WO2019165562A1 - Capteur de détection de fuite d'hydrocarbures pour oléoducs et gazoducs - Google Patents

Capteur de détection de fuite d'hydrocarbures pour oléoducs et gazoducs Download PDF

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Publication number
WO2019165562A1
WO2019165562A1 PCT/CA2019/050253 CA2019050253W WO2019165562A1 WO 2019165562 A1 WO2019165562 A1 WO 2019165562A1 CA 2019050253 W CA2019050253 W CA 2019050253W WO 2019165562 A1 WO2019165562 A1 WO 2019165562A1
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Prior art keywords
refractive index
cladding
grating
core
hydrocarbon
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PCT/CA2019/050253
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English (en)
Inventor
Dilip Tailor
Ronald J. Dunn
Mark Phillip Brandon
Dennis Wong
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Shawcor Ltd.
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Publication of WO2019165562A1 publication Critical patent/WO2019165562A1/fr

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    • G—PHYSICS
    • G01—MEASURING; TESTING
    • G01M—TESTING STATIC OR DYNAMIC BALANCE OF MACHINES OR STRUCTURES; TESTING OF STRUCTURES OR APPARATUS, NOT OTHERWISE PROVIDED FOR
    • G01M3/00—Investigating fluid-tightness of structures
    • G01M3/02—Investigating fluid-tightness of structures by using fluid or vacuum
    • G01M3/04—Investigating fluid-tightness of structures by using fluid or vacuum by detecting the presence of fluid at the leakage point
    • G01M3/042—Investigating fluid-tightness of structures by using fluid or vacuum by detecting the presence of fluid at the leakage point by using materials which expand, contract, disintegrate, or decompose in contact with a fluid
    • G01M3/045—Investigating fluid-tightness of structures by using fluid or vacuum by detecting the presence of fluid at the leakage point by using materials which expand, contract, disintegrate, or decompose in contact with a fluid with electrical detection means
    • G01M3/047—Investigating fluid-tightness of structures by using fluid or vacuum by detecting the presence of fluid at the leakage point by using materials which expand, contract, disintegrate, or decompose in contact with a fluid with electrical detection means with photo-electrical detection means, e.g. using optical fibres
    • F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
    • F17—STORING OR DISTRIBUTING GASES OR LIQUIDS
    • F17D—PIPE-LINE SYSTEMS; PIPE-LINES
    • F17D5/00—Protection or supervision of installations
    • F17D5/02—Preventing, monitoring, or locating loss
    • F17D5/06—Preventing, monitoring, or locating loss using electric or acoustic means

Definitions

  • Hydrocarbon pipeline leaks are of increasing concern.
  • hydrocarbon pipeline is typically made of steel with anti-corrosion coatings, external factors such as impact, coatings damage, water ingress, etc. and (internally) the corrosive and volatile nature of the hydrocarbon being
  • the optical fibre cable 200 comprises an inner core 22, typically made of pure glass (silica), surrounded by a cladding 24.
  • Cladding 24 is typically a glass layer having a lower refractive index than core 22, to maintain guidance of light within the core 22, meaning that the transmitted light is reflected back in the core 22 at the core/cladding
  • the cladding 24 effectively "reflects” stray light back into the core 22, ensuring the transmission of light through the core 22 with minimal loss. This is essentially achieved with a higher refractive index in the core 22 relative to the
  • the cladding 24 is typically further encapsulated by a single or multiple layers of primary polymer coatings, such as acrylates and polyimides, also known as buffer coating 26, for
  • the buffer coating 26 serves to protect the fiber from external conditions and physical damage. It can incorporate many layers depending on the amount of ruggedness and protection required.
  • an outer protective sheath 27 may also be present, which can be made from a wide variety of materials, the purpose of which is further protection and ease of handling.
  • core 22 can be of about 8 microns in diameter, with cladding 24 of a diameter of about 125 microns, buffer coating 26 of about 250 microns in diameter, and an outer sheath 27 or jacket of about 400-600 microns in diameter.
  • Multimode fibers have a larger core 22, typically about 62.5 microns, while the single modes have cores 22 of about 8 microns .
  • Multimode fibers are sometimes used for temperature sensing, whilst single mode fibers are mostly used for distributed acoustic sensing or strain sensing as well as for temperature.
  • a fiber-optic sensor works by modulating one or more properties of a propagating light wave, including intensity, phase, polarization, and frequency, in response to the environmental parameter being measured.
  • an optical fiber sensor is composed of a light source, optical fiber, sensing element, and detector.
  • FBG fiber Bragg gratings
  • uniform FBGs including uniform FBGs, tilted FBGs, chirped FBGs, and superstructure FBGs
  • Sensing technologies have also been developed utilizing tapered fiber optics.
  • Truly distributed fiber-optic sensing systems used the entire fiber length to sense one or more external parameters which can be on the order of several tens of kilometers. This is a capability unique to fiber-optic sensors and one that cannot be easily achieved using conventional electrical sensing techniques .
  • the concept of "distributed sensors” measures the scattered light at every location along the fiber. Different types of scattering exist, including Rayleigh, Brillouin, and Raman scattering .
  • Rayleigh the most dominant type of scattering, is caused by density and composition fluctuations created in the material during the manufacturing process. Rayleigh scattering occurs due to random microscopic variations in the index of refraction of the fiber core. When a narrow pulse of light is launched into a fiber, the variation in Rayleigh backscatter can help determine the approximate spatial location of these variations. Although Rayleigh scattering is relatively
  • Raman scattering is caused by the molecular vibrations of glass fiber stimulated by incident light.
  • the resulting scatter has two wavelength components, one on either side of the main exciting light pulse wavelength, called Stokes and anti-Stokes.
  • the ratio between Stokes and anti-Stokes is used for temperature sensing, and is immune to strain. This technology is popular in downhole oil and gas applications for profiling temperature variations in oil wells.
  • a third type of scattering is Brillouin, which stems from acoustic vibrations stimulated by incident light. To satisfy the requirement of energy conservation, there is a frequency shift between the original light pulse frequency and the
  • Gratings introduced within the fiber optic cable. This permits the measure of changes in temperature or strain on the fiber optic cable by measuring a change in the wavelength of light reflected back to the light source.
  • Fiber Bragg Gratings are made by laterally exposing the core of a single-mode fiber to a periodic pattern of intense ultraviolet light or other methods. The exposure produces a permanent increase in the refractive index of the fiber' s core, creating a fixed index modulation according to the exposure pattern; this fixed index modulation is referred to as a grating.
  • the wavelength at which this reflection occurs is called the Bragg wavelength.
  • Light signals at wavelengths other than the Bragg wavelength, which are not phase matched, are essentially transparent. This results in a peak
  • n the index of refraction
  • A the period of the index of refraction variation of the fiber Bragg grating. Due to the temperature and strain dependence of the parameters n and A, the wavelength of the reflected component will change as a function of strain (typically caused by temperature, pressure, vibration, or bending) "shifting" the peak
  • the reflection wavelength based on strain at the location of the grating This is illustrated in Figure 2.
  • the wavelength of the peak reflection changes every time there is a temperature or strain delta, including but not limited to temperature/strain changes.
  • a non-strained temperature compensating FBG sensor can be used when measuring strains in a non-isothermal application. Separating these effects is often a challenge in practice, and may result in false readings.
  • FBG uniform Fiber Bragg
  • Gratings wherein the gratings are perpendicular to the length of the fiber optic cable (and therefore to the light path) , and where the grating has a uniform period/grating length.
  • Other forms of FBGs are also known.
  • a Chirped FBG is an FBG having a linear variation in the grating period.
  • a chirped FBG adds dispersion - i.e.
  • a tilted FBG also called a slantedFBG, or a blazed FBG, provides a grating that is not perpendicular to the length of the fiber optic cable.
  • tilted FBGs have periodical index variation in axial direction. However, the boundary surface of the varied index is not vertical with respect to the fiber axis, instead, having a defined angle.
  • tilted FBGs can couple guided- modes with copropagating modes, or counterpropagating modes, in specific wavelengths. Because of these characteristics, they can be used as gain flattened erbium fiber amplifiers, optical spectrum analyzers, etc. Tilted FBGs are particularly sensitive to the surrounding refractive index outside the gratings. Modes are coupled between the forward propagating core mode to backward propagating core mode (Bragg) , and forward propagating core mode to backward propagating cladding modes. Therefore both a core mode resonance and numbers of cladding mode resonances appear simultaneously. Using the core mode back reflection as a reference wavelength in the single mode fiber, it is possible to measure the perturbations such as surrounding refractive index using the cladding mode resonance shift. The sensitivity of TFBG to the surrounding media can be extended to a next level of sensitivity.
  • each grating plane of the FBG When the light from the core mode hits each grating plane of the FBG at right angle, it is reflected backwards; however with the tilted FBG where the grating planes are tilted, light is reflected off axis and each grating plane reflects a small portion of light towards the cladding. This increases the growth of the backward propagating cladding mode at phase- matched wavelengths. The cladding modes that will have the strongest coupling are then determined by the tilt angle.
  • tilted fiber Bragg gratings are sensitive to the surrounding refractive index outside the gratings, due to which they can function as
  • Fiber optic sensing systems utilizing tapered fiber have been described. Tapering of the fiber can provide a "FBG" - like effect, where the refractive index of the cladding, and changes therein, can influence the transmission
  • US patent 4,386,269 (incorporated herein by reference), to Avon Rubber Company Limited, describes a pipeline leak detection system utilizing fiber optic lines. This system is distinguished from the currently commercially available fiber optic systems described above, in that it is designed to measure oil leaks directly, rather than through indirect proxies such as changes in temperature or pressure on the fiber optic cable.
  • the patent describes a fiber optic cable comprising a fiber optic surrounded by a medium of which the refractive index is altered by the influence of a leaked hydrocarbon, for example, a silicone rubber of which the refractive index is normally lower than that of a quartz fiber optic, but of which the index increases to that of the quartz or above when oil soaks into it through a permeable cladding and elastomeric protective layer.
  • the detection system utilizes a light emitter at one end of the fiber optic cable, and a light receiver at the other end, which measures the light received.
  • a difference in refractive index will cause the light to be absorbed at the wall of the fiber optic cable, rather than reflected to the light receiver; such difference in light received is indicative of such change in refractive index of the cable, suggesting a leak. While the concept of using the change in the refractive index as one of the
  • the fiber optic cable is still exposed to the normal triggers like the temperature, strain and vibration. It is essentially a distributed fiber optics system as described above with all its shortcomings explained above. Therefore, the signal analyzer would receive signals indicating some disturbance in the fiber, but would not be able accurately delineate the cause of the disturbance. Therefore the invention is not well able to achieve the objective that it set out to teach in the patent.
  • LFGs Long-period fiber gratings
  • the grating period is within the range of 100 ⁇ 1000 pm which is much larger than the wavelength of the light propagating in the fiber. Therefore, the gratings enable coupling of light from the propagating core mode to the co-propagating cladding modes at discrete wavelengths, producing a series of at tenuation bands in the transmission spectrum.
  • the resonant wavelength at each attenuation peak can be calculated by the phase matching condition
  • Ares is the resonant wavelength
  • A is the grating period
  • the term is a function of refractive indices of the core (nl) and cladding (n2) of the fiber as well as its surrounding medium. Therefore, the resonant wavelength changes with the refractive index of the
  • LPGs couple light from a guided mode in the core into forward propagating cladding modes where it is lost due to absorption and scattering.
  • the coupling from the guided mode to cladding modes is wavelength dependent so a spectrally selective loss can be obtained.
  • a fiber optic cable can be manufactured with the LPG properties periodically varying along the fiber, so that the conditions for the interaction of several co
  • LPGs couple co-propagating modes with close propagation constants; therefore the period of such a grating typically considerably exceeds the wavelength of radiation propagating in the fiber.
  • LPGs couple co-propagating modes, and accordingly, their resonances can only be observed in transmission spectra, rather than at a single peak wavelength like FBGs .
  • the transmission spectrum has dips at the wavelengths corresponding to resonances with various cladding modes.
  • LPGs provide different light transmission spectrum based on both refractive index of the fiber optic cable, and the distance between gratings.
  • LPG refractive index
  • the position and strength of attenuation band depends on effective refractive index of the cladding modes, which in turn depends on the refractive index of the
  • LPG's as index sensors based on the change in wavelength and/or attenuation of the LPG bands.
  • LPG is very useful as a sensor when the refractive index of the external medium changes.
  • the change in ambient index changes the effective index of the cladding mode and will lead to wavelength shifts of the resonance dips in the LPG
  • the effective indices of the cladding modes are dependent upon the difference between the refractive index of the cladding and that of the medium surrounding the cladding.
  • the central wavelengths of the attenuation bands thus show a dependence upon the refractive index of the medium surrounding the cladding, with the highest sensitivity being shown for surrounding refractive indices close to that of the cladding of the optical fibre, provided that the cladding has the higher refractive index.
  • the centre wavelengths of the resonance bands show a considerably reduced sensitivity.
  • An LPG grating has been used in a chemical sensor to determine the concentration of manganese in water at ppm level (Akki et al, IOSR Journal of Applied Physics 2278-4861, Volume 4, Issue 3 (Jul-Aug 13), pp 41-46, incorporated herein by reference) .
  • the sensor utilizes core-cladding mode resonances utilizing a fiber optic core surrounded by cladding that has been stripped of all further buffer or outer coating. Such "naked" cladding was placed in solutions containing varying levels of manganese and the effects on the LPG spectral behavior was measured.
  • Transmission spectrum of LPFG as chemical sensor can be explained in terms of surrounding refractive index (SRI) of medium.
  • the SRI is lower than the refractive index of the cladding (nsur ⁇ ncl)
  • mode guidance can be explained using total internal reflection.
  • typically strong resonance peaks are observed and the attenuation dips shift towards shorter wavelengths when the external medium refractive index increases up to that of the fiber cladding.
  • sensitivity increases, which leads to larger wavelength shift of resonance wavelength.
  • the cladding layer acts as an infinitely extended medium and thus supports no discrete cladding modes. In this case, a broadband radiation mode coupling occurs with no distinct attenuation bands.
  • Temperature insensitive strain sensors using LPG fibers are generally known, see for example Madhavan and Chattopadhyay, International Journal on Recent Innovation Trends in Computing and Communication, Vol . 3, Issue 5, pp . 2986-2990, incorporated herein by reference) . By selecting a proper LPG period and mode, a temperature insensitive strain sensor can be designed.
  • LPG gratings in general, and their fabrication techniques are generally taught in Libish, T.M., "Design and Development of Fiber Grating Based Chemical and Bio-sensors", PhD thesis at International School of Photonics, Cochin University of Science and Technology, Huawei, India, and in Vasiliev & Medvedkov, "Long-period refractive index fiber gratings: properties, applications and fabrication techniques”.
  • Figure 1 is a schematic of a prior art fiber optic cable.
  • Figure 2 is an illustration of the wavelength shift through a strained vs. unstrained Fiber Bragg grating.
  • Figure 3 is a schematic cross-section of a prior art fiber optic cable.
  • Figure 4 is a schematic cross-section of a fiber optic cable according to certain embodiments of the present invention.
  • Figure 5 is a schematic cross-section of a fiber optic cable according to certain embodiments of the present invention.
  • Figure 6 is a schematic cross-section of a fiber optic cable according to certain embodiments of the present invention.
  • Figure 7 is a schematic cross-section of a pair of fiber optic cables, including a control cable.
  • Figure 8 is a schematic cross-section of a fiber optic cable according to certain embodiments of the present invention.
  • Figure 8A-C are schematic cross-sections of a fiber optic cable according to certain embodiments of the present
  • Figure 9 is a schematic cross-section of a fiber optic cable according to certain embodiments of the present invention.
  • Figure 10 is a schematic cross-section of a pair of fiber optic cables according to certain embodiments of the present invention .
  • Figure 11 is a schematic representation of a fiber optic cable according to certain embodiments of the present invention, including a plurality of sensor regions.
  • Figure 12 is a schematic representation of a fiber optic cable according to certain embodiments of the present invention, including a plurality of sensor regions, placed alongside a pipeline .
  • Figure 13 is a schematic cross-section of a fiber optic cable according to certain embodiments of the present invention.
  • Figure 14 is a schematic cross-section of a fiber optic cable according to certain embodiments of the present invention.
  • Figure 15 is a schematic cross-section of a fiber optic cable according to certain embodiments of the present invention.
  • Figure 16 is a schematic cross-section of a fiber optic cable according to certain embodiments of the present invention.
  • Figure 17 is a schematic cross-section of a fiber optic cable according to certain embodiments of the present invention.
  • Figure 18 is a schematic cross-section of a pair of fiber optic cables according to certain embodiments of the present invention, including a control cable, within conduit .
  • Figure 19 is a schematic cross-section of a fiber optic cable according to certain embodiments of the present invention, including a control cable, and several staggered sensor cables, within a single protective sheath.
  • Figure 20 is a schematic representation of a fiber optic cable according to certain embodiments of the present invention, including a plurality of sensor regions, placed alongside a pipeline .
  • a device for use in combination with a light emitter and a light receiver in detecting a hydrocarbon leak from a contained volume adjacent to said device, and along which said device extends said device comprising: a fiber optic core having a first refractive index; a cladding around said core, said cladding having a second refractive index that is higher than the first refractive index; a buffer coating around said cladding, at least one portion of said buffer coating having a third refractive index, a remainder of said cladding having either said third refractive index or a fourth refractive index; there being a difference between said second and third refractive indicies, said portion of said buffer coating being of a nature that said third refractive index is altered by contact with hydrocarbon in a manner that alters the internal reflection characteristics of said core.
  • the device further comprises a grating in said core, configured such that said grating is coated with the portion of the buffer coating having the third refractive index.
  • a device for use in combination with a light emitter and a light receiver in detecting a hydrocarbon leak from a contained volume adjacent to said device, and along which said device extends said device comprising: a fiber optic core having a first refractive index; a cladding around said core, at least one portion of said cladding having a third
  • said core comprising a grating, configured such that said grating is coated with the portion of the cladding having the third refractive index.
  • the device further comprises an outer sheath, said outer sheath providing protective means for said cladding and/or buffer coating and being at least semi-permeable to said fluid.
  • the remainder of said buffer coating has the fourth refractive index, said fourth
  • refractive index being unaffected by contact with leaked hydrocarbon from the contained volume.
  • the remainder of said cladding has the second refractive index, said second
  • the grating is a Fiber Bragg Grating .
  • the grating is a Long Period Fiber Grating.
  • the device has a plurality of said portion of said buffer coating having said third refractive index, interspersed along said device and separated by buffer coating having said fourth refractive index.
  • each of said plurality of said portion of said buffer coating having said third refractive index surrounds a grating in said core, wherein the buffer coating having said fourth refractive index surrounds core lacking grating .
  • the device has a plurality of said portion of said cladding having said third refractive index, interspersed along said device and separated by
  • each of said grating has a different and unique period.
  • the third refractive index is normally lower than the second refractive index but increased at least to the value of the second refractive index by the presence of leaked hydrocarbon.
  • contact with hydrocarbon alters a reflection pattern formed from the grating.
  • contact with hydrocarbon renders the core non-internally-reflective .
  • the portion of cladding having the third refractive index is of silicone rubber.
  • the portion of cladding having the third refractive index is of EVA or a styrene butadiene rubber.
  • the third refractive index is normally lower than the second refractive index but increased at least to the value of the second refractive index by the presence of leaked hydrocarbon, whereby contact with said hydrocarbon alters a reflection pattern formed from the grating . According to certain embodiments, contact with said hydrocarbon renders the core non-internally-reflective .
  • a pipeline carrying a fluid in combination, a pipeline carrying a fluid, and extending along the pipeline in a position so as to be
  • a pipeline carrying a fluid comprising a steel pipe with an external polyolefin coating, further comprising a device as hereinbefore described at least
  • refractive index is altered by contact with the leaked fluid which is permitted to seep into said material to alter a predetermined relationship between the refractive indexes of the core and of said surrounding material so as to alter the internal reflection characteristics of the core, and detecting alteration of said characteristics, wherein said core
  • the grating is a Fiber Bragg grating.
  • the grating is a Long Period Fiber Grating.
  • the outer sheath is perforated.
  • the outer sheath is hydrocarbon permeable .
  • the outer sheath is a hydrocarbon - permeable mesh or braid.
  • the outer sheath is a plastic.
  • the device is encased in a conduit.
  • the conduit comprises a plurality of perforations or openings to allow the ingress of hydrocarbon.
  • the conduit is rigid plastic.
  • the conduit is metal
  • the conduit is packed with a
  • the hydrocarbon-permeable filler has temperature insulative properties.
  • a cable having a plurality of the devices as
  • the invention relates to a novel fiber optic sensor and system for the detection of hydrocarbon leaks.
  • the sensor can be run generally parallel with and proximal to a pipeline for
  • the fiber optic sensor and system has one or more of the following improvements over the presently known systems.
  • FIG 1 shows, in schematic form and not to scale, a known fiber optic cable 200.
  • the fiber optic cable comprises a glass fiber core 22, typically made of a single mode or multi mode quartz fiber.
  • the fiber optic cable is surrounded by a conventional cladding 24, usually a glass, with a refractive index greater than that of the core 22.
  • the core/cladding interface 23 between the core 22 and the cladding 24.
  • the cladding 24 is surrounded by a protective buffer or coating 26, typically acrylates or polyimide.
  • the cladding/buffer interface 25 is also shown.
  • the buffer coating 26 is surrounded by outer sheath 27, which provides further protection.
  • Figure 3 shows this same cable, without outer sheath 27, and in cross-sectional view .
  • Example A Distributed Hydrocarbon Sensor with sensor cladding
  • One aspect of the present invention is based on the fiber optic cable of Figure 1, but provides a distributed
  • Cable 20 is shown in schematic cross-section in figure
  • Cable 20 contains core 22, which is surrounded by cladding.
  • a sensor cladding 36 is used instead of the prior art conventional cladding as previously described.
  • Sensor cladding 36 is characterized by having properties that are modified by contact with a hydrocarbon source such as oil
  • sensor cladding 36 is made of a material with a lower refractive index than that of the glass fiber core 22, but which increases in refractive index, to a refractive index equal to or greater than that of the glass fiber core 22 on contact with oil.
  • sensor cladding 36 is made of a material having a lower refractive index than the glass fiber core 22, but which dissolves or dissipates when put in contact with a hydrocarbon source .
  • the sensor cladding 36 is a silicone rubber, preferably a silicone rubber having a refractive index between 1.40 and 1.45. which, when put in contact with a hydrocarbon source such as oil, increases in refractive index to a refractive index greater than that of the glass fiber core 22, for example, greater than 1.46.
  • the sensor cladding 36 is made from a hydrocarbon swellable or hydrocarbon dissolvable material, such as ethylene vinyl acetate (EVA) or styrene butadiene rubbers, such as KratonTM rubbers (Kraton Polymers, USA) .
  • EVA ethylene vinyl acetate
  • KratonTM rubbers Kraton Polymers, USA
  • the silicone, EVA polymer, or Kraton rubber can be made swellable by crosslinking it.
  • Sensor cladding 36 can be made from a number of other compounds.
  • sensor cladding 36 can be made from polymers that are sensitive to oil, have optical clarity, and an appropriate refractive index. These include polymers such as silicones, acrylates, ethylene vinyl acetates, calixarene and styrenes.
  • the sensor cladding 36 is made from polydimethylsiloxane .
  • coating compositions include styrene butadiene rubbers, syndiotactic polystyrene and atactic polystyrene and polystyrene.
  • styrene butadiene rubbers syndiotactic polystyrene and atactic polystyrene and polystyrene.
  • atactic polystyrene due to the affinity between its olefin chains and hydrocarbon molecules. The selection is optimized based on the desired refractive index, the type of hydrocarbon that is being detected, and the service conditions.
  • the thickness of the sensor cladding 36 can be important, both in its refractive index effect and its strain effect, with a thicker sensor cladding 36 inducing larger strain effect onto the glass fiber core 22, especially when bound thereto. It has been found that the strain-inducing behavior of an oil swellable sensor cladding 36 can act as a secondary signal of the hydrocarbon presence, in addition to the primary signal resulting from the change in refractive index described earlier.
  • buffer coating 26 is either not present, or, as shown, is made from a
  • buffer coating 26 may also be perforated, braided, or a mesh.
  • Outer sheath (not shown, but previously described as outer sheath 27), where used, would also be made in a manner that would allow ingress of hydrocarbon.
  • the change in refractive index of sensor cladding 36 creates changes in the properties of the light being sent through core 22, which can be measured.
  • Example B Distributed Hydrocarbon Sensor with Sensor Buffer Layer
  • FIG. 5 A different embodiment of the invention is found in Figure 5.
  • core 22 is surrounded by a conventional cladding 24.
  • the conventional buffer coating previously described is replaced by a sensor coating 37.
  • Sensor buffer coating 37 is, like the sensor cladding of
  • Example A characterized by having properties that are
  • sensor coating 37 is made of a material with a lower refractive index than that of the cladding 24, but which increases in refractive index, to a refractive index equal to or greater than that of the cladding 24 on contact with oil. In other embodiments, sensor coating 37 is made of a material having a lower refractive index than the cladding 24, but which dissolves or dissipates when put in contact with a hydrocarbon source.
  • the sensor coating 37 is a silicone rubber, preferably a silicone rubber having a refractive index between 1.40 and 1.45. which, when put in contact with a hydrocarbon source such as oil, increases in refractive index to a refractive index equal to or greater than that of the cladding 37, for example, greater than 1.46.
  • the sensor coating 37 is made from a hydrocarbon swellable or hydrocarbon dissolvable material, such as ethylene vinyl acetate (EVA) or styrene butadiene rubber such as a Kraton rubber.
  • a hydrocarbon swellable or hydrocarbon dissolvable material such as ethylene vinyl acetate (EVA) or styrene butadiene rubber such as a Kraton rubber.
  • Sensor coating 37 can be made from a number of other materials
  • sensor coating 37 can be made from polymers that are sensitive to oil, have optical clarity, and an appropriate refractive index. These include polymers such as silicones, acrylates, ethylene vinyl acetates, calixarene and styrenes. In certain embodiments, the sensor coating 37 is made from polydimethylsiloxane . Other possible coating compositions include styrene butadiene rubbers and
  • polystyrene syndiotactic polystyrene and atactic polystyrene and polystyrene.
  • atactic polystyrene due to the affinity between its olefin chains and hydrocarbon molecules. The selection is optimized based on the desired refractive index, the type of hydrocarbon that is being detected, and the service conditions.
  • the thickness of the sensor cladding 36 can be important, both in its refractive index effect and its strain effect, with a thicker sensor cladding 36 inducing larger strain effect onto the glass fiber core 22, especially when bound thereto. It has been found that the strain-inducing behavior of an oil swellable sensor cladding 36 can act as a secondary signal of the hydrocarbon presence, in addition to the primary signal resulting from the change in refractive index described earlier.
  • composition of the polymer compound may be adjusted to tailor the response of the coating to different hydrocarbons. For example, it was found that the with a given degree of
  • the light oils such as jet fuel gave a fast response time versus medium oil such as Brent crude oil, which took much longer to respond.
  • the response is in terms of the absorption of the fluid by the coating and resulting in a corresponding swelling and change in the refractive index.
  • a heavy crude oil was used, the standard silicone responded very slowly, and was less than optimum.
  • a lower molecular weight silicone and a lower crosslink level can be utilized to make it more susceptible to a "chemical attack" by the oil.
  • EVA ethylene vinyl acetate
  • the chemical structure can be tailored to impart a desired response.
  • the response is by of initial swelling and subsequent dissolution of the EVA in presence of the hydrocarbon. It was found that the response can be adjusted by the changing the vinyl acetate (VA) content and the molecular weight (MW) of the polymer. The MW is measured by the Melt Flow Index (MFI) . It was found that a typical extrusion grade EVA with a MFI of 1.0 g/10 minutes and a VA content of 10-16% gave as reasonably fast response to the light oil, but the change was not optimum for medium oil type. In contrast, EVA with a VA content of 18-24% gave a good response to the medium oil.
  • MFI Melt Flow Index
  • the VA content should be greater that 27% and even as high as 40% or greater, to obtain good response. It was found that by using lower MW resins, meaning a higher MFI, the response to the heavier oils could be improved.
  • a balance of the VA content and MW was found to be important, depending on the hydrocarbon being targeted and the required physical properties of the polymer for the given service conditions, keeping in mind the processing used for coating the fiber, such as extrusion, solvated resin coating etc.
  • any outer sheath (not shown) is either not present, or is made from a material which is permeable or semi-permeable to hydrocarbon.
  • outer sheath may also be perforated, braided, or a mesh.
  • the change in refractive index of sensor coating 36 creates changes in the properties of the light being sent through core 22, due to the change in cladding mode; such changes in the properties of the light can be measured.
  • Example A and B can be combined, for a cable as depicted in Figure 6, having both sensor cladding 36 and sensor coating 37.
  • the fiber optic cable 20 of Examples A and B are sensitive to the presence of hydrocarbon leaks, they are also sensitive to stress, for example, temperature changes and physical strain on the fiber optic cable, which may be caused through impact or change in pressure or other external factors. Accordingly, while the cable of Examples A and B is useful in detecting hydrocarbon leaks, the signal change resulting from such a leak is not easily discernible from such strain.
  • Figure 7 shows one way in which to decrease false positive signals and a useful way to increase the signal to noise ratio.
  • Sensor fiber optic cable 20, which is able to sense hydrocarbon, as herebefore or hereinafter described, is run alongside and generally in parallel to a cable 200 which does not have any hydrocarbon - sensing properties.
  • Figure 7 shows cable from Example A, but the same concept would apply to Example B, with a buffer coating acting a sensor coating with corresponding control cable. Accordingly, when utilized, the differences in signal change between cable 20 and cable 200 will be primarily due to the sensing of hydrocarbon by cable 20.
  • Figure 8 shows a further embodiment of the invention.
  • a grating 40 is added to the cable 20 as otherwise described in Examples A and B, above.
  • the region of the cable 20 having a grating 40 is defined as a sensor region 28.
  • Grating 40 may be a FBG grating, or, in some, more preferable embodiments, a Long Period Fiber Grating (LFG) .
  • LFG Long Period Fiber Grating
  • tapers 41 in the optical fiber can be used instead of or in addition to gratings, to similar effect .
  • a chirped FBG Figure 8B
  • a tilted FBG Figure 8C
  • a tilted FBG provides greater sensitivity to the sensor.
  • a grating 40 can be a FBG, a LFG, a chirped FBG, a tilted FBG, or a taper as depicted in any of figures 8, 8A-8C.
  • a tilted FBG In the case of a tilted FBG, it can be designed to provide a similar coupling from the core mode to the cladding mode.
  • Tilted FBGs are sensitive to the external refractive index. Hence, a tilted FBG can create an accurate refractometers and they can advantageously be used in the present hydrocarbon sensing applications.
  • the cladding modes are guided by the cladding boundary, and their effective index depends on the refractive index of the outer medium. By monitoring the changes of the cladding modes, an accurate measure of the external refractive index can be obtained.
  • tilted FBGs are more compact and less sensitive to bending. With proper interrogation method, tilted TFBGs can measure both the surrounding refractive index quite accurately and provide the hydrocarbon sensing and detection.
  • the refractive index can also be achieved using the tapered fiber design.
  • the tapered sensor is based on the spectroscopy of mode coupling based on core modes-to-fiber cladding modes excited by the fundamental core mode of an optical fiber when it transitions into tapered regions from untapered regions. The changes are determined from the wavelength shift of the transmission spectrum. The shift in the transmission spectrum depends on the surrounding medium in the waist length region. Thus, the transmission of the SMTF (single mode taper fiber) is quite sensitive to the refractive index of the external medium, which makes it possible to be deployed as an RI sensor .
  • Fiber tapering refers to the process of pulling a fiber while heating, such that the overall diameter of the fiber at the tapered region is less than the original core diameter.
  • a tapered tip fiber consists of an optical fiber which gradually decreases in diameter until it becomes a tiny tip that later becomes the sensing element.
  • a continuous tapered fiber is an optical fiber that is
  • a single cable 20 may have a plurality of gratings 40 (40 and 40' as shown, but a greater number of gratings 40 may be used) .
  • Grating 40 may have different properties at different sensor regions 28.
  • the gratings 40, 40' in each sensor region 28, 28' may have a unique grating period.
  • each sensor region 28, 28' has a
  • each sensor region creates a unique wavelength shift when it is contacted by a hydrocarbon. Accordingly, this enables the localization of the pipe leak to a defined region along the fiber optic cable 20.
  • a similar advantage can be obtained by using LPG gratings with different periods - in which case the spectrum changes are measured.
  • the use of gratings turn the sensors of Examples A and B into point sensors, at sensor regions 28, since the signal change resulting from the change in refractive index at grating 40 or between grating 40 and grating 40' are significantly greater than those otherwise along the cable 20.
  • gratings 40 there is a limit to the number of gratings 40 that can be effectively utilized on one length of core fiber. Accordingly, as shown in Figure 10, a plurality of cables (as shown 20, 20' , but a larger number of cables can be used) can be run, generally in parallel, with staggered sensor regions 28, to provide a plurality of sensor regions 28 along a greater overall length.
  • FBG and LFG gratings can be incorporated into core 22 using a variety of known methods, certain of which, for example, etching using C02 lasers, can be utilized after the coating of the core 22 with cladding and/or coatings, facilitating production .
  • FBG and LPG gratings are sensitive to changes in temperature, strain and refractive index. With FBG sensors, it can be difficult to distinguish which factor is the cause of the disturbance since they all have largely similar
  • the strain imposed on the FBG results in a proportional shift of the Bragg wavelength of the FBG sensor, which can be measured and utilized as a secondary signal of hydrocarbon presence (in addition to the primary signal, due to the change in the refractive index) .
  • This secondary signal is dramatically amplified in a tilted BFG, because the compressive forces and/or stretching of the fibre optic cable is imparted to the grating at an angle to the grating, creating an enhanced effect on the shifting of the reflected wavelength.
  • the primary and secondary signals can be used complimentarily to reduce false positives.
  • a control cable as described in Example C, and/or a second control cable having no gratings can also be
  • sensor regions 28 are at approximately equal intervals on the fiber optic cable 20, for example, at lm intervals if it is desired to have a lm sensing resolution on the cable, or at 10m intervals if a 10m sensing resolution is desired.
  • sensor regions 28 can be concentrated at certain locations, for example, equating to locations of known pipeline weakness such as the field joints of a pipeline, or high risk area of the pipeline route.
  • Figure 12 shows such a configuration, with the fiber optic cable 20 shown (again, in schematic, non-scale form) laid adjacent to an oil pipeline 30 having girth welds 32 and field joint regions 34. As can be appreciated, this leads to greater resolution sensing at the field joint regions, and lower resolution sensing at areas of the pipe between field joints.
  • Example E Dedicated Point Sensor
  • cable 20 as described in Example C provides the sensitivity of a point sensor at gratings 40, but still has noise present due to the distributed sensor found throughout the cable.
  • a further improvement is to limit the sensor cladding and/or sensor coating regions to the regions
  • the cable 20 of Figure 13 comprises glass fiber core 22 surrounded by a conventional cladding 24, which is shown surrounded by a conventional buffer coating 26.
  • Cable 20 also has at least one (as shown) , but preferably a plurality of sensor regions 28, each having a grating 40, such as a LPG grating.
  • the cable 20 has the configuration of Example A or B - that is, at sensor region 28, core 22 is clad with sensor cladding 36 (or, optionally, and not shown, with a conventional cladding and a sensor coating) .
  • the cable 20 may have both sensor cladding 36 and sensor coating 37 at sensor region 28, and more conventional cladding 24 and coating 26 in other regions of the cable 20, or, as shown in Figure 14, sensor coating 36 in the sensor region, and conventional cladding 24 throughout.
  • the entire cable 20 may be coated in sensor coating 37, which would "fill in” gaps in buffer coating 26 in sensing regions 28.
  • the sensor buffer coating 37 would only be functional at sensor region 28, since it would otherwise have no or little effect on light transmission through core 22, due to conventional buffer coating 26.
  • cladding 24 may also be absent in the sensor regions 28.
  • the cable 20 may be configured within a conduit 70.
  • Figure 16 shows a cable 20 of Figure 8, within a conduit 70.
  • Conduit 70 comprises a plurality of perforations or openings 72 (such as circular holes, but optionally of alternate shape, size or form) to allow the ingress of hydrocarbon from an oil spill, as well as drainage of water out of the conduit 70.
  • the conduit 70 may be made of plastic, preferably rigid plastic, or a metallic tube.
  • configuring cable 20 within conduit 70 makes the system much more robust and impact resistant, and most importantly it isolates and mitigates the effects of the strain on the sensors, thus being able to obtain a more clear RI related signal.
  • cable 20 may be packed within a hydrocarbon-permeable filler or
  • substance 74 such as lightly packed sand, or polymer beads preferably with heat insulative properties, to further improve impact resistance and reduce the effect of strain, impact, compression and particularly temperature on the cable.
  • Conduit 70 provides mechanical protection to cable 20, and reduces strains on the cable, resulting in less false positive signals.
  • the substrate 74 acts to dampen the effects of temperature change on the signal transmitted through the fiber.
  • Control cable 200 comprises fiber optic cable core 22 clad in a conventional cladding 24 and a conventional outer sheath 26.
  • control cable 200 also comprises gratings 40, which can be identical to the gratings in fiber optic cable 20, or which may have a different period.
  • a light signal transmitted in control cable 200 will respond near identically to a light signal transmitted in cable 20 when "at rest", and when subjected to traditional strain such as temperature changes or impact strain.
  • the difference in transmission between cable 20 and control cable 200 will be a result of changes in RI of sensor cladding 36, and, thus, use of control cable 200 can lead to a significant reduction of false
  • the distributed sensor of Examples A and/or B can be combined with point sensors of Examples D and/or E; sensing regions of the point sensors of Examples D and/or E can be redundant and/or staggered along the length of the pipeline; and all of these can be run in combination with control cable of Example C.
  • Figure 19 shows, in schematic form and not to scale, a further type of known fiber optic cable bundle 2000.
  • the fiber optic cable 2000 contains a plurality of core 22, each surrounded by cladding 24. Each may additionally and optionally be
  • bundle jacket 47 which, as previously described, may be made from a material which is permeable or semi-permeable to hydrocarbon.
  • bundle jacket 47 may also be perforated, braided, or a mesh.
  • such a cable 20 can be configured such that the sensor regions 28, each as described in any one of the previous examples, can be staggered as shown in Fig 10, thus being at different location along the fiber optic cable 2000.
  • Further cores may be control cores, or distributed sensors as herein described. In one example, merely to illustrate the point, a 1 km long cable 2000 having 100 cores 22, might only need ten sensor regions 28 and ten
  • such a cable 2000 would have 1000 sensor regions 28 total, and either 1000 regions in the protective outer jacket 47 that were permeable to hydrocarbon, or, in a preferred embodiment, a protective outer jacket 47 that was entirely permeable to hydrocarbon, for example an outer jacket that is perforated or braided. It could also be a perforated conduit made from a metal such as steel or made from plastic.
  • Figure 20 shows a schematic of the cable 20 of Figure 1 in use.
  • the fiber optic cable 20 is imbedded into the coating of, affixed to, or (as shown) laid proximal to a pipeline 30.
  • a light emitter 42, and a light detector 44, able to measure the wavelength or light spectrum being emitted by light emitter 42, are functionally connected to the fiber optic cable.
  • the light emitter 42 is activated, projecting light into the fiber optic cable's glass fiber core 22.
  • the light detector 44 measures the wavelength (or wavelength spectrum) of the light reflected back by the FBG grating 40, providing a baseline measurement of light reflectance (illustrated in Figure 6 as peak 54 on monitor 48, though it would be
  • the signal could simply be analyzed and processed automatically by a computer algorithm) .
  • RI outer sheath 38 optionally dissolve
  • contact sensor cladding 36 optionally dissolve
  • sensor cladding 36 will for example swell, or dissolve, changing its refractive index.
  • the resulting refractive index will effect the reflection/refraction of light within the core 22.
  • a second light detector 50 placed at the end of the fiber optic cable, measures light passing through the cable.
  • all light except the light reflected back due to the FBG grating will provide a light output 58 as illustrated on monitor 52.
  • An oil leak will cause a resulting in output 60 as shown on monitor 52.
  • the light emitter 42 will emit light at a very specific and narrow wavelength. In certain embodiments, such a narrow wavelength is the Bragg wavelength; in these cases, all light emitted by light emitter 42 will be reflected back to light detector 44.
  • the change in refractive index of the sensor region will cause a shift in the wavelength being reflected, causing, in effect, certain amount of light to be transmitted to the second light detector 60. It is noted that in the case of the FBG sensors, similar changes may occur as a result of temperature and strain.
  • Example H LPG Gratings While all of the sensor cables described herein are able to sense and detect hydrocarbon, it has been discovered that the use of sensor regions containing LPG gratings provide the most efficient way to highlight the effects of the RI changes and to manage and minimize the effects of temperature and strain.
  • FBGs have a sub-micron period and couple light from the forward propagating core mode of the optical fiber to a backward propagating modes. While LPG has a period typically in the range lOOpm to 1mm and couple light between propagating core mode and co-propagating cladding modes.
  • Optical power coupled to the cladding modes are strongly affected by imperfections in fiber, micro and macro bending, and boundary conditions at the cladding-external medium interface. As light travels through the grating region, the light coupled from core mode to different cladding modes leaks out of the fiber resulting in the transmission spectrum of the fiber containing a series of attenuation bands centered at discrete wavelengths. This sensitivity of LPG spectrum and attenuation bands to the external refractive index is being used here to design it as a hydrocarbon sensors.
  • SRI surrounding refractive index
  • the cladding layer acts as an infinitely extended medium and thus supports no discrete cladding modes. In this case, a broadband radiation mode coupling occurs with no distinct attenuation bands.
  • the external RI becomes equal to that of silica
  • LPG sensors While the LPG sensors are most respondent to the RI changes in the sensor cladding 36 or sensor buffer 37, it is still susceptible to temperature and strain. It is preferable to minimize the effects of the latter, to enhance the efficiency as a chemical sensor.
  • the sensitivity of LPG towards temperature depends on three factors - period of LPG, order of the cladding mode and composition of optical fiber. When all these factors combine together one can produce an LPG sensor that can give positive temperature sensitivity, negative temperature sensitivity and temperature insensitive sensor as well. (Reference: Shima K r Himeno K r Sakai T, Okude S and Wada A "A novel temperature-insensitive long-period grating using a boron-codoped germanosilicate core-fibre" Tech.
  • LPG grating period as well as a selection of core (for example, a boron codoped germanosilicate core fiber) can increase signal to noise ratio, by reducing the effect of temperature changes on the sensed signal.
  • core for example, a boron codoped germanosilicate core fiber
  • the invention provides a robust design for a reliable and consistent hydrocarbon LPG sensor design for leak detection.

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  • Physics & Mathematics (AREA)
  • Engineering & Computer Science (AREA)
  • Acoustics & Sound (AREA)
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  • General Engineering & Computer Science (AREA)
  • General Physics & Mathematics (AREA)
  • Investigating Or Analysing Materials By Optical Means (AREA)

Abstract

L'invention concerne un dispositif de détection à fibre optique pour détecter des fuites d'hydrocarbure dans un pipeline. Le dispositif est basé sur une âme de fibre optique, et un revêtement ou gaine tampon entourant ladite âme, et ayant, au moins à certains emplacements, un indice de réfraction qui est modifié lorsqu'il est mis en contact avec un hydrocarbure, d'une manière qui modifie les caractéristiques de réflexion interne de l'âme/dispositif. Le dispositif peut utiliser un ou plusieurs réseaux de bragg à fibre, par exemple des réseaux de bragg à fibre oblique, ou un ou plusieurs effilements à l'intérieur de l'âme pour améliorer la détection.
PCT/CA2019/050253 2018-03-02 2019-03-01 Capteur de détection de fuite d'hydrocarbures pour oléoducs et gazoducs WO2019165562A1 (fr)

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WO2020170047A1 (fr) * 2019-02-22 2020-08-27 National Research Council Of Canada Appareil, procédé et système pour détecter la présence d'un fluide
WO2021097581A1 (fr) * 2019-11-22 2021-05-27 Shawcor Ltd. Capteur à fibre optique pour détection d'hydrocarbures et de produits chimiques
US11112035B2 (en) 2019-03-28 2021-09-07 Trinity Bay Equipment Holdings, LLC System and method for securing fittings to flexible pipe
US11148904B2 (en) 2019-12-19 2021-10-19 Trinity Bay Equipment Holdings, LLC Expandable coil deployment system for drum assembly and method of using same
US11204114B2 (en) 2019-11-22 2021-12-21 Trinity Bay Equipment Holdings, LLC Reusable pipe fitting systems and methods
US11208257B2 (en) 2016-06-29 2021-12-28 Trinity Bay Equipment Holdings, LLC Pipe coil skid with side rails and method of use
US11231145B2 (en) 2015-11-02 2022-01-25 Trinity Bay Equipment Holdings, LLC Real time integrity monitoring of on-shore pipes
US11231134B2 (en) 2014-09-30 2022-01-25 Trinity Bay Equipment Holdings, LLC Connector for pipes
US11242948B2 (en) 2019-11-22 2022-02-08 Trinity Bay Equipment Holdings, LLC Potted pipe fitting systems and methods
US11378207B2 (en) 2019-11-22 2022-07-05 Trinity Bay Equipment Holdings, LLC Swaged pipe fitting systems and methods
US11407559B2 (en) 2018-02-01 2022-08-09 Trinity Bay Equipment Holdings, LLC Pipe coil skid with side rails and method of use
US11453568B2 (en) 2017-08-21 2022-09-27 Trinity Bay Equipment Holdings, LLC System and method for a flexible pipe containment sled
US11492241B2 (en) 2016-06-28 2022-11-08 Trinity Bay Equipment Holdings, LLC Half-moon lifting device
US11499653B2 (en) 2020-02-17 2022-11-15 Trinity Bay Equipment Holdings, LLC Methods and apparatus for pulling flexible pipe
US11512796B2 (en) 2018-02-22 2022-11-29 Trinity Bay Equipment Holdings, LLC System and method for deploying coils of spoolable pipe
US11548755B2 (en) 2019-02-15 2023-01-10 Trinity Bay Equipment Holdings, LLC Flexible pipe handling system and method of using same
US11560080B2 (en) 2016-10-10 2023-01-24 Trinity Bay Equipment Holdings, LLC Installation trailer for coiled flexible pipe and method of utilizing same
US11613443B2 (en) 2019-11-01 2023-03-28 Trinity Bay Equipment Holdings, LLC Mobile cradle frame for pipe reel
US11643000B2 (en) 2018-10-12 2023-05-09 Trinity Bay Equipment Holdings, LLC Installation trailer for coiled flexible pipe and method of utilizing same
US11644136B2 (en) 2008-06-09 2023-05-09 Trinity Bay Equipment Holdings, LLC Flexible pipe joint
US11667492B2 (en) 2016-10-10 2023-06-06 Trinity Bay Equipment Holdings, LLC Expandable drum assembly for deploying coiled pipe and method of using same
US11767192B2 (en) 2017-11-01 2023-09-26 Trinity Bay Equipment Holdings, LLC System and method for handling reel of pipe
US12000512B2 (en) 2011-10-04 2024-06-04 Trinity Bay Equipment Holdings, LLC Pipe end fitting with improved venting
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US12000512B2 (en) 2011-10-04 2024-06-04 Trinity Bay Equipment Holdings, LLC Pipe end fitting with improved venting
US11231134B2 (en) 2014-09-30 2022-01-25 Trinity Bay Equipment Holdings, LLC Connector for pipes
US11231145B2 (en) 2015-11-02 2022-01-25 Trinity Bay Equipment Holdings, LLC Real time integrity monitoring of on-shore pipes
US11680685B2 (en) 2015-11-02 2023-06-20 Trinity Bay Equipment Holdings, LLC Real time integrity monitoring of on-shore pipes
US11492241B2 (en) 2016-06-28 2022-11-08 Trinity Bay Equipment Holdings, LLC Half-moon lifting device
US11208257B2 (en) 2016-06-29 2021-12-28 Trinity Bay Equipment Holdings, LLC Pipe coil skid with side rails and method of use
US11667492B2 (en) 2016-10-10 2023-06-06 Trinity Bay Equipment Holdings, LLC Expandable drum assembly for deploying coiled pipe and method of using same
US11560080B2 (en) 2016-10-10 2023-01-24 Trinity Bay Equipment Holdings, LLC Installation trailer for coiled flexible pipe and method of utilizing same
US11453568B2 (en) 2017-08-21 2022-09-27 Trinity Bay Equipment Holdings, LLC System and method for a flexible pipe containment sled
US11767192B2 (en) 2017-11-01 2023-09-26 Trinity Bay Equipment Holdings, LLC System and method for handling reel of pipe
US11407559B2 (en) 2018-02-01 2022-08-09 Trinity Bay Equipment Holdings, LLC Pipe coil skid with side rails and method of use
US11512796B2 (en) 2018-02-22 2022-11-29 Trinity Bay Equipment Holdings, LLC System and method for deploying coils of spoolable pipe
US11643000B2 (en) 2018-10-12 2023-05-09 Trinity Bay Equipment Holdings, LLC Installation trailer for coiled flexible pipe and method of utilizing same
US11548755B2 (en) 2019-02-15 2023-01-10 Trinity Bay Equipment Holdings, LLC Flexible pipe handling system and method of using same
WO2020170047A1 (fr) * 2019-02-22 2020-08-27 National Research Council Of Canada Appareil, procédé et système pour détecter la présence d'un fluide
US11112035B2 (en) 2019-03-28 2021-09-07 Trinity Bay Equipment Holdings, LLC System and method for securing fittings to flexible pipe
US11613443B2 (en) 2019-11-01 2023-03-28 Trinity Bay Equipment Holdings, LLC Mobile cradle frame for pipe reel
US11242948B2 (en) 2019-11-22 2022-02-08 Trinity Bay Equipment Holdings, LLC Potted pipe fitting systems and methods
US20220412834A1 (en) * 2019-11-22 2022-12-29 Shawcor Ltd. Fiber optics sensor for hydrocabon and chemical detection
US11204114B2 (en) 2019-11-22 2021-12-21 Trinity Bay Equipment Holdings, LLC Reusable pipe fitting systems and methods
US11378207B2 (en) 2019-11-22 2022-07-05 Trinity Bay Equipment Holdings, LLC Swaged pipe fitting systems and methods
EP4062151A4 (fr) * 2019-11-22 2023-12-06 ShawCor Ltd. Capteur à fibre optique pour détection d'hydrocarbures et de produits chimiques
WO2021097581A1 (fr) * 2019-11-22 2021-05-27 Shawcor Ltd. Capteur à fibre optique pour détection d'hydrocarbures et de produits chimiques
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