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