WO2015135918A1

WO2015135918A1 - Monitoring system and method

Info

Publication number: WO2015135918A1
Application number: PCT/EP2015/054923
Authority: WO
Inventors: Andre Martin Van Der Ende
Original assignee: Paradigm Technology Services B.V.
Priority date: 2014-03-11
Filing date: 2015-03-10
Publication date: 2015-09-17
Also published as: GB201404285D0

Abstract

A monitoring apparatus for monitoring a coated line 10 in use and an associated line handling system, method and controller, wherein the coated line 10 includes a coating disposed around a core, the monitoring apparatus being configured to determine at least one property and/or operational parameter of the line and to monitor or determine an integrity of the line and/or a risk of failure of the line from the at least one property and/or operational parameter of the line. Optionally, the monitoring apparatus includes or communicates with one or more measurement device 325, 330 for measuring and/or determining the at least one property of the line or parts or portions of the line.

Description

MONITORING SYSTEM AND METHOD

FIELD OF THE INVENTION

The present invention relates to a monitoring system and corresponding method, and in particular to a wireline integrity monitoring system and method for monitoring for damage, defects and other changes in wireline.

BACKGROUND TO THE INVENTION

In industries such as oil and gas production and exploration, tools can be lowered into wellbores on various types of flexible wireline, for example, during well service operations or logging operations. Lowering tools on a flexible wireline is generally considered to be faster and less costly than lowering tools on a drill or tubing string of rigid jointed tubes or coiled tubing. Two general types of flexible wireline are commonly used, namely slickline and electric line.

Slickline comprises a single strand of steel wire. Slickline is used, for example, to lower and retrieve devices such as mechanical tools and data logging tools (commonly known in the industry as memory tools) into or from the well. Electric line comprises electrical cable and is generally braided. As a cable, slickline is generally lower cost, has fast running speeds, and the ability to form a pressure seal around the line at the wellhead by using a device called a stuffing box. This enables safer wireline operations in a live well compared with stranded electric line, which is much more difficult to seal effectively. Slickline is deployed into the well, for example, from a motorised reel that stores the cable and also acts as a winch, lowering or raising the tools in the well by rotating the reel and thereby spooling or unspooling cable from the reel.

A new type of slickline, known as a coated slickline or insulated slickline, comprises a single strand of steel wire coated with a thin polymeric layer. This combines the advantages of both electric line and slickline in a new type of wireline cable. The coating covers the conventional slickline with a thin, hard, durable, non- conductive and flexible coating. However, even though the polymeric coating is generally hard wearing, various factors can result in, or contribute to, damage to the wireline and particularly to the polymeric coating.

For example, the coated slickline could rub or slide abrasively against other components such as the steel casing in a well during well service operations. It will be appreciated that any such contact could result in damage to the coating layer and create an insulation loss or present a safety hazard in the stuffing box. In addition, the coated slickline is often forced through a number of reversing bends, for example, over sheaves or pulleys, before the slickline enters the well. The repeated bending of the slickline may cause the coating to come away from the steel wire core, which could potentially create a safety hazard in the sealing stuffing box. The coated slickline could also be subjected to rough handling by wireline personnel, which could again potentially damage the coating.

It will be appreciated that the damage to the coating may build up gradually over time and/or be caused by a single event. Damage to the coating often remains undetected until it leads to disruption or presents a hazard during wireline operations. SUMMARY OF THE INVENTION

According to a first aspect of the present invention there is provided a monitoring system for monitoring a line.

The monitoring system may be configured to monitor the line whilst the line is in use or in-situ, for example as part of a line handling operation, such as moving, deploying or retrieving tools or other payload using the line, e.g. into or from a wellbore. The line handling operation may comprise a well service operation or logging operation.

The monitoring system may be configured to determine at least one property and/or operational parameter of the line or a part or portion of the line, e.g. while the line is in use. For example, the monitoring system may comprise and/or be configured to communicate with at least one, and preferably a plurality of, measurement devices for measuring or determining the at least one property and/or operational parameter of the line or the part or portion of the line. The measurement devices may be selectively activated or operable.

The monitoring system may be configured to monitor or determine an integrity of the line and/or a risk of failure of the line from or using the determined at least one property and/or operational parameter of the line.

At least one of the measurement devices may comprise a dimensional sensor for measuring one or more dimensions or dimensional properties of the line or of the one or more parts or portions of the line, such as one or more thicknesses or diameters of the line, and/or a profile or shape of the line, such as an outer cross sectional shape or profile and/or a degree of roundness or ovality and/or a length of the line or part of the line and/or a stretching of the line. For example, at least one of the measurement devices may comprise at least one of: one or more laser scanners (dual axis or rotary), one or more sonic or ultrasound scanners, radiation (e.g. x-ray, gamma ray, alpha or beta radiation and/or the like) scanners, optical, infrared or ultraviolet scanners, mechanical sensors such as callipers or sheaves, induction sensors, capacitance sensors and/or the like and/or any combinations of the above. In this way, the monitoring system may be configured to identify any dimensional properties or changes in the line that may be indicative of damage or potential failure, such as bulges, constrictions, nicks, cuts, indentations, protrusions, stretches and/or the like.

The monitoring system may comprise one or more devices for measuring length, position or location on the line or line speed. The devices for measuring length, position or location on the line or line speed may be configured or operable to determine at least one position on the line and/or the part or portion of the line for which the at least one property and/or operational parameter has been determined.

The line monitoring system may be configured to monitor or determine the integrity of the at least one position, part or portion of the line and/or a risk of failure of the at least one position, part or portion of the line from or using the at least one property and/or operational parameter associated with that position, part or portion of the line.

For example, the line may comprise a plurality of markers, which may be provided at predetermined, known or defined locations or spacings. The markers may be provided periodically along at least part or all of the length of the line. The markers may comprise visual or optical markers. The markers may comprise magnetic markers, reflective markers, radiation emitters and/or other measurable and/or detectable types or markers known in the art. The markers may be machine readable. The markers may be non-visible markers.

The devices for measuring length, position or location on the line or line speed may comprise one or more of: a reader or detector for detecting the markers on or in the line, a rotary encoder, an optical, sonic or radiation based measurement device, a Doppler effect device, a time of flight measurement device, a device for measuring rotation of a drum, pulley, winch or other rotating apparatus upon which the line is wound, mounted or passes round, over or through, and/or the like. The measurement device may comprise an optical sensor such as a digital camera and/or video camera, a CCD sensor, a CMOS sensor, a photodiode array, a magnetic reader or sensor for sensing or determining magnetic markings, a UV, IR or fluorescence sensor, and/or the like. The monitoring system may comprise an activator for activating the markings, such as a magnetic source, a UV or IR source, a radiation source and/or the like.

One or more of the properties or operational parameters of the line or of the parts or portions of the line, such as a number or degree of line stretches, may be determined using the devices for measuring length, position or location on the line or line speed. For example, stretching may be determined by comparing at least one measured spacing between markers with at least one previous, predetermined or theoretical spacing or by comparing the spacings measured by two techniques or devices for measuring length, position or location on the line or line speed, such as a difference between a spacing determined by the marker reader or detector and a spacing determined by a rotary encoder or other device or by measuring differences in the spacings between the markers at different sections of the line handling apparatus.

The line may be or comprise a wireline, such as a slickline, preferably a coated or insulated wireline or slickline. The coated or insulated wireline may comprise a core, such as a wire core, e.g. a single strand or unbraided core. The core may comprise a metal core or a fibre composite core, such as a polymeric fibre composite core and/or the like. The composite core may comprise one or more conductors, such as metallic, carbon fibre or ceramic conductors, and one or more fibres, which may comprise unidirectional, woven, braided, or intertwined fibres. The fibres may comprise polymeric fibres, such as Vectran, Kevlar, Nomex, or other aramid fibres, nylon, polyester, acrylic, polyethylene and/or polypropylene fibres, and/or derivatives thereof, for example. The coated or insulated wireline may comprise a coating around at least part, and preferably all, of the length of the core, e.g. on a radially outer surface of the core. The coating may comprise a polymeric coating. The coating may comprise an electrically insulating coating. The coating may comprise a chemically resistant or inert coating. The coating may be more chemically resistant than the core, e.g. be more resistant to acid, alkali, corrosion or oxidising agents than the core.

By providing an electrically insulating coating, communications signals and power may be communicated using the line. By providing a chemically resistant or inert coating, a core having lower cost and/or more favourable tensile or other properties may be used in chemically unfavourable environments.

At least one of the determined properties of the line or the part or portion of the line may comprise a property associated with the coating of the line. At least one of the determined properties of the line or the part or portion of the line may comprise a property associated with the core, e.g. with the fibre composite core.

At least one of the measurement devices may comprise a coating or coating integrity measurement device for measuring or determining the at least one property associated with the coating of the line, such as an insulation value, weak points, holes, cuts, passages, and/or thick or thin sections in, or changes or variations in thickness of, the coating and/or a degree of bonding, proximity and/or separation between the coating and the core and/or a degree of concentricity of the coating and core. For example, at least one of the measurement devices may comprise a laser scanner, sonic or ultrasonic scanner, radiation scanner, optical, infrared or ultraviolet scanner, a device for determining or measuring an electrical resistance or impedance of the coating such as an AC impedance spectroscopy unit, a mechanical probe, a spark sensor, a capacitance and/or inductance sensor, an optical sensor or camera or video camera, an x-ray or other radiation sensor and/or the like.

As would be appreciated from the above, examples of the at least one property of the line or of the parts or portions of the line may comprise one or more of: at least one diameter or cross-sectional profile, a degree of stretch, an insulation value, a determination of holes, cuts, passages and/or thin sections of the coating, a degree of proximity, bonding or separation between the coating and core and/or a degree of concentricity between the coating and the core and/or the like.

The monitoring system may be configured to monitor or determine an integrity of the coating and/or parts or portions of the coating and/or a risk of failure of the coating and/or parts or portions of the coating from or using the determined at least one property associated with the coating.

At least one of the measurement devices may comprise at least one of: a temperature, pressure, humidity, strain, stress or load sensor. The at least one stress, strain or load sensor may be configured to determine a stress, strain or load on the line or on the parts or portions of the line.

The at least one operational parameter may comprise at least one parameter associated with at least one operation, which may be at least part of the line handling operation, to which at least a part or portion of the line is subjected in use. The operation may comprise an operation in which at least the part or portion of the line is bent, stretched, or otherwise stressed or strained, such as being subject to, passing over, round or through a handling device such as a drum, pulley, guide or the like. The at least one operation may comprise a reversal in a direction of motion of the line, and/or its running speed or changes in running speed and/or a force, stress, tension, load or strain applied to at least the part or portion of the line and/or a temperature or humidity or other environmental parameter to which at least the part or portion of the line is subjected. The operational parameter may comprise the number of times the part or portion of the line has undergone the operation and/or a magnitude or other parameter of the operation. In this way, the monitoring system may determine, for example, a number of times that one or more portions of the line has been subjected to an operation (which may contribute to wear or damage of the line), which in turn can be used to determine or predict integrity, damage, wear or other changes or risks of failure in the line, preferably along with the location or position on the line where such damage, wear or other changes in the line have occurred or are likely to occur.

The monitoring system may be adapted to determine whether a part or portion of the line has undergone an operation and/or the number of times the part or portion of the line has undergone an operation based on the determination of the position and/or location on the line, which may, for example, be cross referenced against a record or look-up table of the location of components of an associated line handling apparatus or other stress or strain locations relative to the one or more devices for measuring the length, position or location on the line or line speed. For example, if it is known that pulleys are positioned at X and Y metres downstream of the device for measuring the length, position or location on the line, and the device for measuring the length, position or location on the line determines that a point A on the line is currently at its measurement location, then it may be determined that the parts or portions of the line that are at points A+X and A+Y are being subjected to a stressing/bending operation (i.e. on the pulleys).

The monitoring system may be configured to create, store, access and/or update a database, log or record associated with the line or at least the parts or portions of the line. The database, log or record may comprise or store the determined values of the at least one property and/or operational parameter. The database, log or record may comprise a plurality of measurements or determinations of the at least one property and/or operational parameter, or variations therein, taken over time. For example, the log may record a number of times each part or portion of the line has undergone an operation, such as a bending or stretching or loading operation.

The database, log or record may comprise initial or calibration data, which may for example, be measured or determined during or after production or before first use. The initial or calibration data may comprise or represent the properties and/or parameters of the line or parts or portions of the line in an initial, new, or reference state.

The database, log or record may comprise one or more other operational parameters, such as winch operation parameters, details of the tools or tool string, and/or wellbore parameters such as well geometry, well conditions, well temperature, pressure and the like.

The monitoring system may be configured to at least partially determine the integrity or condition or a risk of failure of, and/or damage, anomalies, wear or other changes in, the line or the parts or portions of the line, e.g. in the coating, by determining variations or changes in the at least one property of the line, for example, by comparison with the initial or calibration data and/or previously measured and/or determined values of the at least one property and/or operational parameter. The initial or calibration data and/or previously measured and/or determined values of the at least one property and/or operational parameter may be stored in and/or retrieved or retrievable from the database, log or record.

The monitoring system may be configured to at least partially determine the integrity, risk of failure, condition of and/or damage, anomalies, wear or other changes in the line and/or in the one or more parts or portions of the line, e.g. in the coating of the line, by determining if the at least one property and/or operational parameter and/or variations therein exceeds and/or falls below one or more limits or thresholds or falls outwith a range, which may comprise preset or predetermined limits, thresholds and/or ranges. The limits, thresholds and/or ranges may be determined from prior operational data, experimental data, testing, modelling, and/or the like.

The monitoring system may be configured to apply statistical or numerical analysis based on the determined properties and/or operational parameters associated with the line and/or variations therein and/or the determined positions on the line in order to determine an integrity and/or risk of failure of the line or the parts or portions of the line.

The monitoring system may comprise an id reader for reading an id of the line. The id reader may comprise one or more of: a camera, a 1 , 2 or 3D barcode reader, a magnetic marking reader, a RFID tag reader and/or the like. The monitoring system may be configured to retrieve, access, create and/or update the database associated with the determined line, e.g. the database of properties and/or parameters may be line specific. The monitoring system may be configured to record the determined properties and/or parameters and/or location or position in a database associated with the identified line.

The monitoring system may comprise a line cleaner. The monitoring system may comprise an oiler.

By providing a monitoring system as described above, to monitor the wireline in use or in the field, it may be possible to detect or predict potential damage, failures, wear or deteriorations in the integrity of the line and may help prevent unwanted incidents and events. The monitoring system also provides a means for keeping track of line usage, e.g. for commercial purposes. For example, by determining and recording operational parameters, such as a number of reversals, tensile load on the line and/or which parts or portions of the line are subject to the reversals and/or tensile loads, it may be possible to determine a measure of fatigue and/or whether a safe working load has been breached or other considerations associated with the core tensile strength. Similarly, by determining and recording operational parameters such as a number of reversals, a tensile load on the line and which parts or portions of the line are subject to the reversals and/or tensile loads and the properties of the line such as an insulation value of the coating at those locations, it may be possible to determine or predict electrical insulation problems or failures.

Determining properties of the line, such as outer line shape or size, anomalies such as bulges or necks, and/or by performing measurements such as laser scans, insulation tests and ultrasonic testing, it may be possible to determine variations in outer coating diameter or ovality (which may lead to sealing failures), scratches, nicks or cuts in the coating (which may lead to sealing failures and/or electrical issues) and/or de-bonding of the coating (which may also lead to sealing or electrical failures).

Since the monitor may be configured to determine and track the position of parts or portions of the line and record these in a log or database associated with the particular line, it may be possible to determine cumulative operations and wear and/or or track variations in the properties of the line at specific locations over time. This may be significant as some failure and/or wear mechanisms may be localised.

According to a second aspect of the present invention is a line handling system comprising, or adapted to communicate with, at least one monitoring system of the first aspect.

The line handling system may comprise at least one line handling apparatus. The line handling apparatus may comprise at least one drum, winch or spool upon which the line may be wound or windable. The line handling apparatus may comprise at least one pulley, sheave and/or guide over with the line may be passed. The line handling apparatus may comprise at least one stuffing box or other sealing mechanism, through which the line may pass. The stuffing box or other sealing mechanism may be adapted to seal the line, e.g. to prevent escape of fluid from a well. The line handling system may be configured to lower and/or retrieve the line into/from a well or borehole, such as an oil well.

One or more tools, devices or payload items may be attached or attachable to a distal end or toe end of the line, e.g. distal from the at least one line handling apparatus. In other words, the distal end may be an end of the line that is inserted or insertable into the well or borehole.

The line handling apparatus may be configured to carry out wireline well- services and/or well logging services. The line handling system may comprise a controller, which may be configured to operate the line handling apparatus, e.g. a winch motor, for example, in order to vary a rotational speed, torque and/or direction of rotation or operation.

The line may comprise or be provided with an identifier, such as a wireless identifier, e.g. a RFID tag, optical or visual tag, 1 D, 2D or 3D barcode, and/or the like. The identifier may comprise or encode a unique identifier for the line. The line handling system and/or the controller and/or the monitoring system may be operable to read the identifier, e.g. to identify the line. For example, the line handling system and/or monitoring system may comprise a reader for reading the identifier. The reader may comprise a camera or video camera, such as a digital camera or video camera, a CMOS sensor, a CCD sensor, a photodiode array, a magnetic sensor such as a magnetic ink character reader (MICR), a radio frequency sensor, a UV, IR or fluorescence sensor and/or the like.

The monitoring system may be operable to monitor or determine the one or more properties or parameters at selected or determined locations and/or times or time intervals.

The monitoring system and/or line handling apparatus may comprise a line cleaner such as a brush, wiper, spray and/or the like. The monitoring unit and/or line handling apparatus may comprise an oiler or other lubrication system, for oiling and/or lubricating the line.

The monitoring system and/or handling apparatus may comprise an activator for activating markers in or on the line. The activator may comprise a magnetic source, which may comprise at least one permanent magnet or an electromagnet such as a solenoid coil. The magnetic source may be adapted to magnetise or magnetically energise the line, e.g. to energise or activate or selectively activate the one or more markers on the line. Additionally or alternatively, the activator may comprise a UV or IR source, a laser, a radio frequency source, a radiation source, a thermal source, and/or the like.

The controller and/or one or more monitoring system may be adapted to communicate with each other and/or a remote system or device, which may be via a wired or wireless connection, e.g. via cellular, wi-fi, Bluetooth^R™ or Zigbee^R™ communications. The remote system or device may comprise a remote server or other computing or processing system or device. The controller and/or monitoring system may be configured to communicate the one or more properties and/or operating parameters and/or at least one property derived therefrom, such as the integrity or condition, of the one or more parts or portions of the line. The wire handling system may be operable or configured to move the line and/or tools, devices and/or other payload items. For example, the wire handling system may be configured to dispense the line into and/or retract the line out of a bore or well, for example, during use in oil and gas exploration and/or production. The wire handling system may be comprised in or adapted for use with a wellhead system or the like.

According to a third aspect of the present invention is a method for monitoring a line, such as a wireline, preferably a coated or insulated wireline. The method may comprise using one or more monitoring systems according to the first aspect and/or a line handling apparatus according to the second aspect.

The method may comprise determining at least one property and/or operational parameter of the line, for example, by using at least one measurement device.

The method may comprise measuring and/or determining the at least one property and/or operational parameter associated with at least one and preferably a plurality of parts or portions of the line. The method may comprise identifying or determining a part or portion of the line associated with the measured or determined properties and/or operational parameters, e.g. the part or portion of the line being measured by the at least one measurement device.

The method may comprise determining a length, position or location on the line. The length, position or location may comprise a length, position or location of the part or portion of the line being measured by the at least one measurement device.

The method may comprise identifying one or more markers on the line, wherein the markers may be indicative of length, position or distance along the line.

For example, the markers may be periodically spaced markers. The markers may be associated with known and/or predetermined spacings, lengths, positions and/or locations along the line.

The method may comprise using one or more of the measurement devices to determine a length, position or location. For example, the measuring device may comprise a reader for detecting the markers on or in the line, a rotary encoder, an optical, sonic, radiation or radiation based measurement device, a Doppler effect device, a device for measuring rotation of a drum, pulley, winch or other rotating apparatus upon which the line is wound, mounted or passes round, over or through, and/or the like.

By using the position, length and/or location on the line of the at least one or each part of portion of the line, it may be possible to determine how many times the at least one or each part or portion of the line has been subject to an operation and/or a magnitude of the operation, such as bending, stretching, flexing, straining, stressing, and/or being handled by a piece of apparatus such as a pulley, drum, winch, guide, and/or the like. This determination of how many times the at least one or each part or portion of the line has been subject to an operation and/or the magnitude of the operation may be comprised in operational parameters used to determine an integrity or condition or risk of failure of the line.

The method may comprise maintaining a log or record associated with the line, e.g. of the one or more parts or portions of the line. The log or record may comprise the at least one property of operational parameter of the line, e.g. of the one or more parts or portions of the line. The log or record may comprise a plurality of measurements or determinations of the at least one property and/or operational parameter, or variations therein, taken over time. The log or record may comprise initial or calibration data, which may, for example, be measured or determined during or after production or before first use.

The method may comprise determining the integrity, condition of, and/or damage, anomalies, wear or other changes in the line and/or in the parts or portions of the line, e.g. in the coating of the line, by determining variations or changes in the at least one property of the line, for example, by comparison with the initial or calibration data and/or previously measured and/or detected values of the property and/or operational parameter, which may be comprised in the log or record.

The method may comprise determining the integrity, condition of, and/or damage, anomalies, wear or other changes in the line, e.g. in the coating of the line, by determining if the at least one property and/or operational parameter of the line exceeds and/or falls below one or more limits or thresholds or falls outwith a range, which may comprise pre-set or predetermined limits, thresholds and/or ranges.

The method may comprise identifying the line, e.g. by reading an identification tag or other identifier on or associated with the line. For example, the identifier or tag may comprise a 2D or 3D barcode or a RFID tag or the like. The method may comprise spooling and/or unspooling the line to / from a winch or drum. The method may comprise passing the line through the monitoring system, e.g. immediately after or as it is unspooled from the reel, before it passes through a line handling component and/or immediately before being passed through a stuffing box.

The method may comprise cleaning the line. The method may comprise activating markers in or on the line, e.g. by magnetically energising the line.

The one or more properties of the line may comprise parameters of a coating and/or a core or wire and/or a core/coating interface of the line. The method may comprise performing a trend analysis or other statistical procedure in order to predict or estimate upcoming failures, faults or defects in the wireline or a higher than threshold probability of such failures, faults or defects.

The method may comprise measuring or determining the one or more properties and/or parameters of the line whilst it is being deployed, unspooled or lowered into the well and/or whilst it is being withdrawn, spooled or raised from the well.

According to a fourth aspect of the present invention is a controller for controlling the monitoring system of the first aspect and/or the line handling system of the second aspect. The controller may be configured to implement the method of the third aspect.

The controller may comprise or be configured to communicate with at least one of: one or more processors, one or more memories or data stores, and/or a communications interface, such as a wired and/or wireless communications interface. The controller may be configured to communicate with the monitoring system and/or the line handing system via the communications interface, e.g. in order to send control signals to the monitoring system and/or the line handing system and/or to receive data such as measurements of properties of the line and/or operational parameters of the line handling apparatus.

The processor may be configured to determine an integrity or condition or one or more properties and/or operational parameters of one or more parts or portions of the line, e.g. from the data received from the monitoring system and/or the line handing system. The memory or data store may be configured to store the database, log or record of the at least one property and/or operational parameter of at least the parts or portions of the line.

According to a fifth aspect of the present invention is a production apparatus for producing a line. The production apparatus may comprise one or more monitoring systems according to the first aspect. The line may comprise a wireline such as a coated line and may particularly comprise a coated slickline.

The production apparatus may comprise a pay-out unit for dispensing or unreeling an elongate core or wire such as a metal or polymeric composite wire. The core or wire may comprise a single strand and/or unbraided core or wire.

The production apparatus may comprise one or more dimensional scanners (e.g. a laser scanner) and/or at least one of the monitoring systems arranged to measure and/or determine one or more properties or parameters of the core or wire.

The dimensional scanner and/or monitoring system may be located so as to monitor the uncoated core or wire after it is dispensed or unreeled from the pay-off unit. The production apparatus may comprise a preparation unit, which may be configured to prepare the core or wire for coating. The preparation unit may comprise one or more of: a cleaning or surface preparation unit, such as a corona or solvent treatment unit, or an abrasion cleaning or abrasion unit for abrading the surface of the line, or a thermal treatment unit or an etching unit, such as a chemical etching unit.

At least one of the dimensional scanners and/or at least one of the monitoring systems may be arranged to measure and/or determine one or more properties or parameters of the core or wire as or after it leaves the preparation unit, e.g. before it enters a coating unit.

The production apparatus may comprise a coating unit. The coating unit may be adapted to coat the core or wire, e.g. in a polymeric coating. The coating unit may comprise a dry powder spray unit, e.g. for spraying a dry polymeric powder onto the core or wire. The coating unit may comprise a wet spray unit, such as a wet polymeric spray unit. The coating unit may comprise a hot spray unit, e.g. for spraying molten polymer onto the core. The coating unit may comprise one or more extruders and/or co-extrusion units. The coating unit may be configured to apply a multi-layer coating. The coating unit may comprise at least one post coating or treatment unit, such as a dryer, thermal treatment device, radiation treatment device, cooler and/or the like.

At least one of the dimensional scanners and/or at least one of the monitoring systems may be arranged to measure and/or determine one or more properties or parameters of the line as or after it leaves the coating unit. For example, the at least one of the dimensional scanners and/or the at least one of the monitoring systems arranged downstream of the coating unit may be configured to determine at least one of: diameter and/or ovality/roundness of the line, and/or at least part or all of one or more cross sectional profiles of the line or the one or more parts or portions of the line, e.g. of the coating, or at least one coating fault in the line, such as necks, lumps, holes, weak or thin points and/or the like.

The production apparatus may comprise a plurality of scanner and/or monitoring types, e.g. downstream of the coating unit. For example, the production apparatus may comprise two or more of: at least one dimensional scanner (e.g. a laser scanner, calliper, radiation gauge and/or the like), at least one induction monitor, at least one high voltage spark sensor, at least one electrical impedance or resistance monitor, at least one ultrasound scanner, and/or the like.

The production apparatus may comprise at least one length or position measuring device, such as a rotary encoder, Doppler or time of flight sensor, rotational sensor on the wind or unwind drum or reel or pulley or tensioner and/or the like. The length or position measuring device may be configured to determine a production line speed and/or a position, location or line length of the one or more parts or portions of the line. The length or position measuring device may be configured to determine a position or length on or along the line at which the properties or parameters were determined.

The production apparatus may comprise a controller. The controller may be arranged to receive data collected by the length or position measuring device and/or the dimensional scanners and/or monitoring systems.

The production apparatus may comprise apparatus for winding the line onto a reel or drum. The reel or drum may be provided with an id tag or other identifier or the production apparatus may be adapted to apply an id tag or identifier to the reel or drum. The id tag or identifier may comprise a machine readable id tag or identifier.

The production apparatus may comprise storage means for recording or storing the one or more properties and/or parameters of the line measured or determined by the one or more dimensional scanner(s) and/or monitoring systems and/or the associated position or length on or along the line. The properties and/or parameters may be associated with the id tag or identifier for the line. The associated id or identifier may be stored by the storage means or memory.

The production apparatus may comprise a marker module for applying one or more or a plurality of markers in or on the line. The markers may be indicative of a position or length along the line. For example, the markers may be applied at predetermined, known or defined locations or spacings. The markers may be provided periodically along at least part or all of the length of the line. The marker module may be configured to selectively apply the markers responsive to a determination of the position or length on or along the line by the length or position measuring device.

At least one of the markers may indicate faults or defects. At least one of the markers may be indicative of a line id.

The markers may comprise visual or optical markers. The markers may comprise magnetic markers, reflective markers, radiation emitters and/or other measurable and/or detectable marking techniques known in the art. The markers may be non-visible markers.

According to a sixth aspect of the present invention is a method of producing a line. The method may comprise use of the production apparatus of the fifth aspect.

The line may comprise a core or wire. The method may comprise applying a coating, such as a polymeric coating, to the core or wire. The method may comprise determining one or more properties of the core or wire and/or the coating. The one or more properties and/or parameters may be measured or determined by a monitoring system according to the first aspect.

According to a seventh aspect of the present invention is a controller for controlling a production apparatus according to the fifth aspect. The controller may comprise or be configured to access a memory, database or log. The controller may be configured to receive properties and/or parameters of a line, e.g. from one or more monitoring systems according to the first aspect. The controller may be configured to receive line position and/or length information, e.g. from one or more line length or position sensor. The controller may be configured to store the properties and/or parameters and/or the associated line position or length data in the memory, database or log.

According to an eighth aspect of the present invention is a measurement device for use with the monitoring system of the first aspect. The measurement device may comprise any feature of a measurement device described above in relation to any other aspect.

According to an ninth aspect of the present invention is a computer program product configured to implement or at least partially implement the apparatus of the first, second, fourth, fifth, seventh or eighth aspects of the present invention and/or the method of the third or sixth aspects of the invention.

According to a tenth aspect of the present invention is a carrier medium carrying or comprising the computer program product of the ninth aspect.

According to a eleventh aspect of the present invention is a processing apparatus provided or loaded with the computer program product of the ninth aspect.

According to a twelfth aspect of the present invention is a line. The line may be produced by the production apparatus of the fifth aspect or the method of the sixth aspect. The line may comprise an insulated line, which may comprise an electrically insulting coating around a core. The line may comprise a plurality of markings, which may be indicative of position or length.

It will be appreciated that features analogous to those described above in relation to any of the above aspects may be individually and separably or in combination applicable to any of the other aspects.

Apparatus features analogous to, or configured to implement, those described above in relation to a method and method features analogous to the use and fabrication of those described above in relation to an apparatus are also intended to fall within the scope of the present invention. BRIEF DESCRIPTION OF THE DRAWINGS

These and other aspects of the present invention will now be described, by way of example only, with reference to the accompanying drawings, in which:

Figure 1 is a schematic of a line production unit;

Figure 2a is a cross sectional view of the line shown in Figures 1 and 3;

Figure 2b is a longitudinal or axial view of a portion of the line of Figure 2a;

Figure 3 is a schematic of a line deployment system, including a line monitoring apparatus;

Figure 4 is a schematic of a line monitoring apparatus for use in the deployment system of Figure 3; and

Figure 5 is a flowchart showing a method of monitoring the integrity of a line in use.

DETAILED DESCRIPTION OF THE DRAWINGS

A production system 5 for producing a line 10, particularly a coated or insulated slickline, is shown in Figure 1 . As shown in Figure 2, the coated or insulated slickline comprises a core 15 that is, or is similar to, a conventional slickline, wherein the core 15 is coated in a non-conductive or insulating polymeric coating 20. In this example, the core 15 advantageously comprises a round metal single strand wire, but it will be appreciated that other core structures could be used, such as a long fibre polymeric composite slickline.

The production system 5 comprises a pay-out unit 25 from which the core 15 can be unspooled, a first measuring device 30 for determining one or more properties of the core, a preparation unit 35 for preparing the core for coating, a second measuring device 40 for determining one or more properties of the core 15 after it has been processed by the preparation unit 35, a coating unit 45 for applying the coating 20 to the core15, a third measuring device 50 for determining one or more properties of the line 10 after the coating 20 has been applied, a post coating treatment unit 55 for applying post coating treatments to the line, a length or position detector 60 for determining lengths or positions on the line 10, a marker unit 65 for applying markings to the line 10 and a take-up winch 70 for winding the line around a reel 75.

The pay-out unit 25 comprises a reel 80 upon which the bare core 15 is wound or windable. The reel 80 is selectively rotable by a motor 85 in order to unspool the core 15 from the reel 80. However, although the reel 80 is advantageously driven by the motor 85, it will be appreciated that in some situations a passive pay-out unit may be used instead. From the pay-out unit 25, the core 15 passes through the field of view of the first measuring device 30. The first measuring device 30 is adapted to monitor one or more dimensions, particularly cross sectional dimensions, of the core 15, such as a diameter in one or more cross sectional directions and/or an external shape or profile, such as a degree of ovality or roundness. Examples of suitable measuring devices include laser scanners, callipers or other suitable mechanical dimensional measurement devices, radiation based dimensional sensors, and/or the like. For example, the first measuring device 30 could comprise a dual axis or rotary oscillating laser scanner. Examples of other suitable sensors that could potentially be incorporated in the first measuring device 30 include temperature sensors, pressure sensors, rotation sensors, linear position sensors and/or proximity sensors.

Each of the first, second and third measuring devices 30, 40, 50 is in communication with a controller 90 for controlling the production system 5 and/or another suitable processing device. In this way, any parameters or properties of the core 15 or line 10 determined by the first, second and/or third measuring devices 30, 40, 50 can be fed back to the controller 90 and stored in a database 95, e.g. for use in future monitoring of the line 10, defect or failure prediction, quality control, or the like, and/or used by the controller 90 to adjust one or more process parameters or operating parameters of the production system 5.

The preparation unit 35 is located downstream of the first measuring device

30. The preparation unit 35 comprises one or more treatment systems 100a, 100b, 100c for treating the core 15 prior to coating. The treatment systems 100a, 1 10b, 100c or combinations thereof can be selected to suit the application and can include, for example, one or more of: solvent or corona cleaning or treatment 100a, abrasive cleaning or treatment 100b, thermal treatment 100c, and/or another suitable preparation unit known in the art such as a chemical etching unit. The treatment(s) can advantageously enhance the bonding of the coating 20 to the core 15.

The treated core 15 is inspected by the second measuring device 40, which is a dimensional scanner, similar to the first measuring device 30. In this way, one or more cross sectional dimensions of the core 15 after preparation can be determined.

As a result, unwanted effects on the core 15 due to preparation applied by the preparation unit 35 can be detected, and if necessary, operational parameters of the production system 5 altered, production paused or halted, or repair requested, for example.

Thereafter, the core 15 passes on to the coating unit 45. The coating unit 45 is arranged to coat a radially outer surface 105 of the core 15 with the coating 20, which comprises a polymeric, electrically insulating coating that forms an annular layer around the core 15. It will be appreciated that various mechanisms for providing the coating 20 exist. Examples of possible coating units 45 include dry powder spray units, wet spray units, e.g. for spraying a polymeric based paint, a hot spray unit for spraying molten polymer onto the core, one or more extruders or co- extruders or a combination of extruders or co-extruders and/or the like. It will be appreciated that the coating 20 could comprise a multilayer coating and/or in certain embodiments, the coating unit 45 can comprise one or more, e.g. a plurality of coating applicators, for applying a plurality of coating layers or coating types.

The line 10, now comprising a coated core 15, is inspected by the third measuring device 50 downstream of the coating unit 45. Optionally, the third measuring device 50 can comprise a plurality of measuring devices and/or be configured to determine a plurality of different property types. For example the third measuring device 50 can comprise at least one and preferably two or more from: a dimensional measuring device, such as or similar to the first and second measuring devices, for measuring one or more cross sectional dimensions or profiles of the line, and/or an induction scanner and/or a high voltage spark sensor and/or an electrical resistance or impedance sensor and/or a capacitance or inductance sensor, a camera and/or the like.

In this way, for example, the dimensional measuring device can determine one or more diameters of the line or coating, the profile of the line or coating, e.g. a degree of roundness or ovality, and detect coating faults or variations such as necks or lumps in the coating. One or more of the measuring devices can be operable to identify weak points or defects in the coating 20, such as pinholes, cuts, channels, passages through the coating, uncoated sections, thin coating points, less-dense coating sections and/or the like. A combination laser/induction scanner could be used as a measuring device, which can be particularly suitable for sensing concentricity, e.g. between the core and coating. Other suitable measuring devices comprise devices configured to determine electrical properties of the line, coating and/or core, such as capacitance, inductance, resistance, impedance and/or AC impedance sensors or scanners, which can be useful in detecting and measuring pinholes, pores, tears or other weak points or defects in the coating and/or in determining coating thickness, concentricity and/or coating/core interfacial properties such as degree of bonding, separation and/or any gaps or pockets in the coating or coating/core interface, as these coating/line properties can give rise to measurable variations in the measured or determined electrical properties. High voltage spark sensors may also be useful in detecting pores, or micro-pores, weak points, defects, pinholes and the like. Ultrasound, x-ray and other radiation based sensors or scanners can be useful in determining positions and shapes of the boundaries between the core, the coating and between layers therein. For example, each of the core, the coating and any gaps in or between the coating and/or core have different effects on the transmission, blocking, attenuation and/or reflection of the sound, x-ray or other radiation, which can in turn be used to determine coating properties such as coating thickness, concentricity, separation, and/or the like. Although various examples of measuring devices are given above, a skilled person would appreciate that the third measuring device 50 can comprise other measuring devices or varying combinations of measuring devices, depending on the application.

The post coating treatment unit 55 is an optional unit, configured to apply any post treatment required for the coating 20, such as heating, setting, cooling, radiation treatment, UV treatment, and/or the like. In this example, the post coating treatment unit 55 is provided downstream of the third measuring device 50. However, it will be appreciated that the third measuring device 50 could be provided downstream of the post coating treatment unit 55 or third measuring devices 50 could be provided both upstream and downstream of the post coating treatment unit 55.

The one or more line position or length sensors 60 allow positions on the line 10 and/or a length and/or direction of motion of line 10 that has passed through the position or length sensor 60 can be determined. For example, suitable position or length sensors 60 include rotary encoders, laser sensors or other non-contact sensors such as Doppler effect sensors, time of flight sensors and/or the like. The output of the position or length sensors 60 is communicated to the controller 90, along with any properties or parameters determined by the first, second and/or third measuring devices 30, 40, 50. The position of the first, second and third measuring devices 30, 40, 50 and/or marker unit 65 relative to the position or length sensors 60 are known. In this way, it is possible to determine the positions and/or parts or portions of the line for which the properties or parameters are determined by the first, second and third measurement devices 30, 40, 50. This may help with subsequent integrity and condition monitoring of the line 10 in use and/or in predictions of line failure and so on.

For example, if any of the measured or determined properties or parameters fall outwith a predetermined range, then the controller 90 can track the progress of the associated portion of the line 10 through the production system 5 using with the line position or length sensors 60 (from which line speed can be derived). In this way, the defective portion of the line 10 can be marked using the marking unit 55 to indicate a faulty section. This marking allows defective portions to be selectively removed from a final product line, which may allow quality to be maintained whilst minimising waste, as defective portions can be accurately tracked and/or identified, and removed.

The wire marking unit 55 is configured to apply markings to the line. It will be appreciated that the markings 1 10 could be visible markings on or in the line 10 but could also be markings 1 10 that are not visible to the human eye. However, the markings 1 10 should preferably be machine readable. Examples of suitable markings 1 10 include printed, inked and/or painted coatings, magnetic or ferromagnetic markings, reflective markings, luminescent or phosphorescent markings, UV or IR sensitive markings, electro-sensitive or conductive markings and/or the like. For example, the markings 1 10 may be inked on, engraved or embossed, e.g. laser engraved. The markings 1 10 may be formed from additives to the coating 20, for example to enhance the reflectivity or other property of the coating 20, such as magnetic or ferro-magnetic properties. In embodiments, the coating 20 comprises a selectively activatable compound (such as a laser sensitive polymer, pigment or dye). For example, the selectively activatable compound can be selectively activated by a laser, radiation, by a thermal process and/or the like in order to form the markings 1 10. The markings 1 10 could be colour coded and can be legible and/or symbolic. For example, the markings 1 10 could comprise a barcode or other machine readable indicia.

Advantageously, in embodiments, the markings 1 10 are indicative of position or length along the line 10. For example, the markings 1 10 can be applied periodically lengthwise along the line 10 so that they can be read by suitable reading apparatus in order to determine position on, or length along, the line 10. However, it will be appreciated that markings 1 10 could in principle be used for a variety of purposes such as marking sections of the line 10 having certain properties or defects or to indicate a line id or production batch or run number and/or the like.

Although the marker unit 65 is shown downstream of the coating unit 45, in this case immediately before the line 10 is spooled onto a reel 75 of the take-up winch 70, to apply the markings 1 10 onto the coating 20, it will be appreciated that the marker unit 65 could be provided before or in the coating unit 45 in order to provide markings 1 10 on the core 15 or under or within the coating 20.

At the end of the production process, the line 10 is spooled onto the reel 75 at the take-up winch 25. The line 10 and/or reel 75 is provided with an identifier 1 15, e.g. a tag such as a RFID tag, or other machine readable means, in order to identify the line 10 so that it can be cross referenced against the properties and parameters collected and stored by the controller 90. The coated or insulated slickline 10 is advantageously usable during well service or logging operations.

In use, the reel 75 upon which the line 10 is wound can be loaded onto a line handling system 305, as shown in Figure 3. The line handling system 305 comprises a winch 310, one or more (in this example two) line monitoring units 325, 330, one or more pulleys, sheaves, guides or other line handling components 335a, 335b and a stuffing box 340.

In use, the reel 75 is rotatable by a winch motor 315 under the control of a controller 320. In this way, the winch 310 is operable to unwind and/or wind the line 10 from/to the reel 75. In use, the line handling system 305 is placed near or adjacent to a well.

From the winch 310, the line 10 passes via the one or more pulleys, sheaves, guides or other line handling components 335a, 335b, for guiding the line 10 to the stuffing box 340. The stuffing box 340 allows the line 10 to run through it but acts to prevent fluid from the well from escaping. After passing through the stuffing box 340, the line 10 extends down into the well. One or more tools 345 can be affixed to a distal or furthest end 350 of the line 10 from the winch 310, such that operation of the winch 310 can act to retrieve and deploy the line 10 and thereby move the tool(s) 345 within the well, e.g. to retrieve, or deploy the tools 345.

Advantageously, the line monitoring units 325, 330 are arranged to determine one or more properties of the line 10 at positions between the winch 310 and the point at which it enters the well 352. The line monitoring units 325, 330 are in communication with the controller 320 (e.g. via wired or wireless communication using a communications interface 322) so that the controller 320 receives the determined properties from the line monitoring units 325, 330.

The line handling system 305 is provided with suitable means 355 (e,g, an RFID reader, or other suitable reader for machine readable indicia) for reading the identifier 1 15 on the reel 75. The identifier 1 15 can then be communicated to the controller 320. In this way, the controller 320 can identify the line 10 being used.

The controller 320 is configured to access the log or database 95 associated with the line in order to retrieve properties of the line and/or operational parameters associated with the line 10, for example, as measured during production and/or during previous operations involving the line 10. In this way, the controller 320 can, for example, identify changes in the properties and/or determine operational parameters such as a number of operations that parts or portions of the line have undergone. Using this data, the controller 320 is configured to determine or predict faults, failures or other damage to the line, as detailed below. The controller 320 is configured to operate the winch motor 315 in order to control and vary operational parameters of the line handling system 305 such as the winch motor speed, reel rotational speed or RPM, torque, line movement direction and/or number of line reversals. Advantageously, the operational parameters to which the line is subjected can be stored in the line log or database 95 and used in the determination or prediction of faults, failures or other damage to the line.

In this particular example, two line monitoring units 325, 330 are provided, namely a first line monitoring unit 325 for monitoring the line as it leaves the winch and a second line monitoring unit 330 for monitoring the line immediately before it enters the stuffing box 340. However, it will be appreciated that other arrangements, locations and/or numbers of line monitoring units 325, 330 may be provided.

The line monitoring units 325, 330 are arranged to determine the one or more properties of the line 10, which can be used in monitoring the integrity of the line, for example by detecting and measuring properties of the line indicative of defects, failures or impending failures in the coating 20, coating 20 / core 15 boundary and/or in the core 15. Defects or failures in the coating 20 could lead to wireline functional failure and/or present an operational safety hazard. Such defects and failures in the coating 20 can occur, for example, due to handling, usage, wear and tear, excess strain or stress and/or the like. For example, certain well service operations can cause a small part of the line 10 to suffer repeated cyclic bending over the sheaves, pulleys, guides or other wire handling components. This cyclic tensile loading may consequently result in these parts of the line 10 deteriorating much more rapidly than other parts of the line 10. Examples of defects or properties indicative thereof include diameter or shape (e.g. cross sectional profile) changes, irregularities or anomalies, such as necks, bulges or flats, cuts and pinholes.

In particular, as shown in Figure 4, the line monitoring units 325, 330 comprise wireline cleaners 360 such as a brush, wiper or spray, magnetic sources 365 such as a permanent ring magnet or a solenoid coil, a reader 370 for reading the markings 1 10 on or in the line 10, a rotary encoder 375 for measuring a length of line 10 that has passed through the line monitoring unit 325, 330, an ultrasound sensor

380, a laser scanner 385, a high voltage spark sensor 390, and an oiler 395. Each of the line monitoring units 325, 330 also comprise a housing 400 which encloses or contains components of the monitoring unit 325, 330 such as the magnetic sources 365, reader 370, rotary encoder 375, ultrasound sensor 380, laser scanner 385, and high voltage spark sensor 390. The provision of the housing 400 can allow the monitoring units 325, 330 to operate in hazardous areas, if required. The housing 400 can be explosion-proof or otherwise constructed so as to be suitable for use in the proximity of a wellbore.

The cleaners 360 serve to clear mud, debris or other material that may obscure or interfere with measurements of the line properties. The magnetic sources 365 are configured to magnetically energise the line, in order to activate or energise any magnetic markings 1 10 in or on the line. As such, the magnetic sources 365 are examples of activators for activating the markings 1 10 in the line.

The reader 370 is configured to read the markings 1 10 or other indicia on or in the line 10. For example, in embodiments, where the line 10 is provided with periodic markings 1 10 that indicate a position or length along the line, the reader 370 can be advantageously used to determine a position or location on the line 10 for which the determination of properties by the line monitoring units 325, 330 is being made. The rotary encoder 375 can be alternatively or additionally used for this purpose.

In this way, since positions on the line can be identified, the positions of any defects, properties or operational parameters of the line 10 or variations therein that are determined by the controller as being indicative of a potential defect or fault can be identified.

In addition, since the relative position of the components of the line handling system 305 such as the line handling components 335 (e.g. pulleys, guides and the like) and the stuffing box 340 are known, the positions or locations on the line or the length of line that has passed by the readers 370 or rotary encoders 375 can be used by the controller 320 to identify operational parameters associated with any given part or portion of the line such as a number of times that a given part or portion of the line 10 has undergone a line handling operation such as being passed over a pulley or guide, being wound on the reel 75 or passed through the stuffing box 340. Other operational parameters that can be determined using the reader 370 and/or rotary encoder 375 include a number of reversals in direction of the line.

The various sensors 380, 385, 390 are provided for measuring various properties of the line.

The ultrasound sensor 380 is operable to identify any voids in the coating 20 or areas where the coating 20 is coming free of the core 15.

The laser scanner 385, which can be of the dual axis or rotary type for example, is operable to determine the diameter (in one or more directions through a cross section of the line) and/or the cross sectional profile of the line 10.

The high voltage spark sensor 390 is operable to identify any pinholes, cuts, channels, pores or other portions where the coating has been compromised. Any properties, operational parameters, defects or other data determined by the line monitoring units 325, 330, such as position on the line 10, diameter(s), cross sectional profile, location and/or magnitude or other property of any pinholes or other defect identified, are communicated to the controller 320.

The controller 320 is operable to analyse the properties and operational parameters in order to determine and/or predict a measure of integrity and/or damage, defects or failures in the line 10. For example, the controller 320 is operable to determine if one or more of the determined properties of the line 10 (such as line diameter), or variations therein, are outwith a predetermined threshold or range. Furthermore, the controller 320 is configured to determine if number of times given parts or portions of the line have undergone an operation, such as a reversal in direction of movement of the line or being passed round a pulley or reel, exceeds a predetermined limit. The controller 320 can also be configured to determine if the line 10 has been used with a running speed, load or strain beyond a preset limit. The controller 320 is also operable to receive any direct determinations of defects by the line monitoring units 325, 330, for example, a separation of the coating 20 and core 15 as measured by the ultrasound sensor 380 or pinholes or cuts in the coating determined by the spark sensor 390, for example. In this way, the controller 320 is configured to identify or predict faults, defects or other potential failure mechanisms and/or determine the measure of line integrity. The controller 320 can then take an appropriate action, such as flagging up a warning or halting operation or adjusting an operation parameter such as line speed and so on. It will be appreciated that any necessary, thresholds, limits, ranges or tolerances can be determined by experimental data, experience, modelling, operational data or other techniques that would be apparent to a skilled person.

Although various examples of sensors and other measurement devices for determining properties and/or defects in the line are described in the example above, it will be appreciated that other sensors or measurement devices or combinations or arrangements thereof could be used. For example, a capacitance, impedance or inductance sensor could be used to determine coating thickness, such that variations in the measured capacitance, impedance or inductance or a determination if they fall outwith preset limits can be used to identify potential defects, damage or failures.

An example of a method of monitoring the line integrity using the wireline handling system 305 is now described with reference to Figure 5. In step 505, the controller 320 identifies the specific line 10 via the unique identifier 1 15 on the reel 75. The log or database 95 associated with that particular line 10 (which includes initial and/or calibration data such as properties of the line determined during production and/or properties and operational parameters of the line from previous operations) is retrieved in step 310. The controller 320 then causes the line 10 to be unspooled from (or spooled to) the reel 75 through the first line monitoring unit 325 by operating the winch motor 315 in step 515.

In the first line monitoring unit 325, the line 10 is cleaned using the cleaner

360, and magnetic markings 1 10 energised using the magnetic source 365. A unique wire production number identifier and any wireline length markings 1 10 are read using the reader 370. The production identifier and readings of the wireline length markings 1 10 are transmitted to the controller 320, whereupon they can be used to confirm the line identity and used to determine the position, parts or portions of the line for which determinations of the properties or parameters of the line are being made (step 520).

In step 525, the controller uses this position data to determine operational parameters relating to operations of the line handling system 305, such as identifying which parts or portions of the line are undergoing particular operations that might be detrimental to the line 10, such as number of times a given part or portion of the line has been passed over a pulley 335a, 335b or reel 75 or through the stuffing box 340 or has been subjected to a reversal in direction of motion. The rotary encoder 375 transmits confirmatory wireline length and running direction information to the controller 320. Examples of other operational parameters include measurements of humidity, temperature, load on the line, line or winch speed and/or direction or changes therein.

The various sensors 380, 385, 390 are used to determine properties of the line (step 530). The laser scanner 385 checks the coating integrity by determining the properties of the line (in this case diameter) in order to identify any diameter and/or shape faults. The spark sensor 390 verifies coating insulation properties and the ultrasound sensor 380 verifies coating/core voids.

Further line monitoring units 325, 330 can be connected to the winch controller. For example, the further measuring devices can be positioned on either side of pulleys 335a, 335b that route the wireline from the winch 310 to the stuffing box 340, for example. In this way, the readers 370 of the line monitoring units 325, 330 are operable to send the spacings of the wire length marks 1 10 before and after the line 1 10 travels over the pulley 335a, 335b. In this way, the controller 320 can determine if the line 10 has been stretched beyond a threshold limit or a number of times a given part or portion of the line has been stretched beyond a threshold level, which in turn can be used to determine or predict potential damage, failure or defects in the line 10. The determined properties and operational parameters for any given part or portion of the line can be analysed to determine and monitor the integrity and/or risk of failure of those parts and/or portions of the line (step 535). Any determined properties or operational parameters that fall out with pre-set limits are recorded to the memory database 95, used to flag up a warning or cause the controller 320 to halt or vary the winching operation. On completion of the wireline operation the wireline is reeled in by the winch and pulled through the monitoring units 325, 330, whereupon the wireline integrity is again monitored.

Advantageously, the database 95 associated with the particular line 10 is updated with any determined wireline properties, operational parameters, integrity and usage history. The database 95 can be further updated with winch 310 operation parameters, tool string details and/or oil well parameters (such as well geometry and/or well conditions). The expanded line integrity database 95 can be used in wireline integrity trend analysis, for example. The data analysis can predict a likelihood of line failures e.g. in a section of the coated slickline that has undergone the maximum allowed number of reversal bending cycles.

It should be understood that the embodiments described herein are merely exemplary and that various modifications may be made thereto without departing from the scope of the invention. For example, although the measuring devices 380, 385, 390 are described as having certain types of measurement apparatus, such as laser scanners, ultrasound sensors and high voltage spark sensors, it will be appreciated that other arrangements, e.g. different types and/or numbers of sensors or combinations of sensors may be used. For example, the measuring devices can be selected from laser scanners, ultrasound sensors, high voltage spark sensors, impedance sensors, capacitance sensors, mechanical sensors such as callipers, radiation sensors, UV or IR sensors, Doppler sensors, amongst others that would be apparent to one skilled in the art from the teachings of the present application.

Furthermore, the above embodiments give a number of examples of various properties and operational parameters that are indicative of the integrity and/or defects in the line, such as line diameter or cross sectional profile, stretching of the line, determinations of holes in the coating or changes in electrical resistance or capacitance of the coating, a determination of separation of the coating and core, a number of reversals or other operations of the line and so on. The above embodiments also give examples of devices that can be used to determine such properties and parameters, such as laser scanners, ultrasound scanners and spark sensors. However, it will be appreciated that other properties or operational parameters indicative of the integrity of the line or other means for determining the properties or operational parameters can be used.

Claims

A monitoring apparatus for monitoring a coated line in use, the coated line comprising a coating disposed around a core, the monitoring apparatus being configured to determine at least one property and/or operational parameter of the line and to monitor or determine an integrity of the line and/or a risk of failure of the line from the at least one property and/or operational parameter of the line.

The line monitoring system according to claim 1 , wherein at least one of the measured and/or determined properties comprises at least one property associated with the coating and/or parts or portions of the coating.

The line monitoring system according to claim 1 , wherein the coating comprises an electrically insulating and/or chemically resistant coating.

The line monitoring system according to claim 1 or claim 2, wherein the coating comprises a polymeric coating.

The line monitoring system according to any preceding claim, wherein the monitoring apparatus comprises and/or is configured to communicate with one or more measurement device for measuring and/or determining the at least one property of the line or parts or portions of the line.

The line monitoring system according to claim 5 when dependant on claim 2 or any claim dependent thereon, wherein at least one of the measurement devices comprises a coating measurement device for measuring and/or determining the at least one property associated with the coating and/or parts or portions of the coating.

The line monitoring system according to claim 2 or any claim dependant thereon, wherein the properties associated with the coating comprise one or more of:

an electrical insulation value of the coating or the parts or portions of the coating;

holes, cuts, passages and/or thin or thick sections or other changes or variations in thickness of the coating or of the parts or portions of the coating; a degree of proximity, bonding or separation between the coating or of the parts or portions of the coating and the core; and/or

a concentricity of the coating or of the parts or portions of the coating and the core.

The line monitoring system according to claim 6 or any claim dependent thereon, wherein the at least one coating measurement device comprises at least one of: an ultrasonic measurement device, an electrical resistance or impedance sensor or scanner, an inductance or capacitance sensor or scanner, a spark sensor, and/or an x-ray or other radiation sensor or scanner.

The line monitoring apparatus according to any preceding claim, wherein the line monitoring apparatus is configured to:

determine at least one position on the line, and/or at least one position of one or more parts or portions of the line, for which the at least one property and/or operational parameter has been determined; and

monitor or determine the integrity of the at least one position, part or portion of the line and/or a risk of failure of the at least one position, part or portion of the line from the at least one property and/or operational parameter associated with that position, part or portion of the line.

The line monitoring system of claim 5 or any claim dependent thereon, wherein at least one of the measurement devices comprises a dimensional scanner for determining an outer diameter or cross sectional profile of the line or part or portion of the line.

The line monitoring system of claim 5 or any claim dependent thereon, wherein the measurement device or dimensional scanner comprises a laser scanner.

The line monitoring system according to claim 5 or any claim dependent thereon, wherein at least one of the measurement devices comprises one or more of: an optical sensor or camera or video camera, a temperature sensor, a humidity sensor, a pressure sensor, and/or a strain, stress or load gauge.

The line monitoring system according to any preceding claim, wherein the core comprises a fibre composite core and at least one of the properties determined by the monitoring system comprises a property of the fibre composite core.

The line monitoring system according to any preceding claim, wherein the parameter of the line comprises one or more of: a number of line operations that the line or part or portion of the line has undergone, a number of reversals in direction of motion of the line, a number or magnitude of stretches of the line, a tensile load, stress or strain, a temperature and/or a pressure on the line or the parts or portions of the line.

The line monitoring system according to any preceding claim, wherein the line monitoring system comprises or is configured to access and/or update a database for storing the properties or parameters of the line or parts or portions of the line.

The line monitoring system according to any preceding claim, wherein the line monitoring system is configured to determine if one or more of the properties or parameters, or a variation therein, is above or below a threshold or outwith a range.

The line monitoring system according to any preceding claim, wherein the line comprises a plurality of markers indicative or length or position on the line, the line monitoring system comprises or is configured to access a detector for detecting the markers, and the line monitoring system is configured to determine the length or position on the line and/or stretching of the line by detecting the markers using the detector.

The line monitoring system according to any preceding claim, wherein the line handling system comprises an id reader, for reading an id of the line and recording the determined properties and/or parameters and/or location or position in a database associated with the identified line.

A line handling system for moving deploying or retrieving tools or other payload using a line, the line handling system comprising one or more line monitoring systems according to any of claims 1 to 18 for monitoring or determining an integrity of the line and/or a risk of failure of the line.

A method for monitoring a line in use, wherein the method comprises determining at least one property and/or operational parameter of the line and monitoring or determining an integrity of the line and/or a risk of failure of the line from the at least one property and/or operational parameter of the line.

The method of claim 20, wherein the method comprises using the line monitoring system according to any of claims 1 to 18 to determine the at least one property and/or operational parameter of the line and/or monitor or determine an integrity of the line and/or a risk of failure of the line.

A controller for controlling the monitoring system of any of claims 1 to 18 and/or the line handling system of claim 19, the controller comprising at least one or more of: one or more processors, one or more memories or data stores for storing the database of the properties or parameters of the line or parts or portions of the line, and/or a communications interface.

A computer program product configured to implement the monitoring apparatus of any of claims 1 to 18, the line handling system of claim 19, the method of any of claims 20 or 21 , or the controller of claim 22.

A carrier medium comprising or loaded with the computer program product of claim 23.

A processing apparatus comprising or loaded with the computer program product of claim 23.

A monitoring apparatus substantially as described and/or shown herein. A line handling apparatus substantially as described and/or shown herein.

28. A production apparatus substantially as described and/or shown herein.