Manifold system for oil production with SV line and central multiphase metering module, and commissioning method

Abstract

The present invention relates to a manifold system for oil production, comprising an SV line and a central multiphase metering module. This system comprises a crossover module (MXO), five umbilical termination modules (MTU), a hydraulic distribution and chemical injection unit (CDHIQ), four choke modules, service lines (SV), gas lift (GL) lines, oil production lines (PO), and a central multiphase metering module (MPFM). The present invention also relates to a method for commissioning the central multiphase metering module in this system, which involves steps, such as circulating diesel, performing leak tests using an ROV, and removal of the central module. The present invention further relates to a method for commissioning a choke module via a service line that involves the following steps and their respective sub-steps: injection and first circulation of diesel; second circulation of diesel; third circulation of diesel; circulation of water; and removal of choke module.

Description

OIL PRODUCTION MANIFOLD SYSTEM WITH SV LINE AND CENTRAL MULTIPHASE MEASUREMENT MODULE AND COMMISSIONING METHOD FIELD OF THE INVENTION

[0001] The present invention falls within the technical field of oil and gas production and transportation, especially in offshore exploration operations.

[0002] More specifically, the invention focuses primarily on a system of subsea equipment used in the oil and gas industry. This system features changes aimed at improving the efficiency, safety, and economy of subsea production operations through strategies such as optimizing equipment architecture, flow control, well monitoring, and commissioning operations for component replacement. BACKGROUND OF THE INVENTION

[0003] Oil production manifold systems are fundamental for managing the extraction and distribution of oil from the well to the stationary production unit (SPU).

[0004] These manifold systems play a crucial role in facilitating efficient and safe operation on offshore oil production platforms. By pooling and controlling the flow of oil from wells to the FPSO (typically 4 wells, but not limited to this number), subsea production manifolds (SPMs) help optimize production and reduce the CAPEX (capital expenditure) of the subsea system, minimizing downtime and maximizing oil recovery.

[0005] Furthermore, they ensure the integrity of the process by monitoring and regulating fluid pressures and temperatures. throughout the entire production process. The effective implementation of these systems not only increases productivity but also reduces operational and environmental risks, thus contributing to the long-term sustainability and profitability of oil exploration operations.

[0006] Current systems generally have four lines that go to the power plant: oil production line (OP); gas-lift line (GL); oil production test line (OPT); and gas-lift test line (GLT); in addition to the control umbilical.

[0007] This type of architecture (also called "standard") offers good flexibility for testing, using TPO and TGL lines to individually test wells, verifying what is produced and what is injected into each well. However, in cases of failures in its multiphase metering modules, this type of system presents significant difficulties for replacement, leading to the need for a complete interruption of equipment production (shutdown of 4 producing wells in typical architectures) for the complete replacement of a choke module. This generates a loss of efficiency due to the production stoppage (lost profit), in addition to the costs of implementing a system with the aforementioned subsea lines.

[0008] Thus, the technical problem solved by the present invention consists of providing a system: a- that has a reduced number of lines; b- that allows the replacement of a choke module without interrupting the production of the entire equipment; c- that has a greater number of MEG injection points for hydrate dissociation operations; d- that allows ROV access to the equipment, providing greater flexibility for hydrate dissociation operations, both with local depressurization and with MEG injection via ROV; e- that features a central multiphase measurement module, which can receive production from wells where there has been a failure in the multiphase measurement module of the respective well, avoiding interruptions in overall production.

[0009] Consequently, the present invention increases the availability and efficiency of the system. In a single application of the invention, the gain is approximately USD 19,000,000.00 (nineteen million dollars). In a typical project, the estimated gain is approximately USD 76,000,000.00 (seventy-six million dollars).

[0010] Overall, the invention provides a direct reduction in CAPEX for the subsea system by eliminating a pipeline and increasing equipment availability compared to the previous standard (from 98% to 99.8%), which is significant for a conventional design (Marlim or SRR). SUMMARY OF THE INVENTION

[0011] The present invention relates to an oil production manifold system with only 3 lines (Service, Production and gas-lift, reducing one pipeline compared to the standard architecture, in addition to the control umbilical, common to both architectures). This system further comprises: a crossover module (MXO); five umbilical termination modules (MTU), one receiving the trunk umbilical coming from the UEP while the other four distribute control to the ANMs; a hydraulic and chemical injection distribution box (CDHIQ); four Choke modules containing multiphase meters; service header and branches (SV); gas-lift header and branches (GL); oil production header and branches (PO), and a central multiphase metering module (MPFM).

[0012] Furthermore, the present invention also encompasses a method for commissioning the central multiphase measurement module in this system, which involves steps such as diesel circulation, conducting leak tests with the aid of an ROV, and removing the module.

[0013] The architecture with a central multiphase metering module allows that, in case of failure of one of the multiphase meters present in the choke modules, the production of the failed module is redirected to the central module, postponing the need to replace the equipment and increasing its availability. BRIEF DESCRIPTION OF THE DRAWINGS

[0014] The present invention will now be described with reference to typical embodiments thereof and with reference to the accompanying drawings, in which:

[0015] Figure 1 is a representation of the state-of-the-art (“standard”) oil production manifold system for four wells, with 4 interconnecting pipelines to the FPSO plus a control umbilical.

[0016] Figure 2 is a representation of the oil production manifold system for four wells with a central multiphase metering module (highlighted) according to the present invention, and 3 interconnecting pipelines with the UEP plus control umbilical.

[0017] Figure 3 is a representation of the choke modules according to the present invention.

[0018] Figure 4 is a representation of the crossover module according to the present invention.

[0019] Figure 5 is a representation of the flows in the manifold, as well as the situation of its valves according to the present invention, when the flow is directed to the central measuring module (meter failure in the choke module).

[0020] Figure 6 is a representation of the flows in the manifold, as well as the status of its valves in operation with a local multiphase measurement module under normal operating conditions.

[0021] Figure 7 is a representation of the completed stage 1 of commissioning for removal of the central multiphase metering module according to the present invention (diesel circulation).

[0022] Figure 8 is a representation of the completed stage 2 of commissioning for removal of the central multiphase metering module according to the present invention (water circulation).

[0023] Figure 9 is a representation of the completed stage 3 of commissioning for removal of the central multiphase measurement module according to the present invention (VR-PO4 valve test).

[0024] Figure 10 is a representation of the completed stage 4 of commissioning for the removal of the central multiphase measurement module according to the present invention (leak test of valves VR-07 and VR-08 via Service Line and central module ready to be removed).

[0025] Figure 11 is a representation of the flows inside the choke module during production, as well as the the condition of its valves in normal operation according to the present invention.

[0026] Figure 12 is a representation of the completed stage 1 of commissioning for removal of the choke module according to the present invention (1st diesel circulation).

[0027] Figure 13 is a representation of the completed stage 2 of commissioning for removal of the choke module according to the present invention (2nd diesel circulation).

[0028] Figure 14 is a representation of the completed stage 3 of commissioning for removal of the choke module according to the present invention (3rd diesel circulation).

[0029] Figure 15 is a representation of the completed stage 4 of commissioning for removal of the choke module according to the present invention (water circulation).

[0030] Figure 16 is a representation of the choke module filled with water and ready to be recovered according to the present invention.

[0031] Figure 17 is a representation of one of the wells where the choke module was removed according to the present invention and a blocking cap was installed in its place. DETAILED DESCRIPTION OF THE INVENTION SYSTEM ARCHITECTURE

[0032] The present invention proposes a system comprising an oil production manifold with a Service, Production and gas-lift line and a central multiphase metering module. This type of architecture, when compared with the architecture of the prior art equipment, as shown in Figure 1, presents the following advantages: a. it eliminates the TPO and TGL lines, which are replaced by a service line (LS), connecting the manifold to the a. UEP, resulting in reduced CAPEX by eliminating a pipeline, as well as decreasing the complexity of the subsea layout; b. allows production to be diverted to the central multiphase metering module in case of failures in the multiphase metering module located in one of the choke modules; c. also allows the replacement of a choke module without needing to stop all equipment (as occurred in the standard architecture); d. reduces the number of crossover modules (XO) from 2 (standard architecture) to 1; e. allows the replacement of the MXO without stopping equipment production (as occurred in the standard architecture); f. In addition to the advantages above, the architecture features valves with ROV access, where local depressurization is possible for hydrate dissociation, which also increases operational availability.

[0033] In more detail, Figure 1 illustrates the state-of-the-art system typically applied to four wells. In this case, four lines are used: PO, GL, TPO, and TGL. Furthermore, considering the system's complexity, it is necessary to use two MXO modules (MXO1, MXO2), which allow fluid circulation between the headers, enabling hydrate dissociation and commissioning operations.

[0034] As shown in Figure 2, the system has a central multiphase measurement module (MPFM) – the dotted part within the red square – which serves to temporarily replace a local MPFM of a choke module. In case of failure. This inclusion implies a more robust system, which does not necessarily require an instantaneous replacement of the choke module due to failures in the local MPFM, allowing more time to schedule this procedure.

[0035] Thus, the system of the present invention is composed of the following structures: a crossover module (MXO); four choke modules, each with a local multiphase meter (MPFM) and a local single-phase meter; five Umbilical Termination Modules (MTU); a Hydraulic and Chemical Injection Distribution Box (CDHIQ); a service header (and branches) (SV); a gas-lift header (and branches) (GL); an oil production header (and branches); and a central multiphase metering module (MPFM), in addition to the meters in the choke modules; valves for ROV access for depressurization and MEG injection.

[0036] Furthermore, the system features resident valves (RV) actuated via ROV and remotely actuated hydraulic valves (HV), whose configuration and procedure allow for the replacement of a choke module without impacting other wells in operation.

[0037] As can be seen in Figure 3, which illustrates a choke module of one of the wells, with the operation of the valves at the choke module inlet: VR-GL1, VR-GL2, VR-PO1, VR-PO2 and VR-SV-1 are normally open, while valves VR-PO3, VR-PO4 and VR-GL3 are normally closed. Thus, it is necessary to The use of an ROV to change the state of these valves in order to perform specific operations.

[0038] The present invention also features a MEG / ethanol injection system to inhibit hydrate formation in the equipment, represented by the Umbilical Termination Module (MTU), the Hydraulic and Chemical Injection Distribution Box (CDHIQ), and the jumpers used to connect the MTU to the CDHIQ and to distribute the hydrate inhibitor from the CDHIQ to the choke modules.

[0039] In this regard, the system includes MQC (Multi Quick Connector) interfaces between the resident valves (VR), for access by ROV, which can be used for hydrate dissociation (by depressurization) and for leak testing of the resident valves at the choke module inlets.

[0040] To allow the uninterrupted operation of the other wells in the system during the replacement of one of the choke modules, four steps must be followed. The procedure must be carried out through circulation via ANM, according to the choke module that needs to be replaced. In this sense, cleaning procedures are performed with diesel injection and circulation, followed by water circulation, which are conducted to allow the recovery of the choke module.

[0041] It is also worth highlighting that the positioning of the VH-PO1 and VH-GL1 hydraulic valves aims to prevent the circulation of larger volumes of dead oil through the gas-lift choke during cleaning and commissioning operations, which was one of the causes of wear and clogging by particulates in this type of device in prior art approaches.

[0042] Access from the SV line to the GL line via the VR-GL3 valve is important for cleaning that section. which runs from VR-GL1 to VH-GL1 without requiring the circulation of large volumes of dead oil through the gas-lift choke. Access from the SV line to the PO line via the VR-PO3 valve allows for the diversion of well production passing through the meter to the SV line. In the UEP, this SV line can be aligned to the test guide, thus providing a way to individually test the MPFM. This option was not possible in previous architectures.

[0043] Figure 4 shows a detailed view of the crossover module (MXO), with the nomenclature adopted for the valves and MEG injection points. It can be observed that two resident manual valves were added to the MXO inlet on the PO and GL headers, allowing the MXO to be replaced without stopping production of the equipment.

[0044] A MEG injection point was considered at the upper generatrix of the MXO (loop) piping, downstream of the XV-01 valve. MQC interfaces for the ROV were added between the valves located at the inlet of the GL and PO headers. The objective is to use these access points to conduct valve leak tests, allowing the removal of the XO module without halting manifold production, as well as serving as depressurization points for hydrate dissociation.

[0045] Additionally, in case of any failures in the local MPFM of one of the choke modules, it is possible to divert production using the central multiphase measurement module, as presented in the following sequence of steps: I. Initial situation: production coming from the ANM passing through valves VH-PO1, VR-PO2 and VRPO-1; II. Via ROV, close the resident manual valve VR-PO1 and open VR-PO4, diverting production; III. Via ROV, open the resident manual valves VR-06, VR-07, and VR-08 on the central multiphase metering module line, so that the previous sequence allows production to pass through the central multiphase metering module to the PO line header, joining the production from the other wells, as shown in Figure 5. COMMISSIONING METHOD CHOKE MODULE

[0046] A operação dos poços e equipamentos ocorre após procedimento de comissionamento, iniciando a produção para uma UEP existente. A invenção permite o comissionamento do módulo de choke através da linha de Serviço. Nessa operação a válvula VR- PO4 no acesso para o módulo de medição central fica fechada durante todo o procedimento. A Figura 11 apresenta um dos módulos de choke, mostrando os fluxos durante a produção normal do MSP. Também é destacado o status das válvulas do módulo e da ANM produzindo para o módulo em questão, onde as válvulas de acesso da linha de SV para as linhas de GL e PO (válvulas residentes VR-GL3 e VR-PO3, e válvulas hidráulicas VH-GL2 e VH-PO2) permanecem fechadas (estado inicial).

[0047] The hydrocarbon flow from the well follows this path through the valves: I. DHSV valve open; II. M1 and W1 valves open; III. VH-PO1, VR-PO2, and VR-PO1 valves open; IV. Arrival of the produced fluid at the PO header, and direction to the production line and UEP. The gas-lift circuit in the well follows the sequence from the GL header to the well annulus: I. Gas passes through the gas-lift header, being directed to each well by the gas-lift branches; II. Passage through the VR-GL1, VR-GL2, and VH-GL1 valves open; III. Gas passes through the W2 and M2 valves in the ANM open.

[0048] Now, we will consider the situation where, during normal equipment production, one of the Multiphase Meters stops operating, requiring its replacement. One of the major advantages of the proposed MSP architecture is that it eliminates the need to interrupt the entire manifold production process to clean and replace one of the choke modules.

[0049] Figures 12 to 15 again show one of the Choke Modules, presenting the state of the module's valves and the ANM connected to this module as the cleaning procedures with diesel injection and circulation, followed by water circulation, are conducted to allow the recovery of the Choke Module. The flowcharts represent the steps with diesel injection. Water injection should be done later, following a very similar sequence of steps. The procedure must obviously be done by ANM, according to the Choke Module that needs to be replaced.

[0050] Initially, it is necessary to stop production at the well in question and interrupt the gas-lift flow through the well annulus. This procedure will be divided into four stages: stage 1; stage 2; stage 3; and stage 4.

[0051] Step 1 comprises the following operations: I. Using the UEP, close valves VH-GL1, M1, and M2, interrupting gas-lift injection and production at the well; II. Using the UEP, open valves VH-GL2 and XO; III. Inject diesel through the service header, passing through the open valve VR-SV1 and entering the Choke Module; IV. Circulate diesel through the service line access to the gas-lift line via the open valve VHGL2. The diesel enters the GL line at a point downstream of valve VH-GL1. This is important because it prevents the circulation of large volumes. Diesel / dead oil from the gas-lift choke, which could have some orifice clogged by particulates; V. Circulate diesel through the ANM, entering the ANM through the GL line, passing through valves W2, XO, W1 and returning through the production line; VI. Diesel passing through the open valves VH-PO1, VR-PO2 and VR-PO1 and returning diesel through the production header, being carried along with the production from the other three wells in operation; VII. End of Stage 1.

[0052] Stage 2 comprises the following operations: VIII. Via UEP, open PXO and close valves W1, XO, and W2; IX. Circulate diesel through the gas-lift line, PXO, and returning through the PO line; X. With ROV, close valve VR-GL1 and open valve VR-GL-3; XI. Via UEP, open valve VH-GL1 and close VH-GL2; XII. Circulate diesel in the circuit VR-SV1 – VR-GL3 – VR-GL2 – VH-GL1 – PXO – VH-PO1 – VR-PO2 – VR-PO1, being carried by the PO header along with the production from the other wells; XIII. End of Stage 2.

[0053] Step 3 comprises the following operations: XIV. Via UEP, open the VH-PO2 valve, close the VH-GL1 and PXO valves; XV. Circulate diesel in the VR-SV1 – VH-PO2 – VH-PO1 – VR-PO2 – VR-PO1 circuit, being carried by the PO header along with the production from the other wells; XVI. Via ROV, open VR-PO3; XVII. Via UEP, close the VH-PO2 valve; XVIII. Diesel fuel circulates in the VR-SV1 – VR-PO3 – VR-PO1 circuit, being carried by the PO header along with the production from the other wells; XIX. End of Stage 3.

[0054] Step 4 consists of water circulation operations similar to the previous ones, however, without water circulation in the W2 – XO – W1 circuit. The final situation after water circulation should be as shown in Figure 15, with the resident valves VR-GL1, VR-GL2, VR-PO1 and VR-PO2 closed: XX. After the commissioning steps described above, with the module filled with water, a leak test of the resident valves at the module inlets (VR-GL1, VR-GL2, VR-PO1 and VR-PO2) must be performed. This test can be done in two ways: a. Via ROV, through the MQC accesses between the valves (valve VR-GL1 and VR-PO1 will be tested for leakage into the header, and valves VRGL2 and VR-PO2 for leakage out of the manifold). b. Via SV line, pressurizing through valves VR-GL3 and VR-PO3, and monitoring the pressure through the Pressure Transmitters present in the Module. XXI. Following the previous test, close valves VR-GL3, VR-PO3, and VR-SV1 via ROV. XXII.The Choke Module is commissioned, filled with water, and ready for recovery, as can be seen in Figure 16.

[0055] After removing the Choke Module, if it is not immediately replaced with a new Module and the boat has to leave the location, it is necessary to install a locking cover to meet a permanent condition, as can be seen in Figure 17. MPFM Central Commissioning Method:

[0056] When deemed necessary, commissioning of the system's central multiphase metering module can be carried out without disrupting operation, following these steps: diesel circulation; first leak test; second leak test; third leak test; and removal of the module with the aid of an ROV.

[0057] The commissioning procedure for the central multiphase metering module allows for its replacement without interrupting production from any of the four wells connected to the manifold. The diesel and water passing through the central multiphase metering module are carried along with the well production to the production header.

[0058] Starting from the normal operating situation of the choke module, as shown in Figure 6, with well production flowing through the wet Christmas tree (WCT) and choke module (via valves VH-PO1, VR-PO2 and VR-PO1) towards the production header, the procedure for commissioning the central multiphase metering module is performed as follows: Diesel Circulation

[0059] I. Via ROV, open the resident manual valve VR-09 on the service header access to the trunk line at the output of the central multiphase metering module.

[0060] II. Using the ROV, open the resident manual valves VR-07, VR-06, and VR-PO4, while valve VR-08 remains closed.

[0061] III. Via UEP, inject diesel through the service header.

[0062] IV. Circulate diesel fuel through the central multiphase metering module, passing through valves VR-09, VR-07, VH-PO1, VR-06 and VR-PO4.

[0063] V. Diesel fuel is added to the well production, being carried by the PO header via VR-PO1.

[0064] With this, the entire volume of the central multiphase measurement module was circulated with diesel, as can be seen in Figure 7. First leak test.

[0065] VI. Via UEP, circulate water through valves VR-09, VR-07, VH-PO1, VR-06 and VR-PO4, removing diesel from the central multiphase metering module.

[0066] VII. With the module filled with water, perform a leak test on the valves located at the inlet of the central multiphase metering module, namely VR-PO4, VR-07 and VR-08.

[0067] VIII. Perform the leak test on the VR-PO4 valve. Using an ROV, close the VR-PO4 valve, and with water injection through the SV line access, test the leak tightness of the VR-PO4 valve towards the choke module, as shown in Figure 8. Second leak test

[0068] IX. Temporarily interrupt production at the well connected to the choke module in question to test the tightness of the VR-PO4 valve towards the central multiphase measurement module; Close the VR-PO2 and VR-PO1 valves via ROV.

[0069] X. Using an ROV, perform a leak test on the VR-PO4 valve towards the central multiphase measurement module via the MQC access between the VR-PO2 and VR-PO1 valves. As shown in Figure 9. In case of a positive test result (verification via the ROV's own pump), well production is resumed by opening VR-PO2 and VR-PO1 via the ROV. Third leak test

[0070] XI. Test valves VR-07 (towards the central multiphase measurement module) and VR-08; Close valves VR-06 and VR-07 via ROV.

[0071] XII. Through the SV Line access, pressurize with water using valve VR-09 and monitor the pressure using the pressure transmitter of the central multiphase measurement module, as can be seen in Figure 10.

[0072] XIII. With a positive result, close valve VR-09 with ROV.

[0073] After these procedures, the central multiphase metering module is filled with water and ready to be recovered, without affecting the production operation of the other wells.

Claims

CLAIMS 1. Oil production manifold system with SV line and central multiphase metering module, characterized in that it comprises: a crossover module (MXO); five umbilical termination modules (MTU); a hydraulic and chemical injection distribution box (CDHIQ); four choke modules; service lines (SV); gas-lift lines (GL); oil production lines (PO); and a central multiphase metering module (MPFM). 2.System, according to claim 1, characterized in that valves VR-01, VR-02, VR-03, VR-04, VR-05, XV-01, XV-E01 and XV-E02 influence the operation of the crossover module as follows: valve VR-01 – is responsible for hydraulic isolation between the MXO and the service header; valve VR-02 – is responsible for double-barrier hydraulic isolation between the MXO and the gas lift header; valve VR-03 – is responsible for double-barrier hydraulic isolation between the MXO and the gas lift header; valve VR-04 – is responsible for double-barrier hydraulic isolation between the MXO and the production header; valve VR-05 – is responsible for double-barrier hydraulic isolation between the MXO and the production header; The XV-01 valve – responsible for allowing circulation between the service header and the production header; the XV-E01 valve – responsible for MEG injection into the MXO.

1. The XV-E02 valve – responsible for MEG injection into the MXO.

2. System, according to claim 1, characterized in that the umbilical termination modules (MTU) coordinate the distribution of control and MEG / ethanol from the UEH trunk to the CDHIQ and from the manifold to the ANMs.

3. System, according to claim 1, characterized in that at the choke module input there is a VR-PO4 bypass valve directed to the central multiphase measurement module (MPFM).

4. System, according to claim 1, characterized in that the central multiphase measurement module comprises (the VR valves are at the inputs of the central measurement module but are resident in the manifold): a pressure transducer; a temperature transducer; a VH-01 valve; a VR-06 valve; a VR-07 valve; a VR-08 valve; and a VR-09 valve. 5.System according to claim 1, characterized in that the choke module comprises: a service line (SV); a gas-lift line (GL); and an oil production line (PO).

7. System according to claim 1, characterized in that the service line (SV) in each choke module further comprises: a VR-SV1 valve, a VH-GL2 valve and a VH-PO2 valve.

8. System according to claim 1, characterized in that the gas-lift (GL) line of the choke module further comprises: a VR-GL1 valve; a VR-GL2 valve; a VH-GL1 valve; a single-phase meter (SPFM); a gas-lift choke; three pairs of pressure and temperature transducers.

9. System according to claim 1, characterized in that the oil production (PO) line of the choke module further comprises: a VR-PO1 valve; a VR-PO2 valve; a VH-PO1 valve; a local multiphase meter (MPFM); an oil production choke; three pairs of pressure and temperature transducers.

10. System according to any one of claims 1 to 9, characterized in that the VR type valves are actuated by an ROV and the VH type valves are actuated remotely. 11.A method for commissioning a central multiphase measurement module in a system as defined in any one of claims 1 to 10, characterized in that it comprises the following steps: a) diesel circulation; b) performing a first leak test; c) performing a second leak test; d) performing a third leak test; e. e) removing the central multiphase metering module with the aid of an ROV.

12. Method, according to claim 11, characterized in that step a) comprises: via ROV, opening the resident manual valve VR-09 in the service header access to the trunk line at the output of the central multiphase metering module; via ROV, opening the resident manual valves VR-07, VR-06 and VR-PO4, wherein the valve VR-08 remains closed; via UEP injecting diesel through the service header; circulating diesel through the central multiphase metering module, passing through valves VR-09, VR-07, VH-PO1, VR-06 and VR-PO4. 13.Method according to claim 11, characterized in that step b) comprises: via UEP, circulating water through valves VR-09, VR-07, VH-PO1, VR-06 and VR-PO4, removing diesel from the central multiphase metering module; with the module filled with water, performing a leak test on the valves located at the inlet of the central multiphase metering module, these being VR-PO4, VR-07 and VR-08; performing a leak test on valve VR-PO4; via ROV, closing valve VR-PO4, and injecting water through the SV line access; and measuring the line pressure.

14. Method according to claim 11, characterized in that step c) comprises: interrupting production from the well connected to the choke module in question to test the leak of valve VR-PO4 towards the central multiphase metering module; via ROV close valves VR-PO2 and VR-PO1;.

14. Method according to claim 15, characterized in that step d) comprises: testing valves VR-07 and VR-08 towards the central multiphase measurement module; closing valves VR-06 and VR-07 via ROV; pressurizing with water via valve VR-09 and monitoring the pressure using the pressure transducer of the central multiphase measurement module; and closing valve VR-09 with ROV.

16. Method for commissioning a choke module in a system as defined in any one of claims 1 to 10, characterized in that it comprises the following steps: a) diesel injection and first circulation; b) second diesel circulation; c) third diesel circulation; d) water circulation; e) choke module removal. 17.Method, according to claim 16, characterized in that step a) comprises: via UEP, closing valves VH-GL1 (in the choke module), M1 and M2 (in the ANM), interrupting gas-lift injection and production in the well; via UEP, opening valves VH-GL2 (in the choke module) and XO (in the ANM); injecting diesel through the service header, passing through the open VR-SV1 valve and entering the Choke Module;.

17. A method according to claim 18, characterized in that step b) comprises: circulating diesel through the gas-lift line, PXO (in the ANM) and returning through the PO line; with the ROV, closing valve VR-GL1 and opening valve VR-GL3; via UEP opening valve VH-GL1 and closing VH-GL2; circulating diesel through the service line access to the gas-lift line through the open VH-GL2 valve, where diesel enters the GL line at a point downstream of valve VH-GL1; circulating diesel through the ANM, with entry into the ANM through the GL line passing through valves W2, XO, W1 and returning through the production line; passing diesel in the choke module through valves VH-PO1, VR-PO2 and VR-PO1 open and returning diesel through the production header, being carried along with the production from the other three wells in operation. Diesel fuel circulates in the VR-SV1 – VR-GL3 – VR-GL2 – VH-GL1 – PXO – VH-PO1 – VR-PO2 – VR-PO1 circuit, with the diesel being carried by the PO header along with the production from the other wells.

19. Method, according to claim 16, characterized in that step c) comprises: via UEP opening valve VH-PO2, closing valves VH-GL1 and PXO; circulating diesel in the VR-SV1 – VH-PO2 – VH-PO1 – VR-PO2 – VR-PO1 circuit, being carried by the PO header along with the production from the other wells; via ROV opening VR-PO3; via UEP closing valve VH-PO2;.

20. Method, according to claim 16, characterized in that step d) comprises: repeating steps b) and c) circulating water instead of diesel; leak testing of the valves located at the module inlets (VR-GL1, VR-GL2, VR-PO1 and VR-PO2); and closing valves VR-GL3, VR-PO3 and VR-SV1 via ROV.

Images