Patent Application
20130335232
The present invention relates to the field of underwater exploration, hydrocarbon extraction facilities and plants, general underwater installations and other underwater and deep-sea applications.
A typical hydrocarbon extraction facility comprises the following: a topside rig, which is located on the surface of the sea; a wellhead, where hydrocarbons are extracted from a well buried in the seabed; a production riser which connects from the wellhead on the seabed to the topside rig and which acts as a conduit for fluids between the rig and the wellhead; an umbilical which runs along the riser and which provides power and control of the well head from a control station in the topside rig. Similarly, a hydrocarbon drilling facility comprises a topside rig or drilling vessel; a wellhead installation, providing drilling access to a well buried in the seabed; a drilling riser which connects from the wellhead on the seabed to the topside rig and which acts as a conduit for fluids between the rig and the wellhead; an umbilical which runs along the riser and which provides power and control of the well head from a control station in the topside rig. Different risers are employed for drilling and production facilities, these are often referred to by the generic terms, marine riser or riser.
In shallow water applications, the topside well may be anchored to the seabed. In deep sea applications, the topside rig is typically positioned dynamically, i.e. without being anchored to the seabed and with the ability to move for alignment between the topside rig and the wellhead located on the seabed.
The riser connects to the wellhead via two segments: these are referred to as the Lower Marine Riser Package (LMRP) and the lower stack. Collectively, these two segments are known as a Blow-Out Preventer (BOP). The lower stack is fixed to the wellhead on the seabed and comprises valves, pressure sensors, actuators and other devices for maintaining and monitoring the state of the wellhead. The lower marine riser package is fixed to the lower end of the marine riser and comprises control and monitoring systems for controlling and monitoring the lower stack.
In normal operations, the marine riser remains connected to the wellhead via the blow-out preventer. An umbilical associated with the riser comprises electrical cables, and hydraulic lines which provide control of and monitor the state of the wellhead. Thus, control and monitoring of the wellhead is achieved via a direct wired link through an umbilical running beside the marine riser to the surface.
At the topside, lengths of pipe, typically referred to as a drill string, casing string or production string, as appropriate, is run through the riser and into the well. These tubing strings carry equipment such as the drill bit, casing, completion, intervention and logging tools to the desired positions in the well. Other tools, gauges and sensors can be run into the well on slickline and wireline also. We will use the term ‘string’ to refer to any means for conveying equipment into the well including tubing strings, wireline and slickline. The string passes through the riser, enters the blow-out preventer and wellhead before passing into the well.
Due to the great distances which can be involved in both water depth and well depth, it can be difficult to determine the exact location of the end of the string and thus the location of tools and devices mounted on the string. This is particular pertinent if the tools or string sticks in the well or in the event that the blow-out preventer may be operated. Thus it would be advantageous to be able to communicate between a device mounted on a string located in the riser to a device outside the riser.
WO2009/115798 describes a system and method for communicating electrical power and/or data signals along a production riser. The riser comprises an inner, electrically-insulating sheath defining a conduit and an outer, electrically-insulating layer surrounding the inner sheath so as to define an annulus in-between. The system comprises an electric current generator located at a predetermined position on the riser and operable to generate a current in the annulus; and a device positioned outside the outer layer of the pipe at a first location distant from the generator. The annulus is in electrical communication with the water at a second location on the riser distant from the generator such that an electrical return path extends through the water between the second location and the position of generator; and the device is operable to draw power and/or data from the current generated in the annulus by the generator. A method of communicating electrical power and/or data signals along a riser extending underwater comprises generating an electric current in the annulus at a predetermined position on the riser; positioning a device outside the outer layer of the pipe at a first location distant from the generator; providing an electrical return path extending through the water from a second location distant from the generator where the annulus is in electrical communication with the water to the position of generator; and operating the device to draw power and/or data from the current generated in the annulus by the generator.
While this describes a data communication system which operates along a riser, it does not offer the opportunity to communicate through the riser to a device located on a tubular string within the riser. It is further dependent on the riser being constructed in the fashion described and there being no interruptions in the layers over the distance of the riser between generators.
It is an object of the present invention to provide a system and method for communication data signals through a riser between a device on a string in the riser to a receiver outside the riser for onward transfer to the topside.
According to a first aspect of the present invention there is provided a communication system for data transfer between a first device located upon a string in a riser and a second device located outside the riser, the system comprising: a first transceiver mounted on the first device, the first device being located upon a string within a riser; a second transceiver mounted on the second device, the second device being located outside the riser; the first transceiver being arranged to transmit data in the form of electromagnetic signals and the second transceiver adapted to receive the electromagnetic signals when the first device and second device are substantially adjacent.
In this way, data is transferred through the riser. This removes the requirement to have communication links up the string. Additionally, if the location of the second device is known, the location of the first device is known when a signal is detected.
Preferably, the second device is mounted upon the outer surface of the riser. In this way, the position of the first device is known to be at the location of the second device when a signal is detected at the second device. Preferably also, there is a plurality of second devices located along a length of the riser. In this way, the progress of the first device and the string within the riser can be determined as a signal is detected in series along the second devices during passage of the string in the riser.
Alternatively, the second device is arranged to move along the outer surface of the riser. In this way, the second device may be mounted on an ROV and the location of the first device and position of the string can be determined at any position along the riser.
Preferably, the second transceiver is arranged to transmit electromagnetic signals and the first transceiver is arranged to receive electromagnetic signals. In this way, bi-directional communication is achieved.
Preferably, the first transceiver comprises an electric field coupled antenna. Preferably also the second transceiver comprises an electric field coupled antenna. In this way, the antenna can be located inside the device, embedded in the housing of the device or mounted in a plug located on the device and does not significantly increase the size of the device or interfere with the running of the string.
Alternatively, the transceiver may comprise a loop transducer. Optionally the transceiver may comprise a solenoid. In this way, any arrangement for transmitting and receiving electromagnetic signals may be used.
Preferably, the electromagnetic signal is modulated. In this way, data is transferred on the signal. More preferably, the signal has a carrier frequency less than or equal to 100 Hz. Such frequencies have been by the inventors to pass through the steel commonly used in construction of a riser, seawater and fluids flowing in the riser.
Preferably the second device includes means to communicate the data to the topside. Preferably the means is one of a group comprising: radio communications, acoustic signaling and a direct conductive wired link. In this way, known communication systems can be used between the second device and the topside.
The first device may include one or more sensors. In this way, measurements of physical parameters inside the riser can be transmitted to the topside. The first device may include actuators. In this way, the first device may be signaled to operate and carry out procedures either itself or via another device or tool while in the riser.
Preferably the second device is located adjacent the riser towards the wellhead. In this way, conditions in the wellhead can be monitored and/or operations can be carried out at the wellhead by transmission of signals between the devices.
In an embodiment a repeater is located at the riser. In this way, the second device can be located more remote from the riser. Such an arrangement would provide for communication through a buoyancy tank which may be mounted on the riser.
According to a second aspect of the present invention there is provided a method of communication from a device on a string in a riser to outside the riser, comprising the steps:
Preferably, the method includes the step of relaying the transmitted signal to a topside.
Preferably, the method includes the step of moving the second transceiver along a length of the riser.
Embodiments of the present invention will now be described, by way of example only, with reference to the accompanying figures in which:
a) and (b3) show embodiments of a transducer for use in a communication system of the present invention;
emf=nAωμεμ0H0 Equation 1
where
μE=effective magnetic permeability of core,
μ0=magnetic permeability of free space (4π×10−7 Am−1),
ω=angular frequency,
n=number of windings of solenoid,
A=Cross sectional area of magnetic core,
H0=Magnetic field strength of incident electromagnetic signal in the absence of the core.
A given input signal has a given angular frequency w and produces a given magnetic field strength H0 at the antenna. The sensitivity of the antenna is determined by the variables independent of the input signal in equation 1; i.e. the number of windings of the coil, n, the area of the magnetic core, A, the effective permeability μE of the core.
Loop area can be increased by using the relatively unconstrained Z dimension to extend a loop antenna deployed within a pipe. This orientation also has the benefit of producing field lines that are orthogonal to the circumference of the pipe. For loops deployed in the X-Y plane the circular conductive pipe acts as a shorted turn and in this orientation current is induced in the pipe which acts to reduce the field generated by the loop to the detriment of the communications link budget.
In a further embodiment a solenoid may be employed as the transducer internal to the pipe. In
Electromagnetic signals are highly attenuated when passing through an electrically conductive material. Steel typically has relative permeability in region of 100-8000 depending on applied field strength and steel grade. Steel pipe conductivity is approx 3.8-4.8×106 Sm−1 while the surrounding sea water typically has a conductivity of 2 to 4 Sm−1. Electromagnetic attenuation increases rapidly with frequency and this drives us toward the use of low carrier frequencies in a through steel communications system to achieve the required operational range. For example, in some embodiments a carrier signal of 100 Hz may be used. A modulated electromagnetic signal occupies a spectral bandwidth which is dependent on bit rate and the modulation scheme used. High order modulation schemes, for example 64 QAM, reduce the required bandwidth and this is beneficial for enabling the required link capacity in a low frequency signalling system.
The transmission channel through steel, and to a lesser extent through sea water, is highly dispersive in phase and gain due to the material's high conductivity. Phase and amplitude equalisation schemes may be employed to allow operation of high order modulation schemes.
The electromagnetic signalling path in this system may include many layers of varying material including riser casing; riser steel pipe; riser buoyancy material; riser fluids e.g. ZnBr, CaBr, CaCI; surface rust; pipe scale; sea water. For example, the riser may be of steel at X65 or X80 steel with an inner diameter of 19 inches and an outer diameter of 21 inches.
Where a through sea water radio communications link is used for onward transmission to the surface a relay system using several transceivers on the riser may be required to achieve the required range at the required data rate.
The communications data rate requirement in a hydrocarbon production system is typically asymmetric. Command and control from the topside to equipment within the production system requires a lower bandwidth, for example 10 bps, than the recovery of data from embedded equipment to the control centre which for example may take place at 10 kbps or higher.
The communications system is typically lowered temporarily into the riser pipe as part of a landing string system to perform work inside the well.
In use, a device such as the subsea control module 11, is run into the riser 23 on a string 27. Progress of the descent of the module 11 can be monitored by the transceivers 14 mounted on the riser. Where transceivers 14 are arranged along a length of the riser 23, electromagnetic signals transmitted from the antenna 25 will come into range of each transceiver 14 in series down the riser 23. When the module 11 the lowermost transceiver 14, determined by reception of a signal from this transceiver 14, the string can be stopped so that the module is located at a desired position. In the embodiment shown in
An alternative use may be having transceiver 12 located on string 27 and run in the riser 23 as before, but in this embodiment, the string 27 becomes stuck in the well. This can occur when the string 27 is a drill string or where the string 27 carries logging or intervention tools. With the string in a fixed position, the transceiver 12 can transmit electromagnetic signals which can be detected outside the riser 23. If fixed transceivers 14 are located on the riser 23, one of these may pick-up the signal and thus provide a position of the transceiver 12 and thus the location of tools on the string 27 in the riser 23. An alternative embodiment is to mount the transceiver 14 on an ROV (remotely operable vehicle) 29. The ROV 29 is then moved along the outside of the riser 23 through the seawater. When flown along the length of the riser 23, transceiver 14 will receive the signal from the transceiver 12 within the riser 23, when the ROV 29 is at the position on the riser 23 where the transceiver 12 is located within the riser 23. Once the position is identified, data and control can be communicated between the ROV 29 and the string 27, which can assist in determining the reason for the problem or actuate tools to release at least a portion of the string 27. By determining the location of the string in the riser 23, a precise location of what portion of the string 27 is at the rams of the BOP can be given. This information can be used to make a decision on whether operating the BOP to splice the string 27 would be useful to recovery.
The descriptions of the specific embodiments herein are made by way of example only and not for the purposes of limitation. It will be obvious to a person skilled in the art that in order to achieve some or most of the advantages of the present invention, practical implementations may not necessarily be exactly as exemplified and can include variations within the scope of the present invention.
| Number | Date | Country | Kind |
|---|---|---|---|
| 1011182.1 | Jul 2010 | GB | national |
| Filing Document | Filing Date | Country | Kind | 371c Date |
|---|---|---|---|---|
| PCT/GB11/00979 | 6/30/2011 | WO | 00 | 8/30/2013 |
