GB2414756A

GB2414756A - Subsea logging using alternative conduit in well communicating with floating instrument pod

Info

Publication number: GB2414756A
Application number: GB0517372A
Authority: GB
Inventors: David Randolph Smith
Original assignee: Sensor Highway Ltd
Current assignee: Sensor Highway Ltd
Priority date: 2001-07-12
Filing date: 2002-07-10
Publication date: 2005-12-07
Anticipated expiration: 2022-07-10
Also published as: GB2395965B; US20040020653A1; GB2395965A; WO2003006779A2; NO20040099L; GB2414756B; GB0517372D0; GB0400275D0; GB2414258A; GB2414258B; US20030010500A1; AU2002324484B2; WO2003006779A3; GB0517457D0; US6640900B2; US6913083B2

Abstract

An apparatus for logging or controlling a subsea well comprises an alternative path conduit (11, fig 3) disposed in a subsea well W, proximate a casing string (13, fig 3). The conduit is connected with a floating pod 17 at the ocean surface. A wet connector (12, fig 3) may be used. A logging tool or a cable may be deployed through the conduit. Temperature, pressure or chemical properties may be monitored through the conduit. Downhole devices may be actuated through the conduit. The conduit allows rigless intervention to monitor well variables without interrupting the production tubing fluid flow stream. The pod may house processors and telecom equipment for transmitting data to a remote location.

Description

241 4756 METHOD AND APPARATUS TO MONITOR, CONTROL AND LOG

SUBSEA WELLS

BACKGROUND OF INVENTION

The present invention is directed to methods and apparatus for logging and permanently monitoring subsea oil, gas, and injection wells; specifically to deploying photonic, electromagnetic or hydraulic conduits in an alternative path adjacent the production tubing in said wells.

Subsea wells are broadly defined as wells that do not provide fixed access from the surface of the sea. Subsea wells have weliheads located at or very near the sea floor and produce into subsea pipelines or provide access only through long subsea umbilical cables to distant locations.

Traditional offshore wells located on offshore plaffomms have weliheads located on the platform at or above the sea surface.

Fluid flowing from subsea wells proceeds out of the wellbore from one or more producing zones, through a system of continuous conduits, subsea weliheads, subsea flow lines, subsea pipelines and to a surface production and storage facilities often many miles from the location of the subsea well head.

As oil and gas becomes more and more difficult to find on land or in shallow coastal waters, the oil and gas industry has commenced exploration and development in deeper waters, miles from production and storage facilities. Prior to oil and gas being discovered in deep waters, the preferred method of producing the wells was to place the weliheads and the subsequent control devices for the wells at the sea surface on a platform. The access to these wells for the purpose of placing monitoring devices or performing intervention logging services was easily performed from the off-shore platform with the many well known methods of wireline logging, continuous coiled tubing, or even hydraulically pump down logging and monitoring systems.

Obtaining access to subsea wells for logging, monitoring or control purposes generally requires a costly submersible connection from the sea surface to the welihead. Current methods, for example, to repair permanently disposed monitoring equipment, or to insert a suite of well logging tools into sub-sea wells, require the mobilization of a surface vessel which contains an off shore rig known to those in the industry as a semi-submersible rig or a drill ship. In all cases, the entry into the subsea well of the logging tools or tools to replace and dispose permanent monitoring equipment is performed through the production tubing. Since these wells are very expensive to drill and bring on line, most oil and gas producers prefer to not reenter the well unless absolutely necessary.

Hence, subsea wells are difficult to log or access for the placement of monitoring equipment. Further, visual inspections of these subsea wells are impossible because of the depths and distances of the welihead from the nearest maintenance and production platform facility. Abnormal subsea well conditions cannot be observed in the manner of offshore platform wells or land wells, where u gauges and visual leak detection may be maintained.

Monitoring of the subsea wells for safety, reservoir evaluation, and environmental reasons requires the instrumentation monitoring of the subsea well be done remotely. This requires the transmission of the data from subterranean sensors in the well and subsea monitoring sensors over large distances to a receiving and processing node. This transmission of data is normally done over copper or optic fiber transmission umbilicals connecting the sub-sea wells back to surface data receiving stations. Owing to the long distances and depths, considerable expense must be incurred to utilize these subsea umbilicals.

The current monitoring methods that are used for subsea wells is further compromised by the frequent failure of subterranean gauges and instruments used to monitor oil and gas wells. Owing to the remoteness of subsea wells from the surface of the sea and the need for rig interventions to access the subsea and subterranean monitoring devices requires well maintenance be performed from intervention rigs which are not always readily available to perform such maintenance. The result of these failures and the difficulty of quickly repairing them generally results in the decision to continue producing deep-water wells without any subsea monitoring information for leaks and pressure anomalies and without subterranean monitoring of reservoir parameters. These shortcuts are undesirable because they can lead to catastrophic failures of wells, hydrocarbon releases into the sea, and less than optimal reserve recovery.

The logging of wells has traditionally been done from platforms and on land wells to obtain additional information about a well's reservoir condition and the integrity of the well's structure. In subsea wells, logging is rarely done, as it requires the mobilization of very large and expensive semi- submersible rigs or drill ships. Furthermore, these subsea logging interventions introduce the possibility of losing wireline equipment in the well and compromising the well's ability to produce. Also, sub-sea logging operations normally require the production of the well be reduced or curtailed during process of rigging up of the logging equipment.

Owing to the above-mentioned difficulties of logging and maintaining unreliable subterranean monitoring equipment and very long umbilical transmission lines, many sub-sea wells are produced while monitoring the produced fluid back at the process or storage facility many miles away. This method of monitoring does not yield any indication of where the fluids are coming from in the well (by. which portion of the formation may be producing) desired where production may be resulting from large perforated intervals in the well. Additionally, flow rate information monitored at the surface does not identify possible cross flow of fluids between reservoir intervals, changes in water, oil, and gas quantities as function of the depth of the well, the presence of leaks in well tubular conduits, and whether the reservoir is depleting in pressure.

It is desirable from both a reservoir engineering perspective as well as from a safety and environmental perspective to obtain realtime information from subsea wells relating to dynamic subterranean environment, fluid production parameters, and subsea well equipment integrity. Examples of parameters which are desirable to monitor on a realtime basis are fluid flow rates, water cut, resistivity of subterranean formations, spontaneous potential of subterranean reservoirs, pressure, temperature, sand production, steel wall thickness of tubulars, seismic energy from the reservoir or other sources, and other variables known to those familiar with oil and gas production. This information is currently gathered from either permanently disposed monitoring devices attached to the production tubing or from well intervention methods that insert the devices concentrically through the production tubing in the subsea well.

The commonly disposed permanent monitoring devices include pressure sensors, flow meters, temperature sensors, geophones, accelerometers, seismic source broadcasters, and other sensors and instruments. These devices are inserted in subsea wells concentrically through the well's production tubing either using wireline, coiled tubing, and slickline, from a rig placed at the surface of the sea and connecting to the subsea well through the water by risers. Alternatively, these permanently disposed devices are inserted in a well with the production tubing. The production tubing is also inserted into the well via the use a rig on the surface of the sea where again a large riser is run from the sub-sea welihead at the sea floor up through the water to the rig. Therefore, when permanently disposed monitoring equipment is inserted in a well either with production tubing or the other forms of insertion of the devices concentrically through the production tubing, a surface rig is required.

All of these parameters are obtained traditionally on land or offshore platform wells using offshore platform wells via the art of well logging.

However, in the case of sub-sea wells the methods have to date not been developed to allow for safe, simple, and rapid log intervention into wells.

Likewise, the retrieval of down hole pressure gauges or other instruments on land or off-shore platform wells is often achieved by a well intervention with commonly known methods of wire line operations thereby not requiring a rig to be mobilized to the land or off-shore platform location. Failure and need for retrieval of subterranean pressure gauges or other subterranean instruments in sub-sea wells can not be performed by wire line or logging interventions unless a semi-submersible rig or drill ship is deployed to the sub-sea well location. The present invention provides a rigless intervention method to access subsea wells.

Several subterranean data gathering systems are currently used to obtain data from the wells. This is commonly done using down hole permanent pressure gauges, and flow meters, that have long umbilical from the subsea well to a platform or floating production facility. The umbilical have electrical or optical cable to transmit data from the different permanently deployed instruments and devices in the well. The current method of gathering data from subsea wells practiced by the oil and gas industry requires the pressure gauges and pressure gauge electrical or optical data transmission line be disposed in the subsea well during the initial well construction, known to those familiar with the art as the well completions. It also requires that all down hole instruments be connected to data transmission lines, either electrical or optical lines, by a subsea wet connection. This connection then connects the subterranean data transmission lines to the subsea umbilical transmission lines. These connections are difficult to do at deep-water depths, which often have large currents, high hydrostatic pressures, and are at depths where only a very limited number of Remotely Operated Vehicles (ROVs) can operate and make such wet connections.

The deep-water wells are being placed further from land, platforms, or floating process facilities to which the umbilicals are connected. This results in very long umbilicals with large weights and costs. Therefore, each additional instrument data transmission requirement from the sub-sea well requires an additional line in the umbilical going from the sub-sea welihead back to the host facility at the sea surface often many miles away.

When the pressure gauge fails or when the data transmission line fails, or when the data transmission's wet-mateable connection fails, the only recourse for repair of the data gathering system is an intervention into the well, using either a drill ship or a semi-submersible drilling rig resulting in the pulling of the well completion, and a significant number of days of lost production during the recompletion of the well, all as previously described.

The present invention provides a method and apparatus to intervene into these deepwater sub-sea wells without deploying a deepwater rig to hydraulically connect to the sub-sea welihead and thereafter deploy logging instruments into the well has long been sought by the oil and gas industry.

Another feature of the present invention permits the entry of sub-sea wells for the purpose of obtaining data without placing logging tools and wire line cable into the production tubing fluid flow stream of these subsea wells. The intrusion of logging tools into the flow stream of such wells presents a significant risk of losing the logging equipment in the well and obstructing fluid production. The present invention obviates the need for such interventions.

SUMMARY OF THE INVENTION

According to one aspect of the invention, there is provided anapparatus for logging, controlling, or monitoring a subsea well, the apparatus comprising: a casing string disposed in a subsea well; an alternative path conduit permanently disposed proximate the casing string and passing through a subsea welihead, the alternative path conduit being connected to a hydraulic wet connector; a production tubing located within the casing string; and a flotation pod connected to the alternative path conduit through the hydraulic wet connector.

According to another aspect of the invention, there is provided a method of monitoring a sub sea well, the method comprising: deploying a floating instrument pod proximate to the well; connecting the pod to an alternative path conduit; deploying the alternative path conduit proximate to a casing string within the well; and communicating through the alternative path conduit between the instrument pod and the well.

DETAILED DESCRIPTION OF THE DRAWINGS

Fig. 1 is a partial schematic representation of the invention as disposed in several subsea wells.

Fig. 2 is a cross-sectional schematic view of the invention showing the apparatus of the present invention disposed into a subsea well.

Fig. 3 is a partial schematic view of a U-connection in a producing well.

DETAILED DESCRIPTION

The Alternative Path Conduit Referring now to Fig. 1 of the drawings, a plurality of wells W are shown located on the sea floor 5. The well is drilled from the surface of the sea 7 using a semi-submersible 100 or drillship drilling rig (not shown). One or more wells W are bored by the action of rotating a drill bit on the end of a drill pipe from the surface rig where the drill bit is inserted inside of risers pipes and the drill cuttings are flushed out of the well bore with a drilling fluid using method and apparatus well known to those in the oil and gas industry.

As more clearly shown in Fig. 2, a subsea well is constructed by drilling a borehole 1 down into the earth to intersect subterranean fluid production intervals 2 located in the earth. The well is constructed with at least one diameter of casing 3 disposed into the annulus of the borehole 1 and grouted into place from the surface rig, using cement 4 placed between the annular space formed between the bore hole 1 and casing 3. This process can be repeated with at least one additional casing 13. The final casing, in this figure casing 13, is explosively penetrated using explosive charges forming perforation tunnels 10 connecting the borehole hydraulically with the subterranean fluids in the earth. A production tubing string 8 is inserted inside the casing 13 and deployed from a surface rig. The production tubing 8 can provide adjacent its lower end, a sealing element known as a packer 6. The packer 6 is inserted in the annulus of casing 13 with the production tubing and set in the casing 13 above the perforation tunnels 10 to form a seal between the production tubing 8 and the casing 13 using any of the methods known to those familiar with oil and gas well completion technology. The upper end of the production tubing 8 is terminated and retained in a welihead 9 forming a sealed hydraulic conduit between the production tubing and the casing with hydraulic communication with the reservoir or production zone 2 through the perforations 10.

The present invention teaches the insertion of at least one parallel tubing string 11 of a smaller diameter disposed parallel, but exterior, to the production string 8, forming an alternative path through the well head and into the well.

In one preferred embodiment, the parallel tubing string 11 is connected to the outer diameter of casing 13 and inserted in the well from the surface rig while the casing 13 is deployed into the annulus of the wellbore 1. In another embodiment, a parallel tubing string (not shown) may be attached to the production tubing 8 and inserted into the well as the production tubing 8 is deployed from the surface rig. In either embodiment, the parallel tubing string 11 is connected through the welihead 9 and sealed therein forming a sealed alternative path conduit into the sub-sea well without communication with the production fluid from the production interval 2. In both embodiments, at least one parallel path-tubing conduit 14 is connected above the welihead 9 to a hydraulic quick connection 12. This connection can be made either at the welihead or several hundred feet away from the welihead to avoid the possibility of ROV collisions with the welihead structure.

In yet another embodiment more fully shown schematically in Fig. 3., the well is constructed with a parallel alternative conduit path formed by inserting in the well two parallel conduits attached at the bottom in the well with a U-tube connection. These parallel conduits form an alternative path to the production tubing 8 that goes down the well and then back through the sub-sea welihead 9, with each end hydraulically connected above the well head with a hydraulic disconnect device 12. Each parallel conduit string 11 in each embodiment can provide a fluid control safety valve 15 disposed either above or below the welihead 9. As may be readily seen from Fig. 3, the return conduit need not be of the same internal diameter as the ingress conduit. The continuous path of 14 to 11 through the welihead 9 communicates through the egress side 11' and conduit 16'. In each manner of installation, the fluid control safety valve 15 is used to control the unwanted escape of fluids through the alternative path conduit system. Other hydraulic check valves may be placed at 12' as need to prevent escape of fluids upon disconnection of the conduit during operations.

This invention further teaches the construction of at least one continuous hydraulic conduit path from below the sub-sea floor 5 into and through the subsea welihead 9 to the surface of the sea 7 by connecting alternative path conduit 14 above the well head proceeding from the well to a submersible conduit 16, such that one end of the continuous path has one end at the surface of the sea 7. Referring back to Fig. 1, conduit 16 can be partially supported by subsurface buoys 51.

Referring again back to Fig. 1, the present invention further teaches the connection of the submersible conduit 16 from the subsea welihead 9 to a surface instrument pod 17. This surface instrument pod can be moored to the sea floor by a system of cables and anchors 18 to keep instrument pod 17 on station above the subsea wells. Alternatively, instrument pod 17 can be tethered by a single line providing resilient means to hold the pod in a set position while permitting the pod to move with the movement of the waves.

So far as is known to applicant, no alternative path subsea conduit path has ever been used to provide a means of communicating with or controlling a subsea producing well.

Installation of the Alternative Path Pod and Lines The present invention requires that the alternative path conduit be installed during completion of the well. Consequently, the installation of the alternative path conduit must be coordinated with the setting and grouting of the well structure. Accordingly, the well profile must be planned with the alternative path conduit. If the alternative path conduit is to provide a path for optic fiber cabling only, a '/. inch tubing or similar can be installed and strapped to the final casing upon setting of the casing string from the drilling platform or ship. If the alternative path conduit is to provide a means for wireline logging tools, chemical injection lines or hydraulic control lines, larger diameter conduit can be used to permit subsequent use as a combination pathway for one or more of these methods. If the preferred U-shaped alternative path conduit is set in the completed well, a memory-tool (ie. one having a means of sensing and preserve the information as it passes through the pipe at a fixed velocity) may also be pumped into and out of the well to log the well without any wireline connection. Since the alternative path conduit is set in the welihead of each subsea well, the welihead must be designed for the alternative path conduit as well. Once set in the welihead, the alternative path conduit provides a useful and easy diagnostic tool for monitoring, controlling and logging the well. The casing and welihead are set in a manner well known to those in the industry. The connection of the alternative path conduit to the wetmate connection may be made either at the surface and installed with the welihead or installed later. It is anticipated that most installations will be made after the installation of the welihead is accomplished and flanged up on the sea floor.

For installation, instrument pod 17 is connected to conduit 16 aboard a surface vessel, like a semi-submersible drilling rig, or other vessel that allows for the connection of the conduit 16 aboard the vessel having the same relative motion as the instrument pod 17 and the conduit 16 proceeding up from the sub sea well. The preferred embodiment disposes one or more instrument packages within the instrument pod 17 that permit the gathering of data coming various data transmission lines disposed inside the alternative path conduit 16 proceeding up from the well. These data lines are any of the well-known lines that are used for data transmission including but not limited to optical fiber, electrical conductors, and hydraulic fluids. The optical fiber can be connected to a light source. The electrical conductor can be connected to a logging system. In the case of hydraulic fluids, a pressure monitoring system can be connected to the conduit.

Optical Fiber in the Alternative Path Conduit Optical fibers may be inserted in the alternative path conduit by connecting a pump to the provided port on the instrument pod 17. Silicon gel or another fluid can be pumped into the annulus of the alternative path conduit and fiber optic cabling is fed into the pumping silicon gel (or other fluid) which carries the line into the well bore due to the frictional force of the silicon (or other fluid) against the fiber optic line. Upon reaching total depth, the pumped fiber is fully deployed in the wellbore. Fluids that may be used for deployment include liquids such as water as well as gases such as air or nitrogen.

If the alternative path conduit has been connected with a U-connection within the wellbore, the fiber optic cabling will be transported through the tubing and either egress the well at the welihead or be transported back to the instrument pod by the pumping. The disposition of the optic fiber in the wellbore permits the instrument pod 17 to sense with the use of the optical time domain reflectometry apparatus described in United States Patent No. 5,592,282 to Hartog which is incorporated herein by reference and made a part hereof for all purposes, the thermal profile (distributed temperature measurement) of each well into which the line is disposed providing inflow conformance. The disposed fiber optic line also permits monitoring of production or well conduit integrity thereby permitting detection of leaks in the casing or production string. The fiber optic line also permits the monitoring of gas lift valves from the thermal profile of the well.

In other embodiments, the fiber optic line may include one or multiple sensors or sensor locations. The sensors or sensor locations are adapted to measure a parameter of interest, such as temperature, distributed temperature, pressure, acoustic energy, electric current, magnetic field, electric field, flow, chemical properties, or a combination thereof. The sensors may be fiber optic sensors, electrical sensors, or other types.

Further, the alternative path conduit can be used to pump both multi- mode and single mode optic fiber into the same well bore thereby permitting calibration and correlation of backscattering signals to improve the resolution of the optical time domain refractometry analysis of deep subsea wells.

In an alternative embodiment, an electrical cable can be disposed in the alternative path conduit instead of the optical fiber. The electrical cable may include one or more sensors or sensor locations, as in the case of the optical fiber. The optical fiber and the electrical cable are generally referred to herein as a "cable." Electrical Conductor in the Alternative Path Conduit Well logging is often accomplished by disposing a tool down a wellbore with a variety of tools located thereon. These tools may be inserted into the well bore, adjacent the production flow line, and therefore never risk causing obstruction or damage to these very expensive deep water well projects. Any cased hole logging tool can be disposed and run from a tubular member adjacent the production tubing. These include, without limitation, neutron decay detector scanning, gamma ray logging, magnetic resonance logging, seismic sensing, and the like. For example, referring now to Fig. 3, if conduit 16 was 2 inches in diameter, normal well logging tools could be easily inserted in the well bore to the full extent of the well bore. These tools could be easily pumped down the annulus of conduit 16 through welihead 9 and into the larger diameter side of the U-shaped subsea conduit 11. The logging techniques could be accomplished from the buoy, or the tools could be permanently deployed to allow all varieties of common logging techniques to be accomplished with the deployed tools. These tools could be inserted to the total well depth either from the moon pool of the drilling rig as it completes the well or from the instrument pod 17 after placement on the deck of a service vessel.

Operation of the Alternative Path Pod and Lines The alternative path conduit and instrument pod allows an extension of the welihead to the sea surface for control, logging and sampling lines. The instrument buoy would be deployed after connection with the submersible conduit from a regular buoy tender vessel. Since the buoy is much closer to the subsea welihead than the remote production platform, control lines may be easily used to log well inflow conformance by real-time temperature profiles. If more than one well in a field is provided with the alternative path conduit and buoy system, a real time reservoir profile may be developed by combining the information received from each alternative path instrument pod.

This information may be transferred from each instrument pod to either a production platform or land based radio station and processed and provided over modern communication channels to knowledge workers interested in well production and characteristics.

The instrument pod may also be used as a staging area for remotely activated well shutoff controls which would shut-in a well as required by reservoir engineers for the reasons well known to those having skill in this industry. A command could be issued to the instrument pod which would thereafter executed either an acoustic, electrical, or photonic signal to a subsurface valve to shut in the well.

Service and Repair of the Alternative Path Pod and Lines Service of the alternative path pod and lines can be readily accomplished from regular surface vessels and remotely operated subsea vehicles (ROVs) presently used to service subsea wells. As required, the service vessel would be called to service each buoy with fuel (if required to run generators), glycol or other chemicals (if need to pump into the well zone), or replace or service cabling or conduit run into the alternative path. The pod would be lifted onto the work vessel by crane or other lifting means. The rise and fall of the vessel would not prevent the servicing of the conduit. A pump would be connected to the conduit and the optic fiber line could be washed from the conduit. Alternatively, new lines may be inserted into the alternative path conduit by pumping in a manner well known to those providing current well service.

Since the conduit is continuous from the surface into the well bore and back to the surface in the preferred embodiment. The introduction of cabling, or conductors into the well bore can be enhanced by filing the conduit with a low-denisity hydraulic medium, such as nitrogen gas, and then pumping in the lines one side while bleeding off the gas from the other side of the continuous looped circuit. It is noted that the alternative path conduit, through its different

methods of communication as previously disclosed (such as optical fiber, electrical cable, and hydraulic fluid) can act as a means to send commands from the pod to devices located in the wellbore. For instance, a command to set the packer 6 may be sent from a remote location to the pod and from the pod down the alternative path conduit to the packer. Provided the command sent is the "set packer" command, the packer is then set. Besides a packer, devices that can be controlled include but are not limited to valves (such as flow control valves), perforating guns, and tubing hangers.

The proceeding are examples of deploying permanent or temporary monitoring devices D within the alternative path conduit, including the deployment of cables, logging tools, memory tools, seismic arrays, and sensors. Figure 3 schematically illustrates a device D being deployed within the alternative path conduit.

While particular embodiments of the invention have been described herein, this application is not limited thereto. It is intended that the invention be as broad in scope as the art may allow and that the specification and claims be interpreted accordingly.

Claims

1. An apparatus for logging, controlling, or monitoring a subsea well, the apparatus comprising: a casing string disposed in a subsea well; an alternative path conduit permanently disposed proximate the casing string and passing through a subsea welihead, the alternative path conduit being connected to a hydraulic wet connector; a production tubing located within the casing string; and a flotation pod connected to the alternative path conduit through the hydraulic wet connector.

2. The apparatus of claim 1, wherein the alternative path conduit is Ushaped and provides an ingress and an egress on the welihead.

3. The apparatus of claim 1, wherein the alternative path conduit is located between an exterior surface of the casing string and the wellbore.

4. The apparatus of claim 1, wherein a cable is deployed within the alternative path conduit.

5. The apparatus of claim 4, wherein the cable comprises an optical fiber.

6. The apparatus of claim 4, wherein the cable comprises an electrical cable.

7. The apparatus of claim 4, wherein the cable is deployed by fluid drag.

8. The apparatus of claim 1, wherein the alternative path conduit provides a path for data transmission.

9. The apparatus of claim 1, wherein a device is deployed within the alternative path conduit to measure a parameter of interest.

10. The apparatus of claim 9, wherein the parameter of interest is temperature, distributed temperature, pressure, acoustic energy, electric current, magnetic field, electric field, flow, chemical properties, or a combination thereof.

11. The apparatus of claim 1, further comprising a memory recording device adapted to be deployed through the alternative path conduit.

12. The apparatus of claim 1, further comprising a logging tool adapted to be deployed through the alternative path conduit.

13. The apparatus of claim 1, wherein the alternative path conduit is cemented in place.

14. The apparatus of claim 13, wherein the alternative path conduit is cemented in place between an exterior surface of the casing string and the wellbore.

15. The apparatus of claim 1, wherein a monitoring device is deployed permanently in the alternative path conduit.

16. The apparatus of claim 1, wherein a monitoring device is deployed nonpermanently in the alternative path conduit.

17. The apparatus of claim 1, wherein a command is transmitted through the alternative path conduit to control a device located in the well.

18. The apparatus of claim 1, further comprising additional alternative path conduits disposed proximate the casing string and passing through a subsea welihead.

19. A method of monitoring a sub sea well, the method comprising: deploying a floating instrument pod proximate to the well; connecting the pod to an alternative path conduit; deploying the alternative path conduit proximate to a casing string within the well; and communicating through the alternative path conduit between the instrument pod and the well.

20. The method of claim 19, further comprising partially supporting the alternative path conduit by a submerged flotation device.

21. The method of claim 19, further comprising attaching a sub sea anchor to a sub sea pile to maintain the instrument pod proximate the well.

22. The method of claim 19, further comprising: receiving data at the instrument pod from the well through the alternative path conduit; processing the data; and transmiting the data from the instrument pod to a remote location.