EP2651724A1 - Appareil et procédé pour système de protection à haute intégrité de têtes de puits groupées - Google Patents

Appareil et procédé pour système de protection à haute intégrité de têtes de puits groupées

Info

Publication number
EP2651724A1
EP2651724A1 EP11849689.2A EP11849689A EP2651724A1 EP 2651724 A1 EP2651724 A1 EP 2651724A1 EP 11849689 A EP11849689 A EP 11849689A EP 2651724 A1 EP2651724 A1 EP 2651724A1
Authority
EP
European Patent Office
Prior art keywords
zvs
hips
pressure
sets
closed
Prior art date
Legal status (The legal status 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 status listed.)
Withdrawn
Application number
EP11849689.2A
Other languages
German (de)
English (en)
Inventor
Patrick S. Flanders
Current Assignee (The listed assignees may be inaccurate. Google has not performed a legal analysis and makes no representation or warranty as to the accuracy of the list.)
Saudi Arabian Oil Co
Original Assignee
Saudi Arabian Oil Co
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 Saudi Arabian Oil Co filed Critical Saudi Arabian Oil Co
Publication of EP2651724A1 publication Critical patent/EP2651724A1/fr
Withdrawn legal-status Critical Current

Links

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
    • 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
    • E21B43/017—Production satellite stations, i.e. underwater installations comprising a plurality of satellite well heads connected to a central station
    • E21B43/0175—Hydraulic schemes for production manifolds

Definitions

  • the present invention relates to a method and an apparatus for the operation and testing of a high integrity protection system (HIPS) connected to a production pipeline system.
  • HIPS high integrity protection system
  • HIPS high integrity protection system
  • This is typically an electro -hydraulic system employing pressure sensors to measure the pressure in the pipes, which are used by the electronics of a control module to control the closure of a production pipe HIPS valve(s). This arrangement retains the high pressure within a short section of pipeline between the production tree and the HIPS valve which is capable of withstanding the pressure.
  • U.S. Patent No. 6,591,201 to Hyde discloses a fluid energy pulse test system in which energy pulses are utilized to test dynamic performance characteristics of fluid control devices and systems, like gas-lift valves. This test system is useful for testing surface safety valves in hydraulic circuits, but does not provide safety information of the overall system's ability to perform safety function.
  • U.S. Patent No. 6,880,567 to Klaver et al. discloses a system that includes sensors, a safety control system and shut off valves used for protecting downstream process equipment from overpressure. This system utilizes a partial- stroke testing method in which block valves are closed until a predetermined point and then reopened. This system, however, has to interrupt production for the diagnostic testing.
  • U.S. Patent No. 7,044,156 to Webster discloses a pipeline protection system in which pressure of fluid in a section of pipeline that exceeds a reference pressure of the hydraulic fluid supplied to a differential pressure valve, the differential pressure valve is opened, and thereby causes the hydraulic pressure in the hydraulically actuated valve to be released via a vent.
  • the protection system does not provide any valve diagnostic means and is forced to interrupt the production for shut off valves to be fully closed.
  • U.S. Patent No. 5,524,484 to Sullivan discloses a solenoid-operated valve diagnostic system which permits the valve user with the ability to monitor the condition of the valve in service over time to detect any degradation or problems in the valve and its components and correct them before a failure of the valve occurs. This system does not permit a testing of shut off valves without an interruption of production.
  • U.S. Patent No. 4,903,529 to Hodge discloses a method for testing a hydraulic fluid system in which a portable analyzing apparatus has a supply of hydraulic fluid, an outlet conduit, a unit for supplying hydraulic fluid under pressure from the supply to the outlet conduit, a return conduit communicating with the supply, a fluid pressure monitor connected to the outlet conduit, and a fluid flow monitor in the return conduit.
  • the analyzing apparatus disconnects the fluid inlet of the device from the source and connects the fluid inlet to the outlet conduit, and disconnects the fluid outlet of the device from the reservoir and connects that fluid outlet to the return conduit. Fluid pressure is monitored in the outlet conduit and the flow of fluid through the return conduit with the unit in place in the system. This method, however, requires that the production be interrupted for the testing of the hydraulic system.
  • U.S. Patent No. 4,174,829 to Roark, et al. discloses a pressure sensing safety device in which a transducer produces an electrical signal in proportion to a sensed pressure and a pilot device indicates a sensing out-of-range pressure when the sensed pressure exceeds a predetermined range, which permits an appropriate remedial action to be taken if necessary.
  • the device requires operators intervention.
  • U.S. Patent No. 4,215,746 to Hallden et al. discloses a pressure responsive safety system for fluid lines which shuts in a well in the event of unusual pressure conditions in the production line of the well. Once the safety valve has closed, a controller for detecting when the pressure is within a predetermined range is latched out of service and must be manually reset before the safety valve can be opened. The system results in an interruption of production and operators intervention.
  • Another object is to provide an apparatus and a method for automatically testing a HIPS without the intervention of an operator.
  • the unit is preferably provided with standardized flanges and is integrally constructed.
  • HIPS high integrity protection system
  • a group of flow lines feed into a gathering line, either joining the gathering line at a single point through a header, or joining the gathering line at multiple points along the gathering line.
  • a HIPS of the present invention has an inlet for receiving fluid flow from a portion of the gathering line upstream of the HIPS, and the HIPS has an outlet for connection to a portion of the gathering line downstream of the HIPS.
  • a HIPS is constructed as a skid-mounted integral system for transportation to the site where it is to be installed.
  • the HIPS comprises two sets of isolation valves (ZVs), two vent control valves (VCVS) and a safety logic solver.
  • ZVs isolation valves
  • VCVS vent control valves
  • a safety logic solver When the HIPS is used with a single wellhead flow line, the isolation valves are termed surface safety valves (SSVs).
  • SSVs surface safety valves
  • ZV isolation valve
  • the two sets of ZVs are in fluid communication with the inlet, and the two sets are in parallel with each other.
  • Each set of ZVs has two ZVs in series, and either one or both of the two sets of ZVs is operable as a path for fluid entering the inlet and passing through the HIPS outlet for the piping system.
  • Each of the VCVs is connected to piping intermediate the two sets of ZVs, and each of the VCVs is in fluid communication with a vent line, which upon opening of a VCV vents process pressure between the two ZVs.
  • the safety logic solver is in communication with the ZVs and the VCVs and produces signals to control the operation of the ZVs and VCVs.
  • the VCVs are preferably electrically operated.
  • the pressure sensing transmitters monitor the fluid pressure on a section of piping upstream of the HIPS outlet.
  • three pressure transmitters are provided on the outlet.
  • the logic solver is programmed to transmit a signal to close the ZVs upon an increase in pressure above a threshold value transmitted by at least two of the three pressure sensors. As will be apparent to one of ordinary skill in the art, more or less than three pressure sensors can be employed in this part of the system.
  • Each of the two VCVs is connected to a pipe that is in fluid communication with a common vent line.
  • the vent line can be connected to a reservoir tank or other storage or recirculating means.
  • Each set of ZVs is operable independently of the operation of the parallel set of ZVs.
  • Pressure sensing transmitters are positioned for monitoring the pressure between the ZVs in each of the two sets of ZVs.
  • the safety logic solver is programmed to maintain one set of the ZVs in an open position when the parallel set of ZVs is moved to a closed position from an open position during a full-stroke test.
  • the safety logic solver is programmed to measure and record the pressure between a pair of the closed ZVs during a tight shut-off test, and to open the VCV between the closed ZVs for a short period of time during the test to relieve or reduce the line pressure.
  • the safety logic solver is programmed to generate a failure signal during the tight shut-off test period if the pressure between the closed and vented ZVs rises above a predetermined threshold value following closing of the VCV.
  • the safety logic solver is programmed to designate the closed ZVs for use as an operating set of ZVs if, during the test period, the pressure between the closed ZVs does not rise above a predetermined threshold value.
  • VCVs are closed during normal operations and during a full-stroke test.
  • the HIPS of the invention further comprises manual shut-off valves positioned upstream and downstream of each of the parallel sets of ZVs, which can be used to isolate each of the ZV sets from the piping system, e.g., for maintenance, repairs and/or replacement of system components.
  • the ZVs are provided with electric failsafe valve actuators, whereby all of the valves are moved to a closed position in the event of a power failure. This would result in a termination of all fluid flow in the outlet pipe downstream of the HIPS.
  • this type of failsafe shut down would be coordinated with similar shut down requirements at the wellhead or elsewhere upstream of the HIPS.
  • a method is provided to test the operational safety of a HIPS that has an inlet for connection to a wellhead flow line and an outlet for connection to a downstream outlet pipe, with the outlet pipe connecting to a common gathering line.
  • the HIPS has first and second sets of isolation valves (ZVs) in fluid communication with the piping system, and the two sets are in parallel with each other.
  • ZVs isolation valves
  • Each set of ZVs has two ZVs in series, and the ZVs are operable in response to signals from a safety logic solver as was described in detail above.
  • the first set of ZVs moves from an open position to a closed position for a tight shut-off safety test while the second set of ZVs is open as a fluid path for the pipeline system.
  • a transmitter positioned between the closed ZVs transmits a signal to the safety logic solver that corresponds to the pressure of fluid in the piping between the two closed valves.
  • the VCV located between the closed set of ZVs vents the pressurized fluid between the closed ZVs at the beginning of the safety test.
  • the vented fluid is preferably passed to a reservoir.
  • An alarm signal is actuated if the first set of ZVs do not maintain the pressure in piping between the ZVs at or below a predetermined threshold level during a predetermined shut down time.
  • the pressure, e.g., in PSI, of the fluid in the section of piping between each set of ZVs is recorded before and during the safety shutoff testing of the valves.
  • a graphic display of the recorded pressure is preferably provided to assist operating personnel in evaluating the performance of the system in real time during the test.
  • the second set of ZVs remains open while the first set of ZVs return to the fully open position. If the first set of ZVs do not open fully, an alarm signal is actuated .
  • Each of the two sets of isolation valves is provided with a vent control valve (VCV).
  • VCV vent control valve
  • the VCV connected to the first set of ZVs opens for a predetermined period of time to effect the pressure venting after the first set of ZVs are fully closed.
  • the first set of ZVs are moved to the open position and the second set of ZVs are moved to the closed position.
  • the pressure between the ZVs of the second set of ZVs is measured and an alarm signal is actuated if the second set of ZVs do not maintain the pressure in the intermediate piping at or below a predetermined level.
  • a method is provided to test the operational safety of a HIPS that is placed along a common production pipeline that has upstream connections from a group of wellheads and their associated feeder pipes.
  • FIG. 1 is a schematic diagram of a high integrity protection system (HIPS) in accordance with the invention that is connected to a wellhead and a downstream pipeline;
  • HIPS high integrity protection system
  • FIG. 2 is a flowchart of the process steps for a tight shut-off test on the HIPS of FIG. 1;
  • FIG. 3 is a comparative illustrative graphic display illustrating both a satisfactory and a failed pressure test of a pair of isolation valves (ZVs) during the tight shut-off test;
  • FIG. 4 is a schematic illustration of a plurality of wellhead flow lines connected to a common gathering line in which certain flow lines include the HIPS of FIG. 1;
  • FIG. 5 is a schematic illustration of a plurality of wellhead flow lines connected to a header that in turn connects to a common gathering line, in which the gathering line includes the HIPS of FIG. 1.
  • a high integrity protection system (HIPS) 10 is installed in proximity to a wellhead in a piping system to convey a pressurized fluid product, such as oil or gas, from the wellhead 102 to a remote host location via pipeline 104.
  • the HIPS has an inlet 1 connected to the wellhead piping 102 and an outlet 2 connected to piping system 104 through which the liquid product enters and exits the HIPS 10.
  • the HIPS is preferably skid-mounted for delivery to the site of the wellhead and is provided with appropriate flanges and adapters, if necessary, for attachment to the inlet and outlet to the oil field piping.
  • ZVs isolation valves
  • Each set of ZVs identified and referred to as ZV- 1 and ZV-2, has two ZVs 11-12 and 13-14, respectively, which are connected in series.
  • the ZVs close automatically in the absence of power being supplied to them and are maintained in an open position by conventional hydraulically or electrically powered actuators to protect the downstream piping system 104 from abnormal operational conditions.
  • Two vent control valves (VCVs) 41, 42 are connected to the piping intermediate the two set of ZVs 11, 12 and 13, 14, respectively, and are in fluid communication with a vent line 106.
  • the vent line 106 is in fluid communication with a fluid reservoir 70 that serves as a closed collection system tank. Alternatively, the vent line can be routed to a burn pit (not shown) near the well site.
  • the VCVs 41, 42 upon their opening can vent pressurized fluid between the two ZVs into the vent line 106.
  • Valves 71, 72 and 81 control supply of hydraulic pressure by the pressure reservoir via their opening and closing.
  • pressurized nitrogen from the tank 80 forces fluid out of the reservoir 70, either into the HIPS pipeline or via valve 72 for alternate use or disposed.
  • the VCVs 41, 42 vent pressurized fluid from between the two ZVs into the vent line upon their opening.
  • Pressure sensing transmitters 54, 55 are located between the respective ZVs to determine the fluid pressure between the two ZVs. Multiple pressure sensing transmitters can optionally be installed at locations 54 and 55 to assure reliability and as back-ups to the test system.
  • Pressure sensing transmitters 51, 52, 53 are installed upstream of the outlet 2 to monitor the fluid pressure exiting the HIPS from outlet 2.
  • the three transmitters are monitored by the safety logic solver 31. If any two of three transmitters 51-53 sense a pressure rise above a predetermined threshold value, the logic solver 31 automatically shuts in the well via the ZVs 11-14, thereby protecting the downstream pipeline from excessive pressure.
  • a safety logic solver 31 which is preferably a software module preprogrammed in a computer or the like, is in communication with the ZVs 11-14, VCVs 41, 42, and pressure sensing transmitters 51-55 via a hard- wired connection or by wireless transmitters.
  • the safety logic solver 31 produces and transmits signals to control the operation of the ZVs 11-14 and VCVs 41, 42. The control is performed based on pressure data from the pressure sensing transmitters 51-55.
  • Manual valves 61-64 are installed between inlet 1 and outlet 2 and ZVs 11-14 to isolate the two sets of ZVs 11-14 from the piping system in case of an emergency and also so that the system can be shut down manually for repair and/or replacement of any of its components.
  • valves are operated by conventional valve actuators (not shown) such as those that are well known to art.
  • the valve actuators and pressure transmitters 51-55 have self- diagnostic capabilities and communicate any faults to the safety logic solver 31 that are detected.
  • the first set of ZVs 11, 12 are then opened to prepare for a test of the second set of ZVs 13, 14 (S 40). It is determined whether the first set of ZVs 11, 12 which are used as a fluid path during the shut-off test of the second set of ZVs 13, 14 are fully opened (S50). If the first set of ZVs 11, 12 are not fully opened, an alarm signal is actuated and the test is terminated (S60). If the first set of ZVs 11, 12 are fully opened, the second set of ZVs 13, 14 are closed (S70). The full closing of the ZVs 13, 14 to be tested are checked for the preparation of the tight shut-off test (S80). If the ZVs 13, 14 are not fully closed, an alarm signal is actuated (S90) and the test is terminated.
  • VCV 42 is then closed and the pressure sealing of VCV 42 is checked (SI 10). If the VCV 42 is not fully closed, or the valve is leaking so that pressure continues to drop in the vented section of pipe between the valves, an alarm signal is actuated (S120) and appropriate remedial action is taken. If the VCV 42 is fully closed, the pressure between the ZVs 13, 14 is measured (S130). The pressure between the ZVs 13, 14 continues to be monitored by the pressure transmitter 55 and the result is sent to the safety logic solver 31 during the tight shut-off test up to the end of the tight shut-off test period (S140).
  • the pressure rises above the threshold level it indicates a failure in the ability of the ZVs 13, 14 to seat completely and an alarm signal is actuated by the safety logic solver 31 which notifies of the failure of the tight shut-off test of the ZVs 13, 14 (S160).
  • the second set of ZVs 13, 14 pass the tight shut-off test.
  • the second set of ZVs 13, 14, which passed the tight shut-off test are opened again and used as a fluid path (SI 80).
  • the present invention enables the HIPS to operate continuously as a fluid path while a tight shut-off and a full-stroke test is performed, and while any necessary protective action can be taken.
  • the automatic operation by the safety logic solver assures that emergency shut-off conditions will be carried out, even during a test.
  • a record of the test is stored and can be recovered later or displayed electronically and/or in printed graphic form or as tabulated data.
  • a system 400 includes a plurality of wellhead flow lines 402 and 402' that are typically connected to a common gathering line to transport oil/gas from wells to a gas oil separation plant (GOSP) 404.
  • Flow lines 402 each include associated therewith a HIPS 406, e.g., including an SLS, pressure transmitters and ZVs as shown in FIG. 1.
  • High pressure rated piping is used between each well and the ZV of the associated HIPS 406, and conventional piping is used downstream of the ZV of the HIPS 406, which is rated for a lower pressure and suitable for the transportation and distribution of the product.
  • additional wellhead flow lines 402' are provided that do not show an associated HIPS 406, although other protection and/or safety systems can be used for these wellheads as is within the ordinary skill of one in the art.
  • a system 500 includes a plurality of wellhead flow lines 402, 402' and 502 that are typically connected to a common gathering line to transport the oil/gas to a gas oil separation plant (GOSP) 404.
  • Wellhead flow lines 402 and 402' join the gathering line at individual points on the gathering line.
  • Flow lines 402 are each provided with a HIPS 406, e.g., including an SLS, pressure transmitters, and ZVs as shown in FIG. 1.
  • HIPS 406 e.g., including an SLS, pressure transmitters, and ZVs as shown in FIG. 1.
  • Flow lines 402' are not protected by a HIPS 406, although other protection and/or safety systems can be used for these wellhead flow lines, as is within the ordinary skill of one in the art.
  • Additional flow lines 502 do not join the gathering line at individual points on the gathering line, but rather are connected to a common header 508, the outlet of which connects to a single point on the gathering line.
  • the upstream piping and HIPS 506 is fully rated for the connected high-pressure wells.
  • the HIPS 506 protects the downstream piping, which can therefore be specified as lower-pressure pipe.

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  • Life Sciences & Earth Sciences (AREA)
  • Engineering & Computer Science (AREA)
  • Geology (AREA)
  • Mining & Mineral Resources (AREA)
  • Physics & Mathematics (AREA)
  • Environmental & Geological Engineering (AREA)
  • Fluid Mechanics (AREA)
  • General Life Sciences & Earth Sciences (AREA)
  • Geochemistry & Mineralogy (AREA)
  • Pipeline Systems (AREA)
  • Examining Or Testing Airtightness (AREA)

Abstract

L'invention porte sur un système de protection à haute intégrité (IHPS) pour la protection d'une ligne de groupement en aval d'un certain nombre de lignes d'écoulement de têtes de puits, lequel système comprend : une entrée ; une sortie ; deux ensembles de deux vannes d'isolation reliées en série (ZV) en communication vis-à-vis des fluides avec l'entrée et la sortie, les deux ensembles étant en relation d'écoulement vis-à-vis des fluides parallèlement l'un par rapport à l'autre, soit l'un soit les deux des ensembles de vannes d'isolation reliées en série pouvant fonctionner comme trajectoire pour un fluide entrant dans l'entrée et passant à travers la sortie vers le tuyau aval ; deux vannes de commande d'évacuation (VCV), reliées chacune à une tuyauterie entre un ensemble de vannes d'isolation reliées en série, les vannes de commande d'évacuation étant en communication vis-à-vis des fluides avec une ligne d'évacuation, ce par quoi, lors de l'ouverture d'une vanne de commande d'évacuation, une pression de traitement entre les deux vannes d'isolation est évacuée ; un dispositif de résolution de logique de sécurité générant un signal, en fonction de protocoles de sécurité et de fonctionnement préprogrammés ; et des dispositifs de transmission de détection de pression attachés à une tubulure en amont de la sortie du système de protection à haute intégrité. Le système permet un test de fermeture hermétique de pleine course des vannes d'isolation sans interruption de la production des têtes de puits.
EP11849689.2A 2010-12-17 2011-12-15 Appareil et procédé pour système de protection à haute intégrité de têtes de puits groupées Withdrawn EP2651724A1 (fr)

Applications Claiming Priority (2)

Application Number Priority Date Filing Date Title
US201061424339P 2010-12-17 2010-12-17
PCT/US2011/065199 WO2012083040A1 (fr) 2010-12-17 2011-12-15 Appareil et procédé pour système de protection à haute intégrité de têtes de puits groupées

Publications (1)

Publication Number Publication Date
EP2651724A1 true EP2651724A1 (fr) 2013-10-23

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Family Applications (1)

Application Number Title Priority Date Filing Date
EP11849689.2A Withdrawn EP2651724A1 (fr) 2010-12-17 2011-12-15 Appareil et procédé pour système de protection à haute intégrité de têtes de puits groupées

Country Status (7)

Country Link
EP (1) EP2651724A1 (fr)
CN (1) CN103328288A (fr)
BR (1) BR112013015080A2 (fr)
CA (1) CA2822052A1 (fr)
EA (1) EA201390896A1 (fr)
MX (1) MX2013006829A (fr)
WO (1) WO2012083040A1 (fr)

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Publication number Priority date Publication date Assignee Title
NO342625B1 (en) * 2016-08-24 2018-06-25 Fmc Kongsberg Subsea As High-integrity pressure protection system and associated method
CN106761622B (zh) * 2017-03-23 2023-03-10 西安长庆科技工程有限责任公司 一种空气泡沫驱采油井场装置及其工艺
CN106836175B (zh) * 2017-03-28 2019-01-22 罗淮东 一种适用于雨季期间丛式井平台的施工方法
CN114383554B (zh) * 2021-11-29 2023-08-22 海洋石油工程股份有限公司 一种水下hipps下游高压段海底管道长度计算方法

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Publication number Priority date Publication date Assignee Title
US4934652A (en) * 1989-12-11 1990-06-19 Otis Engineering Corporation Dual stage valve actuator
US7905251B2 (en) * 2006-12-29 2011-03-15 Saudi Arabian Oil Company Method for wellhead high integrity protection system
US8161993B2 (en) * 2008-09-23 2012-04-24 Chevron U.S.A. Inc. Subsea system and method for protecting equipment of a subsea system

Non-Patent Citations (1)

* Cited by examiner, † Cited by third party
Title
See references of WO2012083040A1 *

Also Published As

Publication number Publication date
MX2013006829A (es) 2014-01-31
WO2012083040A1 (fr) 2012-06-21
BR112013015080A2 (pt) 2016-08-09
EA201390896A1 (ru) 2014-11-28
CA2822052A1 (fr) 2012-06-21
CN103328288A (zh) 2013-09-25

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