FPS NEW ENTRANT COORDINATION PROCESS
FPS NEW ENTRANT COORDINATION PROCESS
CODE OF PRACTICE Typical plan for the Commercial Negotiation Process
TECHNICAL INFORMATION REQUIRED
NEW ENTRANT FLUID PROPERTIES
•BP as FPS Operator must control the H2S content of Pipeline Liquids to ensure that the integrity of FPS is maintained and to comply with its statutory obligations in accordance with the Pipeline Safety Regulations and other legislation
•The Pipelines Safety Regulations 1996 state(a) no fluid is conveyed in a pipeline unless the safe operating limits of the pipeline have been established; and(b) a pipeline is not operated beyond its safe operating limits.
•The FPS Safe Operating Limit (SOL) for H2S is set at 10ppm(wt)-SOL calculation is based on ISO 15156,’Petroleum and natural gas industries-Materials for use in H2S containing environments in oil and gas production’
•BP as FPS Operator must control the H2S content of Pipeline Liquids to ensure that the integrity of FPS is maintained and to comply with its statutory obligations in accordance with the Pipeline Safety Regulations and other legislation
•The Pipelines Safety Regulations 1996 state(a) no fluid is conveyed in a pipeline unless the safe operating limits of the pipeline have been established; and(b) a pipeline is not operated beyond its safe operating limits.
•The FPS Safe Operating Limit (SOL) for H2S is set at 10ppm(wt)-SOL calculation is based on ISO 15156,’Petroleum and natural gas industries-Materials for use in H2S containing environments in oil and gas production’
•BP as FPS Operator must control the H2S content of Pipeline Liquids to ensure that the integrity of FPS is maintained and to comply with its statutory obligations in accordance with the Pipeline Safety Regulations and other legislation
•The Pipelines Safety Regulations 1996 state(a) no fluid is conveyed in a pipeline unless the safe operating limits of the pipeline have been established; and(b) a pipeline is not operated beyond its safe operating limits.
•The FPS Safe Operating Limit (SOL) for H2S is set at 10ppm(wt)-SOL calculation is based on ISO 15156,’Petroleum and natural gas industries-Materials for use in H2S containing environments in oil and gas production’
•BP as FPS Operator must control the H2S content of Pipeline Liquids to ensure that the integrity of FPS is maintained and to comply with its statutory obligations in accordance with the Pipeline Safety Regulations and other legislation
•The Pipelines Safety Regulations 1996 state(a) no fluid is conveyed in a pipeline unless the safe operating limits of the pipeline have been established; and(b) a pipeline is not operated beyond its safe operating limits.
•The FPS Safe Operating Limit (SOL) for H2S is set at 10ppm(wt)-SOL calculation is based on ISO 15156,’Petroleum and natural gas industries-Materials for use in H2S containing environments in oil and gas production’
•BP as FPS Operator must control the H2S content of Pipeline Liquids to ensure that the integrity of FPS is maintained and to comply with its statutory obligations in accordance with the Pipeline Safety Regulations and other legislation
•The Pipelines Safety Regulations 1996 state(a) no fluid is conveyed in a pipeline unless the safe operating limits of the pipeline have been established; and(b) a pipeline is not operated beyond its safe operating limits.
•The FPS Safe Operating Limit (SOL) for H2S is set at 10ppm(wt)-SOL calculation is based on ISO 15156,’Petroleum and natural gas industries-Materials for use in H2S containing environments in oil and gas production’
•BP as FPS Operator must control the H2S content of Pipeline Liquids to ensure that the integrity of FPS is maintained and to comply with its statutory obligations in accordance with the Pipeline Safety Regulations and other legislation
•The Pipelines Safety Regulations 1996 state(a) no fluid is conveyed in a pipeline unless the safe operating limits of the pipeline have been established; and(b) a pipeline is not operated beyond its safe operating limits.
•The FPS Safe Operating Limit (SOL) for H2S is set at 10ppm(wt)-SOL calculation is based on ISO 15156,’Petroleum and natural gas industries-Materials for use in H2S containing environments in oil and gas production’
•BP as FPS Operator must control the H2S content of Pipeline Liquids to ensure that the integrity of FPS is maintained and to comply with its statutory obligations in accordance with the Pipeline Safety Regulations and other legislation
•The Pipelines Safety Regulations 1996 state(a) no fluid is conveyed in a pipeline unless the safe operating limits of the pipeline have been established; and(b) a pipeline is not operated beyond its safe operating limits.
•The FPS Safe Operating Limit (SOL) for H2S is set at 10ppm(wt)-SOL calculation is based on ISO 15156,’Petroleum and natural gas industries-Materials for use in H2S containing environments in oil and gas production’
FPS NEW ENTRANTS AND H2S
INEOS
•BP sets different levels of control on new entrant fields depending on the H2S content of their Pipeline Liquids:
•Cat 1 Export steady state H2S levels 1% SOL
-New Entrants with a predicted export H2S value of 0.1ppm(wt) processed on facilities with no dedicated sweetening meet the standard specification and require no further mitigations.
•Cat 2 Export steady state H2S levels >1% SOL and 50% SOL
-require barriers to be put in place, identified by the FPS NEC team using the FPS H2S barrier diagram.-Barriers dependent on entry point to FPS, reservoir H2S level, processing, -Each entrant to be reviewed separately as part of NEC process.
•Cat 3 Export steady state H2S levels >50% SOL
-are required to reduce their export H2S value using additional processing.-require either a quantitative or semi quantitative approach to barrier identification. -FPS Engineering authority to determine if risk model approach is required.
•BP sets different levels of control on new entrant fields depending on the H2S content of their Pipeline Liquids:
•Cat 1 Export steady state H2S levels 1% SOL
-New Entrants with a predicted export H2S value of 0.1ppm(wt) processed on facilities with no dedicated sweetening meet the standard specification and require no further mitigations.
•Cat 2 Export steady state H2S levels >1% SOL and 50% SOL
-require barriers to be put in place, identified by the FPS NEC team using the FPS H2S barrier diagram.-Barriers dependent on entry point to FPS, reservoir H2S level, processing, -Each entrant to be reviewed separately as part of NEC process.
•Cat 3 Export steady state H2S levels >50% SOL
-are required to reduce their export H2S value using additional processing.-require either a quantitative or semi quantitative approach to barrier identification. -FPS Engineering authority to determine if risk model approach is required.
•BP sets different levels of control on new entrant fields depending on the H2S content of their Pipeline Liquids:
•Cat 1 Export steady state H2S levels 1% SOL
-New Entrants with a predicted export H2S value of 0.1ppm(wt) processed on facilities with no dedicated sweetening meet the standard specification and require no further mitigations.
•Cat 2 Export steady state H2S levels >1% SOL and 50% SOL
-require barriers to be put in place, identified by the FPS NEC team using the FPS H2S barrier diagram.-Barriers dependent on entry point to FPS, reservoir H2S level, processing, -Each entrant to be reviewed separately as part of NEC process.
•Cat 3 Export steady state H2S levels >50% SOL
-are required to reduce their export H2S value using additional processing.-require either a quantitative or semi quantitative approach to barrier identification. -FPS Engineering authority to determine if risk model approach is required.
•BP sets different levels of control on new entrant fields depending on the H2S content of their Pipeline Liquids:
•Cat 1 Export steady state H2S levels 1% SOL
-New Entrants with a predicted export H2S value of 0.1ppm(wt) processed on facilities with no dedicated sweetening meet the standard specification and require no further mitigations.
•Cat 2 Export steady state H2S levels >1% SOL and 50% SOL
-require barriers to be put in place, identified by the FPS NEC team using the FPS H2S barrier diagram.-Barriers dependent on entry point to FPS, reservoir H2S level, processing, -Each entrant to be reviewed separately as part of NEC process.
•Cat 3 Export steady state H2S levels >50% SOL
-are required to reduce their export H2S value using additional processing.-require either a quantitative or semi quantitative approach to barrier identification. -FPS Engineering authority to determine if risk model approach is required.
•BP sets different levels of control on new entrant fields depending on the H2S content of their Pipeline Liquids:
•Cat 1 Export steady state H2S levels 1% SOL
-New Entrants with a predicted export H2S value of 0.1ppm(wt) processed on facilities with no dedicated sweetening meet the standard specification and require no further mitigations.
•Cat 2 Export steady state H2S levels >1% SOL and 50% SOL
-require barriers to be put in place, identified by the FPS NEC team using the FPS H2S barrier diagram.-Barriers dependent on entry point to FPS, reservoir H2S level, processing, -Each entrant to be reviewed separately as part of NEC process.
•Cat 3 Export steady state H2S levels >50% SOL
-are required to reduce their export H2S value using additional processing.-require either a quantitative or semi quantitative approach to barrier identification. -FPS Engineering authority to determine if risk model approach is required.
•BP sets different levels of control on new entrant fields depending on the H2S content of their Pipeline Liquids:
•Cat 1 Export steady state H2S levels 1% SOL
-New Entrants with a predicted export H2S value of 0.1ppm(wt) processed on facilities with no dedicated sweetening meet the standard specification and require no further mitigations.
•Cat 2 Export steady state H2S levels >1% SOL and 50% SOL
-require barriers to be put in place, identified by the FPS NEC team using the FPS H2S barrier diagram.-Barriers dependent on entry point to FPS, reservoir H2S level, processing, -Each entrant to be reviewed separately as part of NEC process.
•Cat 3 Export steady state H2S levels >50% SOL
-are required to reduce their export H2S value using additional processing.-require either a quantitative or semi quantitative approach to barrier identification. -FPS Engineering authority to determine if risk model approach is required.
FPS NEW ENTRANTS AND H2S
INEOS’•BP sets different levels of control on new entrant fields depending on the H2S content of their Pipeline Liquids:
•Cat 1 Export steady state H2S levels 1% SOL
-New Entrants with a predicted export H2S value of 0.1ppm(wt) processed on facilities with no dedicated sweetening meet the standard specification and require no further mitigations.
•Cat 2 Export steady state H2S levels >1% SOL and 50% SOL
-require barriers to be put in place, identified by the FPS NEC team using the FPS H2S barrier diagram.-Barriers dependent on entry point to FPS, reservoir H2S level, processing, -Each entrant to be reviewed separately as part of NEC process.
•Cat 3 Export steady state H2S levels >50% SOL
-are required to reduce their export H2S value using additional processing.-require either a quantitative or semi quantitative approach to barrier identification. -FPS Engineering authority to determine if risk model approach is required.
Hierarchy of control – Bias towards hardware/inherent safety & reducing the scope for human error – multi barrier defence
Cooling
before entry
to FPS
(3 days to
reach Unity)
Export
Sampling
HAZARD
H2S levels >
FPS SOL
SIL 1/2 Analyser shutdown
system on oil
export HAZARD Realisati
on
Dilution
H2S
awareness
training and
procedures
Well
management /
blending.
Process design,
eg Basis of
design for
highest H2S
well.
Are facilities designed for worst case H2S
case?
Consequence
Stress corrosion
cracking leads to failure of FPS sealine
Facility or
FPS
Operator
intervention
FPS visits to
platform
Low flow trip
Highest H2S wells shut in when flow
drops
Reservoir
H2S levels
understood?
Carry out RCI testing and well flow
tests.
Reservoir
management to
prevent souring
in place?
Can credit be taken for sampling vs
residence time before entering FPS?
This diagram shows potential barriers in order to manage H2S in FPS, this diagram does NOT prescribe the combination
required for a particular field.
-FPS standard H2S spec<0.1ppm(wt)
-Export H2S>0.1ppm(wt) will require
extra mitigations.
-Mitigations required will depend on
expected export level and highest
level of H2S present in a particular well
stream.
Limit choke opening on sour wells.
Hierarchy of control – Bias towards hardware/inherent safety & reducing the scope for human error – multi barrier defence
Cooling
before entry
to FPS
(3 days to
reach Unity)
Export
Sampling
HAZARD
H2S levels >
FPS SOL
SIL 1/2 Analyser shutdown
system on oil
export HAZARD Realisati
on
Dilution
H2S
awareness
training and
procedures
Well
management /
blending.
Process design,
eg Basis of
design for
highest H2S
well.
Are facilities designed for worst case H2S
case?
Consequence
Stress corrosion
cracking leads to failure of FPS sealine
Facility or
FPS
Operator
intervention
FPS visits to
platform
Low flow trip
Highest H2S wells shut in when flow
drops
Reservoir
H2S levels
understood?
Carry out RCI testing and well flow
tests.
Reservoir
management to
prevent souring
in place?
Can credit be taken for sampling vs
residence time before entering FPS?
This diagram shows potential barriers in order to manage H2S in FPS, this diagram does NOT prescribe the combination
required for a particular field.
-FPS standard H2S spec<0.1ppm(wt)
-Export H2S>0.1ppm(wt) will require
extra mitigations.
-Mitigations required will depend on
expected export level and highest
level of H2S present in a particular well
stream.
Limit choke opening on sour wells.
Hierarchy of control – Bias towards hardware/inherent safety & reducing the scope for human error – multi barrier defence
Cooling
before entry
to FPS
(3 days to
reach Unity)
Export
Sampling
HAZARD
H2S levels >
FPS SOL
SIL 1/2 Analyser shutdown
system on oil
export HAZARD Realisati
on
Dilution
H2S
awareness
training and
procedures
Well
management /
blending.
Process design,
eg Basis of
design for
highest H2S
well.
Are facilities designed for worst case H2S
case?
Consequence
Stress corrosion
cracking leads to failure of FPS sealine
Facility or
FPS
Operator
intervention
FPS visits to
platform
Low flow trip
Highest H2S wells shut in when flow
drops
Reservoir
H2S levels
understood?
Carry out RCI testing and well flow
tests.
Reservoir
management to
prevent souring
in place?
Can credit be taken for sampling vs
residence time before entering FPS?
This diagram shows potential barriers in order to manage H2S in FPS, this diagram does NOT prescribe the combination
required for a particular field.
-FPS standard H2S spec<0.1ppm(wt)
-Export H2S>0.1ppm(wt) will require
extra mitigations.
-Mitigations required will depend on
expected export level and highest
level of H2S present in a particular well
stream.
Limit choke opening on sour wells.
GENERIC FPS H2S BARRIER DIAGRAM