for the Amine Regenerator.

Overhead product from the Amine Regenerator (V-112), which consists primarily of acid gas (H2S / CO2)

and water vapor, flows from V-112 to the Amine Regenerator Reflux Condensers (AC-102A - D). Here

the stream is cooled with forced draft air coolers, utilizing a variable volume of air flow to control the

outlet process temperature. Air flow is controlled in a number of ways including roll-up doors, louvers,

two-speed fan motors (4), and VFD fan motors (2).

This two-phase stream flows to the Amine Regenerator Reflux Accumulator (V-822) where thecondensed water and entrained amine can be separated from the acid gas stream. Refer to the Acid Gas

procedure for additional information regarding the acid gas process description.

The Amine Regenerator Reflux Pumps (P-106A / B) are then used to maintain a liquid level in V-822

while providing a consistent flow of liquid reflux (sour water and amine) to the Amine Regenerator via

FV-116-1. Note that these pumps are protected by a continuously operated minimum flow recycle to

the Amine Regenerator Reflux Accumulator. All of the reflux pumped via P-106A / B will be filtered at

the Amine Regenerator Reflux Filters (F-803A / B) in order to remove any particulates, effectively

minimizing the potential for foaming within the Amine Regenerator.

The liquid reflux stream is reintroduced to the Amine Regenerator above the top bubble tray. The top

section (3 tray enriching section above the Rich Amine feed point) of the Amine Regenerator utilizes this

reflux stream to improve the overhead product quality (i.e. minimize amine and water vapor carryover).

SRU Process Description


9/19

Gas containing high concentrations of H2S and CO2 (acid gas) originates from the Reflux System and is

ultimately processed by one of the following three systems : The Acid Gas System is relatively simple,

consisting entirely of two-phase separation and a header system that is used to deliver the stream to

these end users.

System Product

Sulfur Recovery Unit Sx

Tail Gas Incinerator System ABS

ATS System ATS

All acid gas flows directly from Amine Regenerator Reflux Accumulator (V-822) to Acid Gas Knockout

Drum #1 (V-501). V-501 is a vertical type separator that utilizes reduced gas velocities and a 90 change

in direction to remove any entrained liquids (i.e. sour water carryover from the Reflux System). Liquids

collected in V-501 are normally dumped to the Closed Gravity Drain System through LV-501 for further

processing. Alternatively, liquids could be pumped to the Hydrocarbon Handling System via Acid Gas

Knockout Drum Pumps (P-502A / B).

Water saturated acid gas flows through a demister pad (mesh pad) at the top of V-501 to minimize

liquid entrainment before being distributed to one of the three systems outlined above. Note that only

the acid gas routed to the Sulfur Recovery Unit flows through the second two-phase separator (Acid Gas

Knockout Drum #2 - V-507). Any liquids collected in V-507 gravity drain back to Acid Gas Knockout Drum

#1 (V-501).

Note that these two separators, which are located downstream of Amine Regenerator Reflux

Accumulator (V-822), are used purely as additional safeguards to protect the downstream fired

equipment.

Excess acid gas production, as observed by an increased pressure at PIC-124-1, is routed to the LP Flare

System through PV-124-1. To ensure complete combustion of the acid gas, RIC-132 automatically adds

sweet fuel to the LP Flare System by controlling FV-852 at 1.5x the gas flow rate through PV-124-1. In

addition, the Flare Stack Blower (H-801.2) automatically shuts down as FIC-130 registers flow through

PV-124-1.

High Pressure (HP) Flare Process Description


10/19

The Table Rock Gas Plant utilizes a High Pressure (HP) Flare Header to contain vapors / liquids vented

from the systems listed below:

Plant Blowdown through HV-127 and / or Manual Blowdown of

o Trunk Lines (6 and / or 10)

o Pig Receivers (8 and / or 12)

o Pig Traps (V-095 / 095A)

Inlet Compression Flare Header

Manual Blowdown Downstream of PV-104

PSV-95 / PSV-97 TRGP-0-1-08A

PSV-133 TRGP-0-1-08B

PSV-142 TRGP-0-1-08C

PSV-101 TRGP-0-1-08C

PV-102 / 102A TRGP-0-1-08C

PSV-143 TRGP-0-1-09

PSV-144 TRGP-0-1-09

PSV-141 TRGP-0-1-09

PV-127A TRGP-0-1-09

PSV-107 TRGP-0-1-09A

ROV-111 TRGP-0-1-09A

PSV-122 TRGP-0-1-12

PSV-125 TRGP-0-1-13

PSV-801 TRGP-0-1-18

PSV-802 TRGP-0-1-18

PSV-805 TRGP-0-1-18

PSV-155 TRGP-0-1-47


11/19

PSV-150 TRGP-0-1-47

Note: All of these sources relieve to the HP Flare Header at >100 psig.

Vented vapors / liquids flow through the HP Flare Header to the Flare Separator (V-814). V-814 utilizes

decreased gas velocities and flow redirection to remove entrained liquids from the gas and relies on a

steam coil to maintain a minimum liquids temperature. The liquids are ultimately pumped back to the

Dump Liquids Holding Tank (V-815) via the Flare Separator Liquids Pumps (P-808A / B) for further

processing.

Vapors from the HP Flare Header combine with vapors from the High Pressure Flare Header in the Flare

Separator before being routed to the Flare Stack (H-801). These vapors are combined with combustion

air (supplied by Flare Stack Blower H-801.2) in the mixing chamber (located at the top of H-801) before

being burned. Burning these vapors minimizes the probability of releasing toxic vapors and / or a

flammable vapor cloud to the atmosphere.

Note that the HP Flare Header also includes a constant sweet fuel gas purge to prevent oxygen ingress,dead legs, and / or flame reversal.

Low Pressure (LP) Flare Process Description

The Table Rock Gas Plant utilizes a Low Pressure (LP) Flare Header to contain vapors / liquids vented

from the systems listed below:

Inlet Compression Sour Waste Oil Pump (WP-901 / 902)

Inlet Compression Scrubber Drain Header

Sales Gas H2S Analyzer (AIX-101A)

Closed Gravity Drain Tank (V-820) and Dump Liquids Holding Tank (V-820) Vent

PSV-105 TRGP-0-1-11A

PSV-120 TRGP-0-1-11B

PV-124-1 TRGP-0-1-11B

PSV-814 TRGP-0-1-19

PSV-830 TRGP-0-1-19

PSV-853 TRGP-0-1-26

PSV-854 TRGP-0-1-26


12/19

PV-853 TRGP-0-1-26

PSV-113 TRGP-0-1-30B sht1

PCV-817 TRGP-0-1-30B sht1

Note: All of these sources relieve to the LP Flare Header at 100 psig .

Vented vapors / liquids flow through the LP Flare Header to the Flare Separator (V-814). V-814 utilizes

decreased gas velocities and flow redirection to remove entrained liquids from the gas and relies on a

steam coil to maintain a minimum liquids temperature. The liquids are ultimately pumped back to the

Dump Liquids Holding Tank (V-815) via the Flare Separator Liquids Pumps (P-808A / B) for further

processing.

Vapors from the LP Flare Header combine with vapors from the High Pressure Flare Header in the Flare

Separator before being routed to the Flare Stack (H-801). These vapors are combined with combustion

air (supplied by Flare Stack Blower H-801.2) in the mixing chamber (located at the top of H-801) before

being burned. Burning these vapors minimizes the probability of releasing toxic vapors and / or a

flammable vapor cloud to the atmosphere.

Note that the LP Flare Header also includes a constant sweet fuel gas purge to prevent oxygen ingress,

dead legs, and / or flame reversal.

Sour Water System Process Description

The Table Rock Gas Plant utilizes a Sour Water System to sweeten produced water prior to reinjection.

Produced water, recovered throughout the gas treating and processing areas of the plant, is collected inthe Dump Liquids Holding Tank (V-815) - refer to the Hydrocarbon Handling System procedure for

additional detail. Water collected in V-815 is pumped to the Sour Water Stripper (V-821) through FV-

847 by Sour Water Pumps (P-820A / B). Note that the flow controller associated with this valve (FIC-

847) receives a remote set point from the Dump Liquids Holding Tank (V-815) interface level controller

(LIC-858).

The sour water is then introduced V-821 through a distributor nozzle located above twelve (12) bubble

trays. At the same time, sweet fuel gas is added to the bottom of V-821 through FV-848 at a ratio set to

achieve optimum sweetening. These two streams flow counter-currently through the stripper column

(i.e. water flows down the column and across each tray while sweet fuel gas flows up through theassociated bubble caps), ensuring the maximum possible contact time and greatest potential for

efficient H2S removal.

As the sweet fuel gas flows up through V-821, H2S will be stripped from the water phase. The gas (now

sour) then exits V-821 through a mist pad which is designed to remove entrained water. There, PIC-876

(designed to maintain a maximum backpressure on V-821) controls the flow of sour gas to the Sour Fuel

Gas Scrubber (V-819).


13/19

Water flows from the Sour Water Stripper (V-819) through LV-860 to the Open Drain Tank (V-823)

before ultimately being pumped to the Salt Water Disposal Plant for reinjection.

Process Open Drain System Process DescriptionThe Process Open Drain System is utilized to collect non-hazardous liquids (primarily water) as depicted

below


14/19

Drains at

STB-101A

STB-101B

PSV-807 Outlet

PSV-808 Outlet

Process Building Floor

Drains

Groundwater

Reclamation

(By Others)

Drains at

P-801A

P-801B

Process

Area Seal

Pot

V-823(Open Drain

Tank)

V-821

Locker

Room / Tech

Shop Sump

Maintenance

Shop Sump

Utility Area

Seal PotV-817

Drains at

P-807A

P-807B

Trench Drain Collecting

T-801 Overflow

T-802 Overflow

V-840 Overflow

PSV-849

Steam System Sample Station

CA-805A

CA-805B

V-812

V-813

Utility Building Floor Drains

Cable Vault

W-801 Vent

PV-841-1APV-841-1B

The Process Area Seal Pot (located north of the Process Building near the Dew Point Exchangers) and

Utility Area Seal Pot (located between the Process and Utility Buildings) provide an unobstructed path to

atmosphere, thereby preventing the potential to overpressure any component within the Open Drain

System. For the same reason, a 4 vent to atmosphere is located on Open Drain Tank (V-823). Note

that a containment sump is located west of V-823 to provide secondary containment should the vessel

overfill.


15/19

Liquids collected in Open Drain Tank (V-823) are ultimately pumped via Open Drain Tank Pump (P-817)

to the Salt Water Disposal Plant for reinjection.


16/19


17/19


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