Oil production manifold system with central MQC and without tpo and tgl lines and method for commissioning choke module via ueh

Abstract

The present invention relates to a flowline-less oil production manifold system with a central MQC comprising: a crossover module (MXO); five umbilical termination modules (MTU), one of which is for receiving the main umbilical from the UEP; a hydraulic and chemical injection distribution unit (CDHIQ); four choke modules; four subsea Christmas trees (ANM); headers and branches of gas lift (GL) lines; headers and branches of oil production (PO) lines; and a central MQC (Multi Quick Connector). Furthermore, the present invention also relates to a method for commissioning a choke module via UEH, which reduces the need to circulate large volumes of water and diesel, and is carried out by circulation with MEG flow.

Description

OIL PRODUCTION MANIFOLD SYSTEM WITH CENTRAL MQC AND WITHOUT TPO AND TGL LINES AND CHOKE MODULE COMMISSIONING METHOD VIA UEH 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 from multiple oil wells to the FPSO (typically 4 wells, but not limited to this number), subsea production manifolds (SPMs) help optimize production, reduce CAPEX, minimize downtime, and maximize oil recovery.

[0005] Furthermore, they ensure the integrity of the process by monitoring and regulating pressures and temperatures. of the fluid 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); • gas-lift test line (GLT); and • In addition to the control umbilical, between the equipment and the power plant.

[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 case of failures in its multiphase metering modules, this type of system presents great difficulties for replacement, leading to the need for a total interruption of equipment production (shutdown of 4 producing wells in typical architectures) for the complete replacement of a choke module, which 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- which has a reduced number of lines; b- which allows the replacement of a choke module without interrupting the production of the entire equipment (interruption only of the production of the well connected to the module that will be replaced) through the method described in this document; c- which has a greater number of MEG injection points for hydrate dissociation operations; d- which allows access to the equipment via ROV, providing greater flexibility for hydrate dissociation operations, both with local depressurization and with MEG injection via ROV.

[0009] Therefore, there are no prior art documents that address alternatives aimed at: eliminating the TPO and TGL lines, connecting the manifold to the UEP, resulting in CAPEX reduction by eliminating a pipeline, as well as decreasing the complexity of the subsea arrangement and reducing the header size on the equipment; the possibility of commissioning the manifold choke modules without interrupting production from other wells; and reducing the number of crossover modules. SUMMARY OF THE INVENTION

[0010] The present invention presents a manifold system for oil production without a TPO line and without a TGL line comprising: • A crossover module (MXO); • Five umbilical termination modules (MTU, one for receiving the main umbilical coming from the UEP, the other four for control distribution to ANMs (wet Christmas trees)); • A hydraulic and chemical injection distribution box (CDHIQ); • Four choke modules containing multiphase and single-phase meters; • Gas-lift (GL) header and branches; • Oil production (PO) header and branches; • A central MQC (Multi Quick Connector); • Valves for ROV access.

[0011] Furthermore, the present invention also relates to a method for commissioning a choke module, which involves the following steps and their respective sub-steps: MEG injection and circulation, and choke module removal.

[0012] This method mitigates the need to circulate large volumes of water and diesel, and is achieved via injection with circulation and MEG flow. BRIEF DESCRIPTION OF THE DRAWINGS

[0013] The present invention will now be described with reference to typical embodiments thereof and with reference to the accompanying drawings, in which:

[0014] Figure 1 is a representation of the prior art four-well oil production manifold system.

[0015] Figure 2 is a representation of the oil production manifold system for four wells according to the present invention.

[0016] Figure 3 is a representation of the choke modules according to the present invention.

[0017] Figure 4 is a representation of the choke modules according to the present invention, with the MQC connection. The central point connects the MQCs via jumpers, and the MEG flow is inside the choke module.

[0018] Figure 5 is a representation of the flows inside the choke module, as well as the condition of its valves in normal operation according to the present invention.

[0019] Figure 6 is a representation of the Choke Module filled with MEG and ready for replacement after commissioning via UEH. DETAILED DESCRIPTION OF THE INVENTION SYSTEM ARCHITECTURE

[0020] The present invention proposes a system comprising an oil production manifold without TPO and TGL lines, as shown in Figure 2. This type of architecture, when compared to the architecture of the prior art equipment, as shown in Figure 1, presents the following advantages: a- eliminates TPO and TGL lines, reducing CAPEX by eliminating two pipelines, in addition to decreasing the complexity of the subsea arrangement; b- allows the replacement of a choke module without the need to stop the entire equipment; d- reduces the number of crossover modules (XO) from 2 (standard architecture) to 1; e- allows the replacement of the XO without stopping production of the equipment as occurred in the standard architecture; f- reduces two headers and branches in the equipment; g- enables the exclusive commissioning of the choke module by injection and circulation and MEG, thus avoiding The need to circulate large volumes of diesel and water to the ANM. h- It features valves with access via ROV, where local depressurization is possible for hydrate dissociation, which also increases operational availability.

[0021] In more detail, Figure 1 illustrates the state-of-the-art system applied to four wells. In this case, four lines are used: PO, GL, TPO, and TGL (in addition to the umbilical). Furthermore, considering the system's complexity, the standard architecture requires the use of two MXO blocks (MXO1, MXO2), which allow fluid circulation between the headers, enabling hydrate dissociation and commissioning operations.

[0022] As shown in Figure 2, by eliminating the TPO and TGL lines from the system of the present invention, it is possible to reduce two headers in the equipment, using only the GL and PO lines.

[0023] The system of the present invention is composed of the following structures: • a crossover module (MXO); • five umbilical termination modules; • four choke modules; • gas-lift (GL) header and branches; • oil production (PO) header and branches; • a central MQC (Multi Quick Connector); • valves for ROV access for depressurization and MEG injection.

[0024] Furthermore, the system features resident valves (RV) actuated via ROV and hydraulic valves (HV) actuated remotely.

[0025] For example, as can be seen in Figure 3, which illustrates a choke module in one of the wells, the valves located at the choke module inlet VR-GL1, VR-GL2, VR-GL3, VR-GL4, VR-PO1, VR-PO2, VR-PO3, VR-PO4, VH-GL1 and VH-PO1 are normally open. Thus, ROV actuation is necessary to change the status of these valves to perform certain operations. Similarly, valves VH-GL1 and VH-PO1 require hydraulic control for their actuation.

[0026] Furthermore, 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 and ANMs.

[0027] In this regard, the system also includes local MQC (Multi Quick Connector) interfaces between the resident valves (VR) (these being VR-GL1 / VR-GL2, VR-GL3 / VR-GL4, VR-PO1 / VR-PO2, VR-PO3 / VR-PO4), for access by ROV, which can be used for hydrate dissociation (by depressurization, MEG injection and leak testing of the resident valves at the choke module inlets).

[0028] Furthermore, the system of the present invention also adds a central MQC near the CDHIQ. This allows the ROV to connect a jumper between this central MQC interface and The local MQC (Maximum Quality Control) between the valve pairs residing at the choke module inlet enables the commissioning of the choke module for its replacement, through MEG injection via the umbilical that connects the equipment to the platform.

[0029] Figure 4 shows one of the MSP choke modules commissioned via UEH. The jumpers used by the ROVs to connect the central MQC to the hubs of the local MQCs between the resident valves are also indicated in Figure 4 and allow MEG circulation.

[0030] Therefore, to allow the uninterrupted operation of the other wells in the system during the replacement of one of the choke modules, three steps must be followed. The procedure must be carried out using the choke module that needs to be replaced. This involves cleaning procedures with MEG injection and circulation to allow for the recovery of the choke module.

[0031] Local MQC interfaces were added to the valves located at the inlet of the GL and PO headers for access via ROV. The objective is to use these accesses to conduct valve leak tests, allowing the choke module to be removed without stopping manifold production, preventing hydrate dissociation. Furthermore, these interfaces are also fundamental for MEG injection and circulation through jumpers connected via ROV to the Central MQC. COMMISSIONING METHOD VIA UEH

[0032] The operation of the wells and equipment occurs after the commissioning procedure, initiating production for an existing power plant. Figure 5 shows one of the modules of... The choke shows the flows during normal MSP production. It also highlights the status of the module valves and the ANM producing for the module in question, where the GL and PO line valves remain open (initial state).

[0033] The hydrocarbon flow from the well follows this path through the valves: I. DHSV valve open; II. M1 and W1 valves open; III. VR-PO4, VR-PO3, 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 open VR-GL1, VR-GL2, VH-GL1, VR-GL3, and VR-GL4 valves; III. Gas passes through the open W2 and M2 valves in the ANM.

[0034] 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.

[0035] Figures 4 and 6 again show one of the choke modules, presenting the state of the module's valves and the ANM connected to this module as the MEG injection and circulation cleaning procedures are conducted to allow the choke module to be recovered. The following flowcharts represent the steps with MEG injection via UEH and jumpers. The procedure must obviously be performed according to the choke module that needs to be replaced.

[0036] The procedure for this operation is presented below: • Via ROV, close valves VR-GL1, VR-GL4, VR-PO1, and VR-PO4; • Via ROV, connect jumpers, linking the central MQC to the MQC interfaces positioned between the resident valves VR-GL1 / VR-GL2 and VR-PO3 / VR-PO4, where, from CDHIQ, a MEG flow from the UEH follows through the connected jumpers, accessing the GL and PO branches in the Choke Module via MQC interfaces; • The MEG flow through the GL line enters through the local MQC access between valves VR-GL1 / VR-GL2 and passes through the module to carry the gas in this section, exiting through the local MQC access between valves VR-GL3 / VR-GL4, being collected at this outlet; • The MEG flow through the module's PO duct enters via the local MQC access between valves VR-PO3 / VR-PO4 to carry the oil inside the choke module, exiting via the local MQC access between valves VR-PO2 / VR-PO1, as can be seen in Figure 5;• After injecting and circulating MEG through the MQC access points via ROV, close valves VR-GL-2, VR-GL3, VR-PO3, and VR-PO2; • Disconnect and collect jumpers connected to the MQC access points; • Perform leak tests on the 4 pairs of resident valves (VR-GL1 / VR-GL2, VR-GL3 / VR-GL4, VR-PO1 / VR-PO2, VR-PO3 / VR-PO4) via ROV through the MQC interfaces between valves; • If the previous test result is positive, remove the Choke Module filled with MEG, as shown in Figure 6.

Claims

CLAIMS 1. Oil production manifold system with central MQC and without TPO and TGL lines, characterized in that it comprises: • a crossover module (MXO); • five umbilical termination modules (MTU, one for receiving the main umbilical from the UEP, the other four for control distribution to ANMs); • a hydraulic and chemical injection distribution box (CDHIQ); • four choke modules containing multiphase and single-phase meters; four wet Christmas trees (ANM); • gas-lift line headers and branches (GL); • oil production line headers and branches (PO); • a central MQC (Multi Quick Connector).

2. System, according to claim 1, characterized in that the main umbilical termination module (MTU) coordinates the distribution of MEG / ethanol to the CDHIQ, and the CDHIQ distributes the MEG to the choke modules and ANMs connected to the equipment. 3.System, according to claim 1, characterized in that the choke module comprises: - a gas-lift (GL) branch; - an oil production (PO) branch; - single-phase and multi-phase valves, sensors and meters.

4. System according to claim 1, characterized in that the gas-lift (GL) branch of the choke module additionally comprises: a VR-GL1 valve; a VR-GL2 valve; a VR-GL3 valve; a VR-GL4 valve; a VH-GL1 valve; a single-phase meter (SPFM); and three pairs of pressure and temperature transducers.

5. System according to claim 1, characterized in that the oil production (PO) branch of the choke module additionally comprises: a VR-PO1 valve; a VR-PO2 valve; a VR-PO3 valve; a VR-PO4 valve; a VH-PO1 valve; a multi-phase meter (MPFM); and three pairs of pressure and temperature transducers.

6. System according to any one of claims 1 to 5, characterized in that the VR type valves are actuated by an ROV and the VH type valves are remotely actuated via hydraulics. 7.A system, according to any one of claims 1 to 6, characterized in that the resident valve pairs (VR-GL1 / VR-GL2, VR-GL3 / VR-GL4, VR-PO1 / VR-PO2, VR-PO3 / VR-PO4) have a local MQC interface.

8. System, according to any one of claims 1 to 7, characterized in that a central MQC is added at the output of the CDHIQ, and in that the ROV connects a jumper between the central MQC interface and the local MQC interface between the resident valve (VR) pairs at the module input.

9. Method of commissioning a choke module via UEH in a system, as defined in any one of claims 1 to 8, characterized in that it comprises the following steps: • via ROV, closing valves VR-GL1, VR-GL4, VR-PO1 and VR-PO4; • via ROV, connecting jumpers, linking the central MQC interface to the local MQC interfaces positioned between the resident valves VR-GL1 / VR-GL2 and VR-PO3 / VR-PO4, in which a MEG flow follows from the CDHIQ through the connected jumpers, accessing the GL and PO lines in the choke module through the MQC interfaces;• where the MEG flow through the GL branch enters through the MQC access between VR-GL1 / VR-GL2 valves and passes through the choke module to carry the gas in that section, exiting through the MQC access between VR-GL3 / VR-GL4 valves, being collected at that outlet; • where the MEG flow through the PO duct of the choke module enters through the local MQC access between VR-PO3 / VR-PO4 valves to carry the oil inside the module, exiting through the local MQC access between VR-PO2 / VR-PO1 valves; • After injecting and circulating MEG through the MQC access points, close valves VR-GL-2, VR-GL3, VR-PO3, and VR-PO2 via ROV; • Disconnect and retrieve jumpers connected to the MQC access points; • Perform leak tests on the 4 pairs of resident valves (VR-GL1 / VR-GL2, VR-GL3 / VR-GL4, VR-PO1 / VR-PO2, VR-PO3 / VR-PO4) via ROV through the local MQC interfaces between valves; • Remove the choke module filled with MEG.

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