1. ADCO - Bab Far North Field
CO2 Injection Pilot Project
Date: 5th
May 2015
Syed Ajmal Haider
Sr. Process Engineer

2.  Project Objectives
 Background Concept
 Project Overview/Scope
 Process Design Basis
 Process Description
 Operating and Control Philosophy
 Startup Philosophy
 WAG Change Over Philosophy
 Venting, Relief and Depressurizing
Philosophy
Presentation Outlines
 Pigging Philosophy
 Interfaces With NEB
 Tie-ins at RDS-8

3. Project Objective
 Collecting the necessary technical data to assess CO2
injection effectiveness for enhanced oil recovery from
TH ’B’ which will be used to carry out feasibility study of
a full scale CO2 EOR development in BAB.
 To reduce the CO2 emission in the environment.

4. 1. Mechanism to Reduce the CO2 Emission
to Environment
Carbon dioxide (CO2) capture and sequestration (CCS) is a
set of technologies that can greatly reduce CO2 emissions
from power plants and large industrial sources. CCS is a
three-step process that includes:
Capture of CO2 from power plants or industrial processes
Transport of the captured and compressed CO2 (usually
in pipelines).
Underground injection and geologic sequestration (also
referred to as storage) of the CO2 into deep underground
rock formations.
Background Concept

5. 2. Oil Recovery Methods
 Recovery is the heart of oil production from underground
reservoirs.
 The amount of oil produced worldwide is only one third of
the total oil available according to the Department of Energy
U.S.A.
 Using EOR techniques, we will be able to produce more oil
as the demand increases while we have a shortage in the
supply.

6. 1. Oil Recovery Methods

7. Enhanced Oil Recovery (EOR) – CO2 Injection
 EOR processes attempt to recover oil beyond
secondary methods (30 - 50 %) up to 80%
 Tertiary recovery or EOR targets immobile oil (that oil
which cannot be produced due to capillary and viscous
forces).
 Enhanced Oil Recovery (EOR) - CO2 Injection method
provides additional benefit of Carbon Capture and
sequestration (CCS) to reduce CO2 emissions as well

9. 1. CO2 Injection Facility
 Maximum Capacity of CO2 Pipeline is 41.5 MMSCFD
 Maximum CO2 injection capacity of each of the Injection Well
is 10. 375 MMSCFD
 Maximum water injection capacity of each of the Injection
Well is 6000 BWPD
Project Design Basis
1.1. Pipeline Design Capacity
CO2 Pilot injection Facility provided for following two flanks
 North Flank
 East Flank

10. 1.2. Fluid Composition
Components Units Value
CO2 Mole % More than 98 %
H2 Mole % Less than 0.25
CO Mole % Less than 0.18
CH4 / HC Mole % Less than 0.10
N2 Mole % Less than 0.05
H2O lb/MMSCF 40 (Nor) / 80 (Max)
H2S ppmv Less than 400

11. Process System Description
1. CO2 Supply and Injection System
 Dense phase CO2 supplied from MASDAR to Rumaitha at 210-235
barg.
 CO2 supplied to Bab either from suction (210-235 barg) or from
discharge (265 barg) of the Rumaitha booster pumps and enters the
CO2 pipeline via pig launching facility
 Online moisture analyser with high alarm and CO2 leakage
detectors provided on CO2 pipeline to BAB
 BVS-1 /BVS-2 provided at ~24 km and ~48 km for sectionalizing of
CO2 pipeline.
 CO2 injection heaters are provided at each flank to keep CO2
injection temperature above 38°C during winter.
Process description of the major facilities provided as
follows:

12. 2. Hydrocarbon Gas For Start-up/CO2 Displacement
 Hydrocarbon lift gas used for initial pressurization of 70 Km CO2
pipeline
 Hydrocarbon gas is available at high pressure of 408 barg which is
let-down to the requirement when passes through pressure reduction
station at BAB Launcher area in Rumaitha
 A dedicated Start-up Electrical heater provided to heat up the
hydrocarbon lift gas to maintain 80 °C to protect CO2 pipeline against
low temperature exposure during start-up operation ( to avoid pipeline
fracture/cracking).
 Hydrocarbon lift gas also used for displacement of CO2 from the
pipeline in case of CO2 pipeline maintenance required.

13. 3. Water Injection System
 Both CO2 injection pilot flanks will be switched alternatively to water
injection cycle every 6 months. Injection water taken from existing
water injection cluster (Cluster 30 and 31).
 WIC-31 shall supply injection water to North Flank and WIC-30 shall
supply injection water to East Flank
 Water Injection Pressure downstream of well head choke will be
approximately 138 barg.
 During CO2 injection cycle, the brackish water in injection pipeline
will be drained in a pit and pipeline will be flushed twice with sweet
water to preserve the water pipeline.
 Inhibited water will be filled in water pipeline dosed with Combo
chemical (Oxygen scavenger/biocide).

14. 4. Oil Producer System
 There is one dedicated oil producer well at each injection flank to
produce and to monitor the performance of CO2 injection
effectiveness
 Two separate flow lines from both oil producer well connected to
RDS8 and buried underground.
 Both flowlines are provided with a provision of mobile pigging facility
( Pig Launcher and Pig Receiver) for cleaning and inspection purpose.
 A dedicated MPFM and Manifold provided

15. 5. Chemical Injection Systems Provided
 Mobile Methanol Injection System – Common for both flanks at CO2
Injection wells
 Oxygen Scavenger / Biocide Injection system – one at each flanks for
Water Injection Pipeline
 Asphaltene / Corrosion inhibitor Injection system – one at each
Producer well
 Antiscalant (scale inhibitor) Injection System – one at each Producer
well
6. Utility Systems
 Two CO2 Vent Stacks for BVS-1 and BVS-2 each
 Nitrogen Package (Purging & Pressurization)
 Mobile Flare Package - Common for both BVSs

16. CO2 Pipeline Route

17. Operating and Control Philosophy
1. CO2 Pipeline– Operating Philosophy
 The intention is to operate CO2 Pipeline facility in a safe and
efficient manner.
 The CO2 Pipeline will be remotely operated facility by ADCO
operations in BAB CDS / RDS-8 Control Room.
 Functionally, the CO2 pipeline network & Well injection system is
similar to the gas injection network.
 The main process parameters to be monitored are pressure,
temperature and moisture content in the CO2 pipeline.
1.1. General

18. Phase Behaviour of Pure CO2
 The triple point is 5 Bara, -56.7 °C.
 The critical point is 72 bar a, 31.1 °C.

19. Phase Behaviour of CO2

20. Phase Behaviour of CO2
 Cryogenic nature of CO2 due to its highly negative Joule-Thompson coefficient
 Requires careful consideration in the design of CO2 pipeline related to
depressurization from high pressure to low pressure and also during start-up of
CO2 pipeline whereby high differential pressure across the valve exist.
 During both operations (depressurization and start-up which are independent
activities), low temperature is experienced by pipeline due to Joule-Thompson
effect.
 Furthermore, while depressurizing, the triple point of CO2 could be reached,
resulting in the formation of solid CO2 (dry ice).
 Disposal of the CO2 stream into the atmosphere, especially when it contains
H2S is a health issue with the potential for personnel injury and CO2 emission
limits.
 The CO2 pipeline depressurising (blow down) should consider the associated
health issues as the Bab Far North Injection gas stream contains up to 400 ppm
H2S.

21. 1.2. Mode Of Operation
CO2 pipeline is designed to handle the following conditions/
scenarios
SCENARIO DESCRIPTION
SCENARIO-1
Max. Operating capacity as 41.5 MMSCFD. It occurs
when all Rumaitha injectors are down & flow diverted to
BAB CO2 pilot Injection project
SCENARIO-2
Operating capacity as 32 MMSCFD. It occurs when some
of Rumaitha injectors are down and flow diverted to BAB
CO2 pilot injection project
SCENARIO-3
Operating capacity as 16 MMSCFD. This scenario is
normal case and it occurs when both BAB CO2 flanks and
Rumaitha injectors are working.
SCENARIO-4
Operating capacity as 8 MMSCFD. This scenario occurs
when only one of the BAB injector is working and all the
Rumaitha injectors are working on CO2 injection mode.

22. 1.3. WAG Change Over
 The WAG or Water-Alternate- CO2 technique is a combination of
two traditional improved hydrocarbon recovery techniques;
water flooding and CO2 injection.
 Main advantages of the WAG process include higher CO2
utilization, reduced CO2 production and greater ultimate
recovery of oil
 The WAG injection well will have water and gas injection
alternatively with changeover occurring every 6 months.
 The changeover from one to the other will be manual operation
and will take place close to the wellhead.
 Methanol injection is required during change over from CO2
injection to water injection for 1 hour or as the need arises to
avoid hydrate formation.

23.  During CO2 Injection cycle in either North Flank/East Flank, water
inside pipeline/piping shall be preserved by draining the brackish
water to drain pit to avoid corrosion.
 Once draining operation is completed then the pipeline/piping will
be flushed with sweet water using sweet water tanker pump.
 Oxygen Scavenger/Biocide is to be injected at the discharge side
of sweet water tanker pump
 Sweet water will be supplied by tanker and is to be brought to the
each flank before start of water preservation operation.
 A dedicated Oxygen Scavenger/Biocide injection package at the
each flank is provided to inject the chemical during water
preservation operation.
 The inhibited water will be filled in water pipeline after dosing with
Combo chemical (Oxygen scavenger/biocide) to avoid corrosion.
1.4. Water Preservation System

24.  The CO2 flow to CO2 Pipeline is controlled by FCV at the
discharge of Booster pumps at Rumaitha during all modes of
operation.
 The Gas lift Pressure from Rumaitha is reduced via Pressure
Reduction Station during start-up and required gas lift
temperature is maintained by start-up electrical Heater.
 At each flank, The dense phase CO2 temperature is maintained
by respective CO2 injection heaters and CO2 injection rate is
regulated by choke valves at each injection well
 During water injection cycle, Water flow from the cluster 30/31
will be controlled by respective control valves at water injection
piping of the injector well.
2. CO2 Pipeline – Control Philosophy

25. Start up Philosophy
1. CO2 Pipeline Start up Philosophy:
The following systems/activities are need to be completed before
commencement of start-up operations:
Fire Protection System is commissioned and started.
CO2 Injection pipeline is completely air free and purged with N2.
Adequate pressure is available in Water injection header/pipeline
The start-up of CO2 pipeline is based on the following scenarios:
Initial Start-up : Start-up for the first time after the mechanical
completion and pre-commissioning/commissioning checks)
Pipeline Start-up in Pressurized Condition after a short shutdown
Start-up after shutdown of pipeline on ESD
Start-up after a major work-over or maintenance

26. Start up Philosophy

27. 1.1. Initial Start-up
The sequence of activity will be as follows:
Start-up electric heater and associated piping is under positive
pressure at say 20 barg with nitrogen.
Open the bypass around the battery limit valve of the HC source gas
(HC gas @ 408 barg at B/L) and line-up Start-up Electrical Heater.
Heat the HC lift gas to 80 °C and start pressurizing the piping/pipeline
section up to manual isolation valve to 90 barg.
After pressurization of piping section up to manual isolation valve start
pressurization of CO2 pipeline by opening of pressurization globe valve
to 90 barg and open pipeline shutdown valve (SDV).
The HC gas starts filling the pipeline up to 90 barg. The nitrogen will be
vented at the well end by opening the vent valves.
The pressure starts building up in the pipeline.

28. 1.1. Initial Start-up
 Continue till the pressure reaches about 90 bar inside the CO2
pipeline, close the HC gas battery limit isolation valve and stop the HC
gas supply. Close the isolation valves on HC gas supply line,
downstream of HIPPS.
 The pipeline is now ready for introduction of CO2.
 The HC gas will be displaced and pushed into the reservoir by CO2.
 Start the CO2 booster pumps in recycle mode.
 Open the battery limit isolation valve slowly for CO2 supply.
 The pipeline hydrocarbon gas will start getting displaced pushed by
incoming CO2.
 As the pressure in the pipeline reaches a value of about 200 bar (as
read from the pressure indicators at well head end), open the choke
valve manually and route the HC gas into the well.

29. 1.2. Pipeline Start-up in Pressurized Condition after a
short shutdown
During short duration shutdown initiated by operator intervention, the
pipeline will be boxed-up under normal operating pressure. As the CO2
is available at the requisite pressure and the pipeline is pressurized, the
operation can be started by opening the battery limit valve. It should be
ensured that all the block valves downstream of the line are in open
position. Finally open the choke valve to line up the CO2 injection.
1.3. Start-up after shutdown of pipeline on ESD
Scenario-1: In case pipeline is shutdown due to any ESD activation,
and the shutdown is for a short duration and the pipeline is isolated
with the CO2 boxed-up in the pipeline. The philosophy for start-up in
this condition will then be similar to the one described under
scenario 1.2 above.

30. 1.3. Start-up after shutdown of pipeline on ESD
Scenario-2: If a prolonged shutdown is envisaged and it is required to
evacuate the CO2 from the pipeline through HC displacement, the
CO2 pipeline will be pressurized with nitrogen to 1 - 2 barg and start-
up of CO2 pipeline will be initiated following same procedure
described under scenario 1.1 above.
1.4. Start-up after a major work-over or maintenance
This Scenario occurs when the pipeline start-up follows after
maintenance on a section of CO2 pipeline. This Scenario considers
pipeline sectionalizing for carrying out some major work over or
maintenance on a section of CO2 pipeline post CO2 displacement with
HC gas while maintaining the other pipeline sections in pressurized
condition with HC gas. The HC gas from CO2 pipeline section requiring
maintenance is vented and flared using Mobile Flare Package.

31. WAG Change Over Philosophy
 The WAG injection well will be injected water and gas alternatively with
switchovers occurring every 6 months. The changeover from one to the
other will be a manual operation and will take place close to the
wellhead with the help of positive isolation as shown in below
schematic.
 When switching from CO2 injection to water injection, the well tubing
need to be depressurized from 200 barg pressure at 38 C or well settle
out pressure to 138 barg pressure at 32.7 C which is the required water
injection pressure. The well tubing will be depressurized using vent
line as shown in Schematic. Prior to depressurization of well tubing,
the line which is marked with green and orange colours need to be
pressurized with nitrogen up to 90 barg to provide a back pressure for
CO2 in order to prevent solid CO2 formation as well as avoid exposing
the piping to low temperature.

32. WAG Change Over Schematic

33. 1.1- Switching from CO2 Injection to Water Injection
 Isolate the CO2 supply from the CO2 Pipeline by closing wellhead
injector battery limit double isolation valves and SDVs.
 Isolate the CO2 supply from Flowline to the wellhead by closing
isolation valves downstream of CO2 injector choke and closing Wing
valve on wellhead.
 Maintain CO2 under pressure in the CO2 pipeline in boxed up
condition during water injection cycle.
 Check and ensure that water supply is isolated on water line at
wellhead injector battery limit isolation valve.
 Depressurize and purge the Flowline section marked in green in the
Schematic shown in section 5.0.

34. 1.1- Switching from CO2 Injection to Water Injection
 Pressurize Flow line section portion marked in green in the
Schematic shown in section 5.0 with nitrogen up to 90 bar.
 Open Wing valve, Master valve and SSSV.
 Depressurize the well tubing using vent line marked in Orange color
in the Schematic and closely monitor temperature and pressure.
When the pressure reaches to 138 bar stop depressurization by
closing Wing valve and Master valve.
 Depressurize and purge with nitrogen the Flow line section portion
marked in green in the Schematic to ensure entire CO2 is vented.
 Switch the swing elbow and removal spool piece removal spool
from CO2 supply to water supply line. Install blind flanges on both
ends of the CO2 Flow line at the location where the swing elbow and
spool piece spool is removed.

35.  Override PTs High/low pressure signals to operate the injection
Wing valve and Master Valve.
 Make sure that mobile methanol injection package is ready to inject
methanol.
 Check that the injection water is available at the double isolation
near injector wellhead. Vent any gas pocket in the water injection
wellhead piping upstream of battery isolation valves.
 Start Mobile Methanol injection package for injecting methanol to
water piping.
 Slowly bring water flow up to the required value.
1.1- Switching from CO2 Injection to Water Injection

36. 1.2- Switching from Water Injection to CO2 Injection
 Isolate the water supply to the injector wellhead by closing the wing
valve and the isolation valve at wellhead.
 Close the isolation valve located near to the wellhead to that isolates
well piping from the water injection Flowline.
 Drain the entrapped water inventory between wellhead Wing Valve and
isolation valve located near to the wellhead through low point drain
valve.
 Ensure that the double block and bleed (DBB) valve on water side near
to wellhead fence area are in closed position. Drain the wellhead water
piping.

37.  Remove the drop out spool piece and swing elbow spool out
connection from the water supply line. Install blind flanges on both
ends of the water supply line from where spool piece and swing elbow
spool is removed.
 Ensure that choke valve on CO2 injector flow line and isolation valves
downstream of choke on CO2 flow line are in CLOSED Position.
 Ensure pressure transmitters are in “Override PTs” mode on the flow
line.
 Connect swing elbow and spool piece from water line to CO2 injector
flow line. While connecting the swing elbow and spool piece, keep
bleed valve open which is located on the CO2 injection line to release
any trap-in pressure in between the double block valve. Install the
same removable spool piece from water line to CO2 injector flowline.
1.2- Switching from Water Injection to CO2 Injection

38.  After switching of the swing elbow removable spool piece from
water supply to CO2 supply, the CO2 flow line shall be checked for
any leaks by nitrogen pressurization.
 After leak checking, pressurize the line by nitrogen to 90 barg.
 High/Low pressure override signals should be changed to
“NORMAL”.
 Open the choke valve on CO2 injector flowline and allow dense
phase CO2 to displace water in well string. Slowly increase flow rate
until desired value is reached.
 During CO2 injection cycle dormant water pipeline/piping are to be
preserved with sweet water injected with Oxygen
Scavenger/Biocide.
1.2- Switching from Water Injection to CO2 Injection

39. Pigging Philosophy
1. In-Service Cleaning
 On the completion of construction phase of the project, pipeline may
accumulate with water, corrosion products (rust scale) and other
deposits which must be cleaned out to maintain efficiency of
operation. Therefore, pigging of CO2 pipeline with cleaning type pig
will be done initially.
 However, during normal operation, dehydrated CO2 (near bone dry
condition) will flow through pipeline and water accumulation is not
anticipated. Therefore, in service pigging is not required for this
case.

40. Pigging Philosophy
2. Intelligent Pigging
 The recommended inspection pigging frequency based on industry
experience is one run during the line commissioning, then after the
first year of operation as a baseline and thereafter every 3 to 5 years,
depending on initial results and subsequent integrity assessments.
 The following mediums will be utilized for intelligent pigging:
 Water
 HC lift gas
 CO2

41. Pigging Philosophy
2.1 First Intelligent Pigging
The intelligent pigging will be carried out initially with water to collect
base-line data after completion of hydro-testing and pipeline cleaning
before CO2 introduction in pipeline at minimum operating pressure which
will be confirmed by pipeline inspection vendors. All necessary
arrangements will be ensured to dry and preserve the CO2 pipeline
completely when water is used as a motive fluid for intelligent pigging.
2.2 Subsequent Intelligent Pigging
During subsequent intelligent pigging after 3 – 5 year time for integrity
assessments, same service fluid (CO2) will be used as a motive fluid for
the pigging operation at the CO2 pipeline operating pressure and pigging
inventory will be routed to CO2 injection wells.

42. Pigging Philosophy
 During any major maintenance activity of CO2 pipeline, the CO2
will be displaced into the injection well at CO2 pipeline
operating pressure using HC Lift Gas and a separation pig will
be used between CO2 and HC gas. Separation pig is useful to
correctly determine the interface and also to reduce the length
of interface layer. However CO2 displacement with separation
pig can be avoided if the environmental impact study accepts
and approves the safe venting of CO2 pipeline section under
maintenance.
3. Separation Pigging For CO2 Displacement

43. Pigging Philosophy
 The CO2 from the pipeline will be displaced using HC Lift Gas and
a Separation Pig will be used between CO2 and HC gas. The CO2
will be displaced into the injection well. As the pig approaches the
receiver station at North Flank, the MOV located on bypass line will
be kept open and MOV located on the receiver inlet will be throttled
to facilitate flow of gas through the pig receiver. This operation is
continued for about 10 – 15 seconds after the pig is received in the
receiver. This is to ensure complete displacement upto MOV
located at the inlet of pig receiver. At this point the displacement
process is complete and all the relevant valves on pipeline need to
be closed.
3. Separation Pigging For CO2 Displacement

44. Isolation and Maintenance Philosophy
The Process units/ systems which will have isolation requirements as a
part of this Project are as follows:
I. Flow lines / CO2 Pipeline
II. Package items
 Electrical heaters
 Chemical Injection Skid
 MPFM
I. Tie-ins
 Tie-in of CO2 pipe line to Injection Well
 Tie-in of CO2 pipe line with Rumaitha NEB

45. Isolation and Maintenance Philosophy
 Tie-in of Hydrocarbon Gas Lift line with Rumaitha NEB
 Tie-in of oil producer flow lines with RDS
 Utilities – Nitrogen
 Water injection pipeline
 Vent & Blowdown tie-ins
IV. Pig Traps

46. Vent, Relief and Depressuring Philosophy
 The normal relieving strategy in case of depressurization, relief or venting
scenario applied to hydrocarbon releases of collecting gases in a flare
knock out drum and venting via a flare stack cannot be applied for CO2
venting.
 Cold CO2 is heavier than air, and so if large quantities of CO2 were
released via a vent stack with inclement benign weather conditions, the
CO2 would settle down back to on grade level and potentially present a
significant asphyxiation suffocation risk.
 Also when Dense Phase CO2 is letdown from high pressure to atmosphere,
Joule Thompson cooling effect drops the CO2 temperature to around -78° C
and so a mixture of solid CO2 (dry ice) and gas is produced.
 High Pressure vent will consider controlled pressure reduction of CO2 in
order to minimise significant temperature drops upon release to
atmosphere.

47. Scenarios For Depressurisation, Venting & Relief
For Bab CO2 Pipeline
 Blocked Conditions
 External Fire
 General Thermal Relief
 General Maintenance Venting
Areas Requiring Venting And Depressurization
Venting and Depressurization is applicable for the following
areas/sections of Bab CO2 Injection Pilot Project:
Pig Launcher at Rumaitha
Block Valve Station-1 (BVS 1)
Block Valve Station-2 (BVS 2)
Pig Receiver at Bab North Flank
CO2 Injectors

48. Interface with NEB
Following are the interfaces with NEB Rumaitha facilities
Interface with CO2 pipeline: CO2 is supplied to Bab either from suction
(210-235 barg) or from discharge (265 barg) of the booster pumps (part of
NEB facilities).
Interface with HC lift gas: Hydrocarbon lift gas will be supplied from
NEB facilities. Hydrocarbon lift gas will be used for start-up
pressurization and for CO2 displacement. BAB operating team is to co-
ordinate with NEB operating team for line-up of HC lift gas to BAB
facilities to perform above activities.
PLC Interface: The BAB RTU/PLC shall be interfaced with Rumaitha
Cluster–N PLC by serial interface RS-485 Modbus for the alarm signal
exchange for monitoring and operator intervention which shall be fibre
optic based.
There is no ESD interface between BAB RTU/PLC and Rumaitha
Cluster–N PLC.

49. Interface with NEB
The following status indications have been imported from the
Rumaitha Cluster 14(N) to the BAB CO2 injection facility.
Flow indication from the discharge of CO2 Booster Pump (FI-3114-
01);
Total CO2 flow indication from Masdar (FI-3114-02A/02B);
CO2 Booster Pump On/Off status indication (XI-3114-01/02/03);
ESD 1, complete Rumaitha Cluster 14(N) shutdown status signal;
ESD 2, Rumaitha Cluster 14(N) production and injection shutdown
status signal.

50. Interface with NEB
The following status indications have been exported from the BAB
CO2 injection facility to the Rumaitha Cluster 14(N).
Start-up Electric Heater On/Off indication (XI-3901-02);
Pressure control valve (PCV-3901-01) pressure indication (PI-3901-
01);
HC Lift Gas HIPPS valve (SDV-3901-03/04) Open/Close indication
(SZIL-3901-03/04 and SZIH-3901-03/04);
CO2 HIPPS valve (SDV-3901-05/06) Open/Close indication (SZIL-
3901-05/06 and SZIH-3901-05/06).
ESD 1, complete BAB CO2 injection Cluster shutdown status signal;

51. Interface with NEB
The following status indications from the Masdar facility have been
provided in the BAB CO2 injection facility and Tabulated below in
Table 13.1
Sr No. Tag No SIGNAL DESCRIPTION
1 1501-XA-XXX2
CCF (Carbon Capture Facility) ESD Alarm
(CCF Emergency Shutdown)
2
1501-XA-XXX1
Confirmed CO2 Detection Alarm
(CO2 Release Warning)
3 1501-XA-XXX3 CCF trip Alarm (CCF Trips)
4
(1501-FI-4151 AA/BA) MMscf /
Tons
CO2 Daily Average Flowrate Indication
5
1501-AI-4150 AA / AB /AC /AD/AE /
AF
Gas Composition - H2S /CO2/H2/CO/CH4/N2 respectively.
6 1501-AI-4149 A Gas Composition - O2
7 (1501-XA-XXXX) Moisture Composition - H2O
8 1501-PI-4162 PIT (Pipeline Inlet Pressure)
9 1501-PAL-4162 PIT (Pipeline Low Pressure Alarm)
10 - ESI 1 Trip Alarm
11 - ESI 2 Trip Alarm

52.  2” Blow Down line from Manifold to Existing Header (TP 17)
 2” Drain line from MPFM to Existing Header (TP 18)
 2” Vent Gas Line from MPFM to Existing Header (TP 19A/B)
 10”Producer line connecting to 24” Existing Production Header (TP
20A/B)
 2” Chemical Inj. line from Existing Header to Manifold’s Production &
Test Headers (TP 21)
 2” Nitrogen line from Existing Header to Manifold’s Production, Test
& Blow Down Headers (TP 102)
Tie ins at RDS-8

53. Thank You