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WO2018037084A2 - High-integrity pressure protection system - Google Patents

High-integrity pressure protection system Download PDF

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Publication number
WO2018037084A2
WO2018037084A2 PCT/EP2017/071345 EP2017071345W WO2018037084A2 WO 2018037084 A2 WO2018037084 A2 WO 2018037084A2 EP 2017071345 W EP2017071345 W EP 2017071345W WO 2018037084 A2 WO2018037084 A2 WO 2018037084A2
Authority
WO
WIPO (PCT)
Prior art keywords
production
pressure protection
valve
fluid
integrity pressure
Prior art date
Application number
PCT/EP2017/071345
Other languages
French (fr)
Other versions
WO2018037084A3 (en
Inventor
Marcel CAVALCANTI DE CASTRO
Wenche FINNERUD
Andrew Stephen Edward WILSON
Original Assignee
Fmc Kongsberg Subsea As
Priority date (The priority date is an assumption and is not a legal conclusion. Google has not performed a legal analysis and makes no representation as to the accuracy of the date listed.)
Filing date
Publication date
Application filed by Fmc Kongsberg Subsea As filed Critical Fmc Kongsberg Subsea As
Publication of WO2018037084A2 publication Critical patent/WO2018037084A2/en
Publication of WO2018037084A3 publication Critical patent/WO2018037084A3/en

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Classifications

    • E—FIXED CONSTRUCTIONS
    • E21—EARTH OR ROCK DRILLING; MINING
    • E21B—EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
    • E21B41/00—Equipment or details not covered by groups E21B15/00 - E21B40/00
    • E21B41/0007—Equipment or details not covered by groups E21B15/00 - E21B40/00 for underwater installations
    • E—FIXED CONSTRUCTIONS
    • E21—EARTH OR ROCK DRILLING; MINING
    • E21B—EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
    • E21B33/00—Sealing or packing boreholes or wells
    • E21B33/02—Surface sealing or packing
    • E21B33/03—Well heads; Setting-up thereof
    • E—FIXED CONSTRUCTIONS
    • E21—EARTH OR ROCK DRILLING; MINING
    • E21B—EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
    • E21B33/00—Sealing or packing boreholes or wells
    • E21B33/02—Surface sealing or packing
    • E21B33/03—Well heads; Setting-up thereof
    • E21B33/035—Well heads; Setting-up thereof specially adapted for underwater installations
    • E—FIXED CONSTRUCTIONS
    • E21—EARTH OR ROCK DRILLING; MINING
    • E21B—EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
    • E21B43/00—Methods or apparatus for obtaining oil, gas, water, soluble or meltable materials or a slurry of minerals from wells
    • E21B43/01—Methods or apparatus for obtaining oil, gas, water, soluble or meltable materials or a slurry of minerals from wells specially adapted for obtaining from underwater installations
    • F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
    • F16—ENGINEERING ELEMENTS AND UNITS; GENERAL MEASURES FOR PRODUCING AND MAINTAINING EFFECTIVE FUNCTIONING OF MACHINES OR INSTALLATIONS; THERMAL INSULATION IN GENERAL
    • F16K—VALVES; TAPS; COCKS; ACTUATING-FLOATS; DEVICES FOR VENTING OR AERATING
    • F16K17/00—Safety valves; Equalising valves, e.g. pressure relief valves
    • F16K17/02—Safety valves; Equalising valves, e.g. pressure relief valves opening on surplus pressure on one side; closing on insufficient pressure on one side

Definitions

  • the present invention relates to a subsea hydrocarbon fluid production system comprising a high-integrity pressure protection system and an associated method of providing a high-integrity pressure protection system for protecting a flowline transporting a hydrocarbon production fluid, e.g. oil and gas, from a subsea hydrocarbon fluid production system.
  • a hydrocarbon production fluid e.g. oil and gas
  • the present invention relates to a subsea hydrocarbon fluid production system comprising:
  • a X-mas tree supported by, i.e. directly or indirectly mounted on, the seabed- founded structure comprising a production master valve, a production wing valve and a flowline connection interface arranged in a flow path of a hydrocarbon production fluid;
  • a high-integrity pressure protection system comprising a pair of high-integrity pressure protection barrier valves arranged to protect a flowline connected to the flowline connection interface for transporting the production fluid from the X-mas tree.
  • the present invention also relates to an independently retrievable high-integrity pressure protection module for use in said subsea hydrocarbon fluid production system.
  • the present invention further relates to a method of providing a high-integrity pressure protection system for protecting a flowline transporting a hydrocarbon production fluid from a subsea hydrocarbon fluid production system comprising: - a seabed-founded structure; and
  • X-mas tree supported by the seabed-founded structure comprising a production master valve, a production wing valve and a flowline connection interface arranged in a flow path of the hydrocarbon production fluid, to which flowline connection interface said flowline is connected.
  • a high-integrity pressure-protection system also known as HIPPS
  • HIPPS high-integrity pressure-protection system
  • downstream equipment e.g. flowlines
  • the main requirement of a HIPPS is to reliably act to isolate the lower-pressure- rated downstream components from the shut-in wellhead pressure in any and all situations.
  • the design and reliability performance requirements for a HIPPS is normally defined in terms of the required Safety Integrity Level (SIL) as specified in IEC 6151 1s.
  • SIL Safety Integrity Level
  • a typical HIPPS employs two barrier valves to positively isolate the lower- pressure-rated components from the shut-in wellhead pressure.
  • the HIPPS barrier valves are configured to be fail-safe close, such that any loss of electrical and/or hydraulic power to the HIPPS results in automatic closure of the HIPPS barrier valves.
  • the HIPPS barrier valves are normally spring return actuated, i.e. each HIPPS barrier valve comprises a valve body which is biased towards a closed position by a spring but is kept open by a pressurised hydraulic fluid. When an abnormal condition is detected, the hydraulic fluid is bled off and the spring is allowed to bias the valve body to a closed position.
  • HIPPS In order for the HIPPS barrier valve to comply with HIPPS requirements, the closure time of the barrier valve must not exceed specified limits, which depends on flow nature and component performance. It is known to install HIPPS close to individual wellheads. However, in hydrocarbon fluid production systems having a satellite well architecture, HIPPS may
  • EP 2592318 Al discloses a pipeline protection system having a pipeline for fluid flow, a plurality of isolation valves in series in the pipeline, means for sensing a fluid pressure in the pipeline and closing the isolation valves in response to a pressure exceeding a threshold, a series connection of a plurality of by-pass valves connected in parallel across said isolation valves, means for selectively opening and closing the by-pass valves, and safety means adapted to prevent the by-pass valves all being open at the same time.
  • the object of the present invention is to improve on prior art HIPPS and, in a reliable and cost-efficient manner, provide a HIPPS function for flowline running from a seabed-founded X-mas tree.
  • the subsea hydrocarbon well according to the invention is characterised in that the high-integrity pressure protection system comprises a high-integrity pressure protection module which is supported by the seabed-founded structure and comprises a least one high-integrity pressure protection barrier valve positioned in the flow path of the production fluid between the production wing valve and the flowline connection interface.
  • the independently retrievable high-integrity pressure protection module is characterised in that it comprises a least one high-integrity pressure protection barrier valve and module interface comprising an upstream production fluid conduit interface arranged for fluid communication with the production valves, and a downstream production fluid conduit interface arranged for fluid communication with the flowline connection interface.
  • the method according to the invention is characterised by the step of mounting a high-integrity pressure protection module comprising at least one high-integrity pressure protection barrier valve so that it is supported by the seabed-founded structure with said at least one high-integrity pressure protection barrier valve positioned in the flow path of the production fluid between the production valves and the flowline connection interface.
  • mounting the HIPPS module on the seabed-founded structure together with the X-mas tree allows for integration of at least one of the production master valve and the production wing valve into the HIPPS.
  • the HIPPS module By configuring at least one of the production master valve and the production wing valve as a HIPPS barrier valve, the HIPPS module only needs to be equipped with one HIPPS barrier valve while still achieving high reliability and appropriate level of risk reduction. Consequently, in such a configuration the production master valve or the production wing valve will operate as and provide the functionality of a first HIPPS barrier valve and the HIPPS barrier valve of the HIPPS module will operate as and provide the functionality of the second HIPPS barrier valve.
  • At least one of the production master valve and the production wing valve may be configured as a high-integrity pressure protection barrier valve, which at least one high-integrity pressure protection barrier valve of the high-integrity pressure protection module and at least one of the production master valve and the production wing valve together form said pair of high-integrity pressure protection barrier valves.
  • the HIPPS module may comprise two HIPPS barrier valves arranged in series, in which case neither the production master valve nor the production wing valve need to be configured as a HIPPS barrier valve allowing additional hardware redundancy and higher level of risk reduction.
  • high-integrity pressure protection module may comprise a first high- integrity pressure protection barrier valve and second high-integrity pressure protection barrier valve which together form said pair of high-integrity pressure protection barrier valves.
  • a X-mas tree often comprises a flowline isolation valve which is arranged to isolate the production valves of the X-mas tree from the flowline arranged to transport production fluids from the X-mas tree to downstream production facilities, e.g. a manifold. If the at least one barrier valve of the HIPPS module is positioned upstream of the flowline isolation valve, the flowline isolation valve can also be used as a test valve for the HIPPS, thus removing the need to provide a separate test valve for the barrier valves of the HIPPS.
  • the at least one high-integrity pressure protection barrier valve of the high-integrity pressure protection module may be positioned upstream of the flowline isolation valve.
  • the flowline isolation valve will become a test and flowline isolation valve.
  • test and flowline isolation valve may be configured as a fail-safe closed barrier valve.
  • mounting the HIPPS module on the seabed-founded structure together with the X-mas tree allows a common, independently retrievable subsea control module, SCM, to control all of the valves supported by the seabed-founded structure, including the valves of the HIPPS module and the X-mas tree.
  • Independent logic controllers and independent hydraulic return paths between the HIPPS barrier valves and X-mas tree valves within the SCM allows further redundancy and consequently reduced common cause failure.
  • the subsea hydrocarbon fluid production system may comprise a retrievable subsea control module arranged to control all valves supported by the seabed-founded structure, including the valves of the HIPPS module and the valves of the X-mas tree.
  • the hydrocarbon well may comprise individually retrievable first and second SCMs, wherein the first SCM is arranged to control valves supported by the seabed-founded structure which are safety critical, i.e. arranged to function as barrier valves, and the second SCM is arranged to control valves supported by the seabed-founded structure which are not safety critical, i.e. not configured to function as barrier valves.
  • the first SCM may be configured to control the production master valve, the production wing valve and the at least one HIPPS barrier valve of the HIPPS module
  • the second SCM may be configured to control injection valves, cross-over valves and other valves which are not barrier valves.
  • the hydraulic fluid preventing the HIPPS valve or valves from closing needs to be bled off, i.e. drained from the actuators controlling the HIPPS valve or valves.
  • Two hydraulic fluid bleed off methods can be used to achieve rapid closure of the HIPPS valve or valves: (a) open hydraulic bleed off to the surrounding sea either via the subsea control module controlling the HIPPS valve or valves, or via a quick dump valve which is controlled by the subsea control module, and (b) closed hydraulic bleed off either from the HIPPS valve actuators to an external compensator and/or between the HIPPS valve actuator chambers.
  • the high-integrity pressure protection module may be made as an integral part of the X-mas tree such that it cannot be retrieved separately from the X-mas tree.
  • the high-integrity pressure protection module may be retrievably mounted on the X-mas tree.
  • the high-integrity pressure protection module may comprise at least one of:
  • a temperature transducer for monitoring the temperature of the production fluid
  • a multi-phase flow meter and/or a wet gas meter for monitoring the flow rate, the gas volume fraction and/or the wet gas content of the production fluid
  • connection interface for connecting to a subsea control module of the X-mas tree.
  • the plurality of pressure transducers may comprise three pressure transducers positioned downstream of the choke for operation of the HIPPS and a pressure transducer positioned between the HIPPS barrier valves. Description of the drawings
  • Fig. 1 is a schematic representation of a X-mas tree supported by a subsea-founded structure, which X-mas tree comprises a high-integrity pressure protection module as an integral part.
  • Fig. 2 is a schematic representation of a X-mas tree supported by a subsea-founded structure and a retrievable valve module mounted on the X-mas tree, which retrievable valve module comprises a high-integrity pressure protection module.
  • Fig. 3 is a schematic representation of a X-mas tree supported by a subsea-founded structure and a retrievable valve module mounted on the X-mas tree, which retrievable valve module comprises a high-integrity pressure protection module and a choke.
  • Fig. 1 is a schematic representation of a subsea hydrocarbon fluid production system 101 comprising a seabed-founded structure 1 and a subsea X-mas tree, XT, 2 supported by the seabed-founded structure 1.
  • the seabed-founded structure 1 comprises a structural framework and a foundation, e.g. driven/suction piles or a gravity-based foundation, arranged so as to provide support for the XT 2.
  • the XT 2 comprises a hydrocarbon fluid production conduit 3 emerging from a hydrocarbon well bore (not disclosed).
  • the XT 2 comprises a surface controlled sub-surface safety valve, SCSSV, 4, a production master valve, PMV, 5 and a production wing valve, PWV, 6 mounted in the flow path of the production fluid. Downstream of the PWV 6, the XT comprises a choke 7a, 7b (two alternative positions of which are disclosed), a test and flowline isolation valve, TFIV, 8 and a flowline connection interface 9, all of which are arranged in the flow path of the production fluid.
  • the flowline connection interface 9 provides a connection interface for a flowline (not disclosed) arranged to transport production fluid from the XT 2 to a downstream facility, e.g. a manifold, which is located at a distance from the XT 2 and, to the extent the downstream facility is seabed-founded, is supported by its own seabed-founded structure.
  • a downstream facility e.g. a manifold
  • the particulars and modus operandi of the valves 4, 5, 6, and 8 and the choke 7a, 7b are well known in the art and will not be discussed any further here.
  • the XT 2 need not necessarily comprise all of the discussed equipment.
  • the choke valve 7a, 7b and/or the TFIV 8 may be omitted.
  • the XT 2 may comprise additional equipment for facilitating the hydrocarbon fluid production, e.g. valves for gaining access to the production conduit 3 and transducers for monitoring parameters relevant for the hydrocarbon fluid production.
  • additional equipment may be included in the XT 2.
  • the XT 2 comprises a high-integrity pressure protection module, HIPPS module, 14 which is arranged in the flow path of the production fluid between the PWV 6 and the flowline connection interface 9.
  • HIPPS module high-integrity pressure protection module
  • the HIPPS module 14 is arranged to protect the flowline (not disclosed) connected to the flowline connection interface 9 from the full shut-in tubing head pressure of the hydrocarbon well. This will allow the flowline to be rated to a pressure less than the full shut-in tubing head pressure.
  • the HIPPS module 14 comprises two high-integrity pressure protection barrier valves 15, 16 which can be actuated between an open position and a closed position.
  • the barrier valves 15, 16 are configured to be fail-safe close valves, such that any loss of electrical power and/or hydraulic pressure to the HIPPS module 14 will result in automatic closure of the barrier valves 15, 16.
  • the barrier valves 15, 16 isolate the flowline connection interface 9 and the flowline connected thereto from the shut-in tubing head pressure of the well.
  • the HIPPS module 14 comprises a pressure transducer 17 positioned between the barrier valves 15, 16 as well as pressure transducers 18-20.
  • Pressure transducer 21 and a temperature transducer 22 positioned downstream of the barrier valves 15, 16 are typical requirements as part of the normal production system and are not specifically required for operation of the HIPPS.
  • Pressure transducers 18-20 are typically arranged to provide 2oo3 (2-out-of-3) voting whether or not to activate the HIPPS valves 15, 16.
  • the TFIV 8 is positioned between the HIPPS module 14 and the flowline
  • connection interface 9 i.e. downstream of the HIPPS module 14. This will allow the TFIV 8 to double as a test valve for the barrier valves 15, 16 of the HIPPS module 14 and the production valves 5, 6, in addition to being used as an isolation valve for the flowline connection interface 9.
  • the TFIV 8 is a fail-safe closed valve, i.e. a valve which is actuated to a closed position in case of a failure.
  • the TFIV 8 may be utilised as a barrier valve to provide an isolation barrier between the production valves 5, 6 and the flowline connection interface 9 in addition to the barrier valves 14, 15 of the HIPPS module 14.
  • at least one of the production valves 5, 6 is configured to function as a HIPPS barrier valve.
  • Using at least one of the PMV 5 and the PWV 6 as a HIPPS barrier valve will allow the HIPPS module 14 to be equipped with only one HIPPS barrier valve without deviating from the normal HIPPS requirement of having two HIPPS barrier valves between the high pressure rated and the low pressure rated sections of the hydrocarbon fluid production system.
  • Configuring any one of the PMV 5 and the PWV 6 as a HIPPS barrier valve will normally include configuring the valve to close within a specified timeframe upon detection of an abnormal situation, e.g. within two seconds.
  • the hydrocarbon fluid production system 101 may comprise a retrievable subsea control module, SCM, 23 arranged to control all of the valves of the XT 2, including the production valves 5, 6, the HIPPS barrier valves 15, 16, the XOV 10 and the CIV 1 1.
  • SCM retrievable subsea control module
  • the hydrocarbon fluid production system 101 may comprise individually retrievable first and second SCMs 24a and 24b, wherein the first SCM 24a is arranged to control valves supported by the seabed-founded structure 1 which are safety critical, i.e. arranged to function as barrier valves, and the second SCM 24b is arranged to control valves supported by the seabed-founded structure 1 which are not safety critical, i.e. not configured to function as barrier valves.
  • the HIPPS module 14 is made as an integral part of the XT 2 and, consequently, cannot be retrieved independently from the XT 2.
  • Fig. 2 discloses an alternative embodiment of a hydrocarbon fluid production system 102 according to the invention.
  • the system 102 shares features with the previously disclose system 101 and in Fig. 2 like reference numerals indicate like features.
  • the HIPPS module 14 is retrievably mounted on the XT 2. This will allow the HIPPS module 14 to be disconnected from the rest of the X-mas tree structure.
  • the retrievable HIPPS module 14 and the XT 2 comprise interfaces 26 and 27, respectively, allowing the retrievable HIPPS module 14 to be connected to and disconnected from the XT 2.
  • the retrievable HIPPS module interface 26 comprises an upstream production fluid conduit interface 28 arranged for fluid communication with the production valves 5, 6, and a downstream production fluid conduit interface 29 arranged for fluid communication with the flowline connection interface 9, thus allowing the HIPPS barrier valves 15, 16 of the retrievable HIPPS module 14 to be connected in the flow path of the production fluid between the production valves 5, 6 and the flowline connection interface 9.
  • the flow path of the production fluid will be routed though barrier valves 15, 16 of the retrievable HIPPS module 14, and when the retrievable HIPPS module 14 is disconnected from the XT 2, the flow path between the production valves 5, 6 and the flowline connection interface 9 will be open, but isolated through the closure of the TFIV 8 and the PMW 6.
  • the choke 7 is positioned outside of the retrievable HIPPS module 14 upstream of interface 27.
  • Pressure transducer 21 and temperature transducer 22 are also positioned outside of the retrievable HIPPS module 14, but downstream of interface 27. Consequently, the choke 7 and the transducers 21 and 22 will remain in the XT 2 when the retrievable HIPPS module 14 is disconnected from the XT 2.
  • the hydrocarbon fluid production system 102 may comprise an independently retrievable subsea control module, SCM, 23 arranged to control all of the valves supported by the seabed-founded structure 1 or, alternatively, individually retrievable first and second SCMs 24a and 24b, wherein the first SCM 24a is arranged to control valves supported by the seabed-founded structure 1 which are safety critical, and the second SCM 24b is arranged to control valves supported by the seabed-founded structure 1 which are not safety critical.
  • Fig. 3 discloses a further embodiment of a hydrocarbon fluid production system 103 according to the invention.
  • the system 103 shares features with the previously disclose systems 101 and 102, and, consequently, in Fig. 3 like reference numerals indicate like features.
  • the choke 7 is positioned inside the retrievable HIPPS module 14 downstream of the HIPPS barrier valves 15 and 16. Also, pressure transducer 21 and temperature transducer 22 are positioned inside the retrievable HIPPS module 14 downstream of the choke 7. Consequently, the choke 7 and the transducers 21 and 22 are retrievable together with the valve module 14, thus allowing also the choke 7 and the transducers 21 and 22 to be retrieved from the XT 2. It is to be understood, however, that the retrievable HIPPS module 14 of Figs. 2 and 3 may comprise additional components than those disclosed in the figures.
  • the retrievable HIPPS module 14 may comprise at least one of a multi-phase flow meter and/or a wet gas meter and/or a single phase meter for monitoring the flow rate, the gas volume fraction and/or the wet gas content of the production fluid, hydraulic fluid bleed-off lines and/or control lines connectable to a subsea control module of the X-mas tree (2), a chemical injection valve, a sand detector and a connection interface for connecting to a subsea control module of the X mas tree (2), which equipment can give the retrievable HIPPS module flow control and/or monitoring functionality in addition to the HIPPS functionality.
  • the SCMs may advantageously be modularised such that the distribution of hydraulic functions and electric functions are effectuated via separate sub-modules.
  • the SCMs may comprise a power control router (not disclosed) arranged to effectuate the electric signals and a hydraulic control router arranged to effectuate the hydraulic signals, wherein at least one of the control routers is configured to control the HIPPS functionality of the hydrocarbon fluid production system.

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  • Engineering & Computer Science (AREA)
  • Geology (AREA)
  • Life Sciences & Earth Sciences (AREA)
  • Mining & Mineral Resources (AREA)
  • Environmental & Geological Engineering (AREA)
  • Fluid Mechanics (AREA)
  • Physics & Mathematics (AREA)
  • General Life Sciences & Earth Sciences (AREA)
  • Geochemistry & Mineralogy (AREA)
  • General Engineering & Computer Science (AREA)
  • Mechanical Engineering (AREA)
  • Production Of Liquid Hydrocarbon Mixture For Refining Petroleum (AREA)
  • Pipeline Systems (AREA)
  • Loading And Unloading Of Fuel Tanks Or Ships (AREA)

Abstract

A subsea hydrocarbon fluid production system (101, 102, 103) comprising a seabed-founded structure (1), a X-mas tree (2) supported by the seabed-founded structure comprising a production master valve (5), a production wing valve (6) and a flowline connection interface (9) arranged in a flow path of a hydrocarbon production fluid, and a high-integrity pressure protection system comprising a pair of high-integrity pressure protection barrier valves arranged to protect a flowline connected to the flowline connection interface for transporting the production fluid from the X-mas tree. The high-integrity pressure protection system comprises a high-integrity pressure protection module (14) which is supported by the seabed-founded structure and comprises a least one high-integrity pressure protection barrier valve (15, 16) positioned in the flow path of the production fluid between the production wing valve and the flowline connection interface.

Description

HIGH-INTEGRITY PRESSURE PROTECTION SYSTEM
Field of the invention
The present invention relates to a subsea hydrocarbon fluid production system comprising a high-integrity pressure protection system and an associated method of providing a high-integrity pressure protection system for protecting a flowline transporting a hydrocarbon production fluid, e.g. oil and gas, from a subsea hydrocarbon fluid production system.
In particular, the present invention relates to a subsea hydrocarbon fluid production system comprising:
- a seabed-founded structure;
a X-mas tree supported by, i.e. directly or indirectly mounted on, the seabed- founded structure comprising a production master valve, a production wing valve and a flowline connection interface arranged in a flow path of a hydrocarbon production fluid; and
- a high-integrity pressure protection system comprising a pair of high-integrity pressure protection barrier valves arranged to protect a flowline connected to the flowline connection interface for transporting the production fluid from the X-mas tree.
The present invention also relates to an independently retrievable high-integrity pressure protection module for use in said subsea hydrocarbon fluid production system.
The present invention further relates to a method of providing a high-integrity pressure protection system for protecting a flowline transporting a hydrocarbon production fluid from a subsea hydrocarbon fluid production system comprising: - a seabed-founded structure; and
- a X-mas tree supported by the seabed-founded structure comprising a production master valve, a production wing valve and a flowline connection interface arranged in a flow path of the hydrocarbon production fluid, to which flowline connection interface said flowline is connected. Background
As is known in the art, a high-integrity pressure-protection system, also known as HIPPS, is used to protect downstream equipment, e.g. flowlines, from the full shut- in wellhead pressure and hence allow use of downstream flowlines which are not rated for such pressure. The main requirement of a HIPPS is to reliably act to isolate the lower-pressure- rated downstream components from the shut-in wellhead pressure in any and all situations. The design and reliability performance requirements for a HIPPS is normally defined in terms of the required Safety Integrity Level (SIL) as specified in IEC 6151 1s.
A typical HIPPS employs two barrier valves to positively isolate the lower- pressure-rated components from the shut-in wellhead pressure. The HIPPS barrier valves are configured to be fail-safe close, such that any loss of electrical and/or hydraulic power to the HIPPS results in automatic closure of the HIPPS barrier valves. The HIPPS barrier valves are normally spring return actuated, i.e. each HIPPS barrier valve comprises a valve body which is biased towards a closed position by a spring but is kept open by a pressurised hydraulic fluid. When an abnormal condition is detected, the hydraulic fluid is bled off and the spring is allowed to bias the valve body to a closed position. In order for the HIPPS barrier valve to comply with HIPPS requirements, the closure time of the barrier valve must not exceed specified limits, which depends on flow nature and component performance. It is known to install HIPPS close to individual wellheads. However, in hydrocarbon fluid production systems having a satellite well architecture, HIPPS may
alternatively be installed on a common production header or manifold upstream of the main flowline. For example, such configurations are discussed in
US 2010/0071775 Al. It is also known to utilise one of the process control or production valves of the subsea X-mas tree (XT), e.g. a production master valve or a production wing valve, as a barrier valve in a HIPPS. Such a system is disclosed in GB 2459488 A.
EP 2592318 Al discloses a pipeline protection system having a pipeline for fluid flow, a plurality of isolation valves in series in the pipeline, means for sensing a fluid pressure in the pipeline and closing the isolation valves in response to a pressure exceeding a threshold, a series connection of a plurality of by-pass valves connected in parallel across said isolation valves, means for selectively opening and closing the by-pass valves, and safety means adapted to prevent the by-pass valves all being open at the same time. The object of the present invention is to improve on prior art HIPPS and, in a reliable and cost-efficient manner, provide a HIPPS function for flowline running from a seabed-founded X-mas tree.
Summary of the invention
The subsea hydrocarbon well according to the invention is characterised in that the high-integrity pressure protection system comprises a high-integrity pressure protection module which is supported by the seabed-founded structure and comprises a least one high-integrity pressure protection barrier valve positioned in the flow path of the production fluid between the production wing valve and the flowline connection interface.
The independently retrievable high-integrity pressure protection module according to the invention is characterised in that it comprises a least one high-integrity pressure protection barrier valve and module interface comprising an upstream production fluid conduit interface arranged for fluid communication with the production valves, and a downstream production fluid conduit interface arranged for fluid communication with the flowline connection interface.
The method according to the invention is characterised by the step of mounting a high-integrity pressure protection module comprising at least one high-integrity pressure protection barrier valve so that it is supported by the seabed-founded structure with said at least one high-integrity pressure protection barrier valve positioned in the flow path of the production fluid between the production valves and the flowline connection interface. By arranging the high-integrity pressure protection module on the same seabed- founded structure supporting the X-mas tree, a number of advantages are obtained.
Firstly, there will be no need to provide a separate seabed-founded structure for the HIPPS.
Secondly, mounting the HIPPS module on the seabed-founded structure together with the X-mas tree allows for integration of at least one of the production master valve and the production wing valve into the HIPPS.
By configuring at least one of the production master valve and the production wing valve as a HIPPS barrier valve, the HIPPS module only needs to be equipped with one HIPPS barrier valve while still achieving high reliability and appropriate level of risk reduction. Consequently, in such a configuration the production master valve or the production wing valve will operate as and provide the functionality of a first HIPPS barrier valve and the HIPPS barrier valve of the HIPPS module will operate as and provide the functionality of the second HIPPS barrier valve.
Accordingly, at least one of the production master valve and the production wing valve may be configured as a high-integrity pressure protection barrier valve, which at least one high-integrity pressure protection barrier valve of the high-integrity pressure protection module and at least one of the production master valve and the production wing valve together form said pair of high-integrity pressure protection barrier valves. Alternatively, the HIPPS module may comprise two HIPPS barrier valves arranged in series, in which case neither the production master valve nor the production wing valve need to be configured as a HIPPS barrier valve allowing additional hardware redundancy and higher level of risk reduction.
Accordingly, high-integrity pressure protection module may comprise a first high- integrity pressure protection barrier valve and second high-integrity pressure protection barrier valve which together form said pair of high-integrity pressure protection barrier valves.
Thirdly, mounting the HIPPS module on the seabed-founded structure together with the X-mas tree allows valves already present in the X-mas tree to be utilised for supporting the HIPPS. For example, a X-mas tree often comprises a flowline isolation valve which is arranged to isolate the production valves of the X-mas tree from the flowline arranged to transport production fluids from the X-mas tree to downstream production facilities, e.g. a manifold. If the at least one barrier valve of the HIPPS module is positioned upstream of the flowline isolation valve, the flowline isolation valve can also be used as a test valve for the HIPPS, thus removing the need to provide a separate test valve for the barrier valves of the HIPPS.
Accordingly, if the X-mas tree comprises a flowline isolation valve positioned in the flow path of the production fluid upstream of the flowline connection interface, the at least one high-integrity pressure protection barrier valve of the high-integrity pressure protection module may be positioned upstream of the flowline isolation valve. In this case the flowline isolation valve will become a test and flowline isolation valve.
Also, the test and flowline isolation valve may be configured as a fail-safe closed barrier valve. Furthermore, mounting the HIPPS module on the seabed-founded structure together with the X-mas tree allows a common, independently retrievable subsea control module, SCM, to control all of the valves supported by the seabed-founded structure, including the valves of the HIPPS module and the X-mas tree.
Independent logic controllers and independent hydraulic return paths between the HIPPS barrier valves and X-mas tree valves within the SCM allows further redundancy and consequently reduced common cause failure.
Accordingly, the subsea hydrocarbon fluid production system may comprise a retrievable subsea control module arranged to control all valves supported by the seabed-founded structure, including the valves of the HIPPS module and the valves of the X-mas tree.
Alternatively, the hydrocarbon well may comprise individually retrievable first and second SCMs, wherein the first SCM is arranged to control valves supported by the seabed-founded structure which are safety critical, i.e. arranged to function as barrier valves, and the second SCM is arranged to control valves supported by the seabed-founded structure which are not safety critical, i.e. not configured to function as barrier valves. For example, the first SCM may be configured to control the production master valve, the production wing valve and the at least one HIPPS barrier valve of the HIPPS module, and the second SCM may be configured to control injection valves, cross-over valves and other valves which are not barrier valves.
During closure of the high-integrity pressure protection barrier valve or valves of the high-integrity pressure protection module, the hydraulic fluid preventing the HIPPS valve or valves from closing needs to be bled off, i.e. drained from the actuators controlling the HIPPS valve or valves. Two hydraulic fluid bleed off methods can be used to achieve rapid closure of the HIPPS valve or valves: (a) open hydraulic bleed off to the surrounding sea either via the subsea control module controlling the HIPPS valve or valves, or via a quick dump valve which is controlled by the subsea control module, and (b) closed hydraulic bleed off either from the HIPPS valve actuators to an external compensator and/or between the HIPPS valve actuator chambers.
The high-integrity pressure protection module may be made as an integral part of the X-mas tree such that it cannot be retrieved separately from the X-mas tree.
Alternatively, the high-integrity pressure protection module may be retrievably mounted on the X-mas tree.
The high-integrity pressure protection module may comprise at least one of:
a choke positioned in the flow path of the production fluid;
- a plurality of pressure transducers for monitoring the pressure of the production fluid;
a temperature transducer for monitoring the temperature of the production fluid; a multi-phase flow meter and/or a wet gas meter for monitoring the flow rate, the gas volume fraction and/or the wet gas content of the production fluid;
- hydraulic fluid bleed-off lines and/or control lines connectable to a subsea
control module of the X-mas tree;
a chemical injection valve;
a sand detector; and
a connection interface for connecting to a subsea control module of the X-mas tree.
The plurality of pressure transducers may comprise three pressure transducers positioned downstream of the choke for operation of the HIPPS and a pressure transducer positioned between the HIPPS barrier valves. Description of the drawings
In the following, the invention will be discussed in more detail with reference to the attached drawings.
Fig. 1 is a schematic representation of a X-mas tree supported by a subsea-founded structure, which X-mas tree comprises a high-integrity pressure protection module as an integral part.
Fig. 2 is a schematic representation of a X-mas tree supported by a subsea-founded structure and a retrievable valve module mounted on the X-mas tree, which retrievable valve module comprises a high-integrity pressure protection module. Fig. 3 is a schematic representation of a X-mas tree supported by a subsea-founded structure and a retrievable valve module mounted on the X-mas tree, which retrievable valve module comprises a high-integrity pressure protection module and a choke.
In the drawings, like reference numerals indicate like features unless otherwise stated.
Detailed description of the invention
Fig. 1 is a schematic representation of a subsea hydrocarbon fluid production system 101 comprising a seabed-founded structure 1 and a subsea X-mas tree, XT, 2 supported by the seabed-founded structure 1. As is well known in the art, the seabed-founded structure 1 comprises a structural framework and a foundation, e.g. driven/suction piles or a gravity-based foundation, arranged so as to provide support for the XT 2.
The XT 2 comprises a hydrocarbon fluid production conduit 3 emerging from a hydrocarbon well bore (not disclosed). The XT 2 comprises a surface controlled sub-surface safety valve, SCSSV, 4, a production master valve, PMV, 5 and a production wing valve, PWV, 6 mounted in the flow path of the production fluid. Downstream of the PWV 6, the XT comprises a choke 7a, 7b (two alternative positions of which are disclosed), a test and flowline isolation valve, TFIV, 8 and a flowline connection interface 9, all of which are arranged in the flow path of the production fluid.
As is known in the art, the flowline connection interface 9 provides a connection interface for a flowline (not disclosed) arranged to transport production fluid from the XT 2 to a downstream facility, e.g. a manifold, which is located at a distance from the XT 2 and, to the extent the downstream facility is seabed-founded, is supported by its own seabed-founded structure. The particulars and modus operandi of the valves 4, 5, 6, and 8 and the choke 7a, 7b are well known in the art and will not be discussed any further here. Also, as is known in the art, the XT 2 need not necessarily comprise all of the discussed equipment. For example, in some XT implementations the choke valve 7a, 7b and/or the TFIV 8 may be omitted.
As is known in the art, the XT 2 may comprise additional equipment for facilitating the hydrocarbon fluid production, e.g. valves for gaining access to the production conduit 3 and transducers for monitoring parameters relevant for the hydrocarbon fluid production. In the schematic representation of Fig. 1 , a cross-over valve, XOV, 10 and a chemical injection valve, CIV, 1 1 are disclosed, as is a pressure transducer 12 and a temperature transducer 13. However, as the skilled person is aware, additional equipment may be included in the XT 2.
The XT 2 comprises a high-integrity pressure protection module, HIPPS module, 14 which is arranged in the flow path of the production fluid between the PWV 6 and the flowline connection interface 9.
The HIPPS module 14 is arranged to protect the flowline (not disclosed) connected to the flowline connection interface 9 from the full shut-in tubing head pressure of the hydrocarbon well. This will allow the flowline to be rated to a pressure less than the full shut-in tubing head pressure. The HIPPS module 14 comprises two high-integrity pressure protection barrier valves 15, 16 which can be actuated between an open position and a closed position. The barrier valves 15, 16 are configured to be fail-safe close valves, such that any loss of electrical power and/or hydraulic pressure to the HIPPS module 14 will result in automatic closure of the barrier valves 15, 16. When in the closed position, the barrier valves 15, 16 isolate the flowline connection interface 9 and the flowline connected thereto from the shut-in tubing head pressure of the well.
To monitor the pressure and temperature of the production fluid, the HIPPS module 14 comprises a pressure transducer 17 positioned between the barrier valves 15, 16 as well as pressure transducers 18-20. Pressure transducer 21 and a temperature transducer 22 positioned downstream of the barrier valves 15, 16 are typical requirements as part of the normal production system and are not specifically required for operation of the HIPPS. Pressure transducers 18-20 are typically arranged to provide 2oo3 (2-out-of-3) voting whether or not to activate the HIPPS valves 15, 16. The TFIV 8 is positioned between the HIPPS module 14 and the flowline
connection interface 9, i.e. downstream of the HIPPS module 14. This will allow the TFIV 8 to double as a test valve for the barrier valves 15, 16 of the HIPPS module 14 and the production valves 5, 6, in addition to being used as an isolation valve for the flowline connection interface 9.
It may be advantageous if the TFIV 8 is a fail-safe closed valve, i.e. a valve which is actuated to a closed position in case of a failure. In such a case, the TFIV 8 may be utilised as a barrier valve to provide an isolation barrier between the production valves 5, 6 and the flowline connection interface 9 in addition to the barrier valves 14, 15 of the HIPPS module 14. In addition, or as an alternative, it may be advantageous if at least one of the production valves 5, 6 is configured to function as a HIPPS barrier valve. Using at least one of the PMV 5 and the PWV 6 as a HIPPS barrier valve will allow the HIPPS module 14 to be equipped with only one HIPPS barrier valve without deviating from the normal HIPPS requirement of having two HIPPS barrier valves between the high pressure rated and the low pressure rated sections of the hydrocarbon fluid production system.
Configuring any one of the PMV 5 and the PWV 6 as a HIPPS barrier valve will normally include configuring the valve to close within a specified timeframe upon detection of an abnormal situation, e.g. within two seconds.
The hydrocarbon fluid production system 101 may comprise a retrievable subsea control module, SCM, 23 arranged to control all of the valves of the XT 2, including the production valves 5, 6, the HIPPS barrier valves 15, 16, the XOV 10 and the CIV 1 1.
Alternatively, the hydrocarbon fluid production system 101 may comprise individually retrievable first and second SCMs 24a and 24b, wherein the first SCM 24a is arranged to control valves supported by the seabed-founded structure 1 which are safety critical, i.e. arranged to function as barrier valves, and the second SCM 24b is arranged to control valves supported by the seabed-founded structure 1 which are not safety critical, i.e. not configured to function as barrier valves. In the present embodiment, this would imply using SCM 24a to control the production valves 5, 6 and the HIPPS barrier valves 15, 16, and using SCM 24b to control the XOV 10 and the MIV 1 1. In the embodiment disclosed in Fig. 1 , the HIPPS module 14 is made as an integral part of the XT 2 and, consequently, cannot be retrieved independently from the XT 2.
Fig. 2 discloses an alternative embodiment of a hydrocarbon fluid production system 102 according to the invention. The system 102 shares features with the previously disclose system 101 and in Fig. 2 like reference numerals indicate like features. As compared to the embodiment disclosed in Fig. 1 , however, the HIPPS module 14 is retrievably mounted on the XT 2. This will allow the HIPPS module 14 to be disconnected from the rest of the X-mas tree structure. The retrievable HIPPS module 14 and the XT 2 comprise interfaces 26 and 27, respectively, allowing the retrievable HIPPS module 14 to be connected to and disconnected from the XT 2. The retrievable HIPPS module interface 26 comprises an upstream production fluid conduit interface 28 arranged for fluid communication with the production valves 5, 6, and a downstream production fluid conduit interface 29 arranged for fluid communication with the flowline connection interface 9, thus allowing the HIPPS barrier valves 15, 16 of the retrievable HIPPS module 14 to be connected in the flow path of the production fluid between the production valves 5, 6 and the flowline connection interface 9. Consequently, when the retrievable HIPPS module 14 is connected to the XT 2, the flow path of the production fluid will be routed though barrier valves 15, 16 of the retrievable HIPPS module 14, and when the retrievable HIPPS module 14 is disconnected from the XT 2, the flow path between the production valves 5, 6 and the flowline connection interface 9 will be open, but isolated through the closure of the TFIV 8 and the PMW 6.
In this embodiment, the choke 7 is positioned outside of the retrievable HIPPS module 14 upstream of interface 27. Pressure transducer 21 and temperature transducer 22 are also positioned outside of the retrievable HIPPS module 14, but downstream of interface 27. Consequently, the choke 7 and the transducers 21 and 22 will remain in the XT 2 when the retrievable HIPPS module 14 is disconnected from the XT 2.
In the same way as the hydrocarbon fluid production system 101 , the hydrocarbon fluid production system 102 may comprise an independently retrievable subsea control module, SCM, 23 arranged to control all of the valves supported by the seabed-founded structure 1 or, alternatively, individually retrievable first and second SCMs 24a and 24b, wherein the first SCM 24a is arranged to control valves supported by the seabed-founded structure 1 which are safety critical, and the second SCM 24b is arranged to control valves supported by the seabed-founded structure 1 which are not safety critical. Fig. 3 discloses a further embodiment of a hydrocarbon fluid production system 103 according to the invention. The system 103 shares features with the previously disclose systems 101 and 102, and, consequently, in Fig. 3 like reference numerals indicate like features.
In this embodiment the choke 7 is positioned inside the retrievable HIPPS module 14 downstream of the HIPPS barrier valves 15 and 16. Also, pressure transducer 21 and temperature transducer 22 are positioned inside the retrievable HIPPS module 14 downstream of the choke 7. Consequently, the choke 7 and the transducers 21 and 22 are retrievable together with the valve module 14, thus allowing also the choke 7 and the transducers 21 and 22 to be retrieved from the XT 2. It is to be understood, however, that the retrievable HIPPS module 14 of Figs. 2 and 3 may comprise additional components than those disclosed in the figures. For example, in addition to the disclosed components, the retrievable HIPPS module 14 may comprise at least one of a multi-phase flow meter and/or a wet gas meter and/or a single phase meter for monitoring the flow rate, the gas volume fraction and/or the wet gas content of the production fluid, hydraulic fluid bleed-off lines and/or control lines connectable to a subsea control module of the X-mas tree (2), a chemical injection valve, a sand detector and a connection interface for connecting to a subsea control module of the X mas tree (2), which equipment can give the retrievable HIPPS module flow control and/or monitoring functionality in addition to the HIPPS functionality.
In cases when the SCMs provide both electric and hydraulic functionality, the SCMs may advantageously be modularised such that the distribution of hydraulic functions and electric functions are effectuated via separate sub-modules. For example, the SCMs may comprise a power control router (not disclosed) arranged to effectuate the electric signals and a hydraulic control router arranged to effectuate the hydraulic signals, wherein at least one of the control routers is configured to control the HIPPS functionality of the hydrocarbon fluid production system.
In the preceding description, various aspects of the hydrocarbon fluid production system according to the invention have been described with reference to the illustrative embodiment. For purposes of explanation, specific numbers, systems and configurations were set forth in order to provide a thorough understanding of the apparatus and its workings. However, this description is not intended to be construed in a limiting sense. Various modifications and variations of the illustrative embodiment are possible within the scope of the present invention as defined in the following claims.

Claims

A subsea hydrocarbon fluid production system (101 , 102, 103) comprising:
- a seabed-founded structure (1);
- a X-mas tree (2) supported by the seabed-founded structure (1) comprising a production master valve (5), a production wing valve (6) and a flowline connection interface (9) arranged in a flow path of a hydrocarbon production fluid; and
- a high-integrity pressure protection system comprising a pair of high- integrity pressure protection barrier valves arranged to protect a flowline connected to the flowline connection interface (9) for transporting the production fluid from the X-mas tree (2),
characterised in that the high-integrity pressure protection system comprises a high-integrity pressure protection module (14) which is supported by the seabed-founded structure (1) and comprises a least one high-integrity pressure protection barrier valve (15, 16) positioned in the flow path of the production fluid between the production wing valve (6) and the flowline connection interface (9).
The subsea hydrocarbon fluid production system (101 , 102, 103) according to claim 1 , characterised in that the high-integrity pressure protection module (14) comprises a first high-integrity pressure protection barrier valve (15) and second high-integrity pressure protection barrier valve (16) which together form said pair of high-integrity pressure protection barrier valves.
The subsea hydrocarbon fluid production (101 , 102, 103) system according to claim 1 , characterised in that at least one of the production master valve (5) and the production wing valve (6) is configured as a high-integrity pressure protection barrier valve, which at least one high-integrity pressure protection barrier valve (15, 16) of the high-integrity pressure protection module (14) and at least one of the production master valve (5) and the production wing valve (6) together form said pair of high-integrity pressure protection barrier valves.
The subsea hydrocarbon fluid production system (101 , 102, 103) according to any one of claims 1 and 2, characterised in that the X-mas tree (2) comprises a test and flowline isolation valve (8) positioned in the flow path of the production fluid upstream of the flowline connection interface (9), and in that the at least one high-integrity pressure protection barrier valve (15, 16) of the high-integrity pressure protection module (14) is positioned upstream of the test and flowline isolation valve (8).
The subsea hydrocarbon fluid production system (101 , 102, 103) according to claim 4, characterised in that the test and flowline isolation valve (8) is configured as a fail-safe closed barrier valve.
The subsea hydrocarbon fluid production system (101 , 102, 103) according to any one of the preceding claims, characterised in that the subsea hydrocarbon fluid production system (101 , 102, 103) comprises a retrievable subsea control module (23) arranged to control all valves supported by the seabed-founded structure (1).
The subsea hydrocarbon fluid production system (101 , 102, 103) according to claim 6, characterised in that the subsea control module (23), during closure of the at least one high-integrity pressure protection barrier valve (15, 16) of the high-integrity pressure protection module (14), is arranged to be bleed off hydraulic fluid preventing said at least one high-integrity pressure protection barrier valve (15, 16) from closing.
The subsea hydrocarbon fluid production system (101 , 102, 103) according to any one of claims 1 to 5, characterised in that the subsea hydrocarbon fluid production system (101 , 102, 103) comprises:
a retrievable first subsea control module (24a) arranged to control the production master valve (5), the production wing valve (6) and the at least one high-integrity pressure protection barrier valve (15, 16) of the high- integrity pressure protection module (14);
and a retrievable second subsea control module (24b) arranged to control valves (10, 1 1) supported by the seabed-founded structure (1) which are not barrier valves.
The subsea hydrocarbon fluid production system (101) according to any one of the preceding claims, characterised in that the high-integrity pressure protection module (14) is made as an integral part of the X-mas tree (2) such that it cannot be retrieved separately from the X-mas tree (2).
10. The subsea hydrocarbon fluid production system (102, 103) according to any one of claims 1 to 8, characterised in that the high-integrity pressure protection module (14) is retrievably mounted on the X-mas tree (2).
. The subsea hydrocarbon fluid production system (102, 103) according to claim 10, characterised in that the retrievably mounted high-integrity pressure protection module (14) comprises at least one of:
a choke (7) positioned in the flow path of the production fluid;
a pressure transducer (17-21) for monitoring the pressure of the production fluid;
a temperature transducer (22) for monitoring the temperature of the production fluid;
a multi-phase flow meter and/or a wet gas meter and/or a single phase meter for monitoring the flow rate, the gas volume fraction and/or the wet gas content of the production fluid;
hydraulic fluid bleed-of lines and/or control lines connectable to a subsea control module mounted on the X-mas tree (2);
a chemical injection valve;
a sand detector; and
a connection interface for connecting to a subsea control module mounted on the X-mas tree (2).
12. An independently retrievable high-integrity pressure protection module (14) for use in the subsea hydrocarbon fluid production system (101 , 102) according to any one of claims 10 and 1 1 , characterised in that it comprises a least one high-integrity pressure protection barrier valve (15, 16) and a module interface (26) comprising an upstream production fluid conduit interface (28) arranged for fluid communication with the production valves (5, 6), and a downstream production fluid conduit interface (29) arranged for fluid communication with the flowline connection interface (9).
The independently retrievable high-integrity pressure protection module (14) according to claim 12, characterised in that it comprises at least one of:
a choke (7) positioned in the flow path of the production fluid;
a pressure transducer (17-21) for monitoring the pressure of the production fluid;
a temperature transducer (22) for monitoring the temperature of the production fluid; a multi-phase flow meter and/or a wet gas meter and/or a single phase meter for monitoring the flow rate, the gas volume fraction and/or the wet gas content of the production fluid;
a chemical injection valve;
a sand detector;
hydraulic fluid bleed-of lines and/or control lines connectable to a subsea control module mounted on the X-mas tree (2); and
a connection interface for connecting to a subsea control module mounted on the X-mas tree (2).
A method of providing a high-integrity pressure protection system (14) for protecting a flowline transporting a hydrocarbon production fluid from a subsea hydrocarbon fluid production system (101 , 102, 103) comprising:
- a seabed-founded structure (1); and
- a X-mas tree (2) supported by the seabed-founded structure (1) comprising a production master valve (5), a production wing valve (6) and a flowline connection interface (9) arranged in a flow path of the hydrocarbon production fluid, to which flowline connection interface (9) said flowline is connected;
characterised by the step of mounting a high-integrity pressure protection module (14) comprising at least one high-integrity pressure protection barrier valve (15, 16) so that it is supported by the seabed-founded structure (1) with said a least one high-integrity pressure protection barrier valve (15, 16) positioned in the flow path of the production fluid between the production valves (5, 6) and the flowline connection interface (9).
PCT/EP2017/071345 2016-08-24 2017-08-24 High-integrity pressure protection system WO2018037084A2 (en)

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