WO1997021117A1 - Structures de materiaux composites possedant une attenuation de signal reduite - Google Patents

Structures de materiaux composites possedant une attenuation de signal reduite Download PDF

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Publication number
WO1997021117A1
WO1997021117A1 PCT/CA1996/000768 CA9600768W WO9721117A1 WO 1997021117 A1 WO1997021117 A1 WO 1997021117A1 CA 9600768 W CA9600768 W CA 9600768W WO 9721117 A1 WO9721117 A1 WO 9721117A1
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WO
WIPO (PCT)
Prior art keywords
tube
composite
fittings
composite tube
fibre
Prior art date
Application number
PCT/CA1996/000768
Other languages
English (en)
Inventor
Daniel Guy Pomerleau
Brian Spencer
Mark Voghell
Doug Maclean
Paul Pastushak
Original Assignee
Lwt Instruments Inc.
Priority date (The priority date is an assumption and is not a legal conclusion. Google has not performed a legal analysis and makes no representation as to the accuracy of the date listed.)
Filing date
Publication date
Priority claimed from US08/740,665 external-priority patent/US5988300A/en
Application filed by Lwt Instruments Inc. filed Critical Lwt Instruments Inc.
Priority to CA 2237432 priority Critical patent/CA2237432A1/fr
Priority to AU75589/96A priority patent/AU7558996A/en
Priority to EP96937962A priority patent/EP0865613A1/fr
Publication of WO1997021117A1 publication Critical patent/WO1997021117A1/fr
Priority to NO982427A priority patent/NO982427L/no

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Classifications

    • E—FIXED CONSTRUCTIONS
    • E21—EARTH OR ROCK DRILLING; MINING
    • E21B—EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
    • E21B47/00—Survey of boreholes or wells
    • E21B47/01—Devices for supporting measuring instruments on drill bits, pipes, rods or wirelines; Protecting measuring instruments in boreholes against heat, shock, pressure or the like
    • G—PHYSICS
    • G01—MEASURING; TESTING
    • G01V—GEOPHYSICS; GRAVITATIONAL MEASUREMENTS; DETECTING MASSES OR OBJECTS; TAGS
    • G01V3/00—Electric or magnetic prospecting or detecting; Measuring magnetic field characteristics of the earth, e.g. declination, deviation
    • G01V3/18—Electric or magnetic prospecting or detecting; Measuring magnetic field characteristics of the earth, e.g. declination, deviation specially adapted for well-logging
    • E—FIXED CONSTRUCTIONS
    • E21—EARTH OR ROCK DRILLING; MINING
    • E21B—EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
    • E21B17/00—Drilling rods or pipes; Flexible drill strings; Kellies; Drill collars; Sucker rods; Cables; Casings; Tubings
    • E—FIXED CONSTRUCTIONS
    • E21—EARTH OR ROCK DRILLING; MINING
    • E21B—EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
    • E21B17/00—Drilling rods or pipes; Flexible drill strings; Kellies; Drill collars; Sucker rods; Cables; Casings; Tubings
    • E21B17/003—Drilling rods or pipes; Flexible drill strings; Kellies; Drill collars; Sucker rods; Cables; Casings; Tubings with electrically conducting or insulating means
    • E—FIXED CONSTRUCTIONS
    • E21—EARTH OR ROCK DRILLING; MINING
    • E21B—EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
    • E21B17/00—Drilling rods or pipes; Flexible drill strings; Kellies; Drill collars; Sucker rods; Cables; Casings; Tubings
    • E21B17/10—Wear protectors; Centralising devices, e.g. stabilisers
    • E—FIXED CONSTRUCTIONS
    • E21—EARTH OR ROCK DRILLING; MINING
    • E21B—EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
    • E21B47/00—Survey of boreholes or wells
    • E21B47/08—Measuring diameters or related dimensions at the borehole
    • E21B47/085—Measuring diameters or related dimensions at the borehole using radiant means, e.g. acoustic, radioactive or electromagnetic
    • E—FIXED CONSTRUCTIONS
    • E21—EARTH OR ROCK DRILLING; MINING
    • E21B—EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
    • E21B47/00—Survey of boreholes or wells
    • E21B47/12—Means for transmitting measuring-signals or control signals from the well to the surface, or from the surface to the well, e.g. for logging while drilling
    • E21B47/13—Means for transmitting measuring-signals or control signals from the well to the surface, or from the surface to the well, e.g. for logging while drilling by electromagnetic energy, e.g. radio frequency
    • G—PHYSICS
    • G01—MEASURING; TESTING
    • G01V—GEOPHYSICS; GRAVITATIONAL MEASUREMENTS; DETECTING MASSES OR OBJECTS; TAGS
    • G01V1/00—Seismology; Seismic or acoustic prospecting or detecting
    • G01V1/40—Seismology; Seismic or acoustic prospecting or detecting specially adapted for well-logging
    • G—PHYSICS
    • G01—MEASURING; TESTING
    • G01V—GEOPHYSICS; GRAVITATIONAL MEASUREMENTS; DETECTING MASSES OR OBJECTS; TAGS
    • G01V5/00—Prospecting or detecting by the use of ionising radiation, e.g. of natural or induced radioactivity
    • G01V5/04—Prospecting or detecting by the use of ionising radiation, e.g. of natural or induced radioactivity specially adapted for well-logging

Definitions

  • the present invention relates to composite material structures having reduced signal attenuation properties.
  • the invention relates to composite drillstring components which exhibit a degree of transparancy which permits for the transition of electromagnetic fields, acoustic signals and echos and nuclear media thus enabling the use of electromagnetic, acoustic and nuclear sensing equipment to obtain data from a wellbore from within a drill pipe.
  • a composite tube is incorporated with end-fittings which enable its incorporation into a drillstring thereby permitting the use of logging equipment from within the composite tube.
  • MWD measurement while drilling
  • LWD logging while drilling
  • LWT logging while tripping
  • MTT measurement while tripping
  • sensing technologies and devices such as spectral gamma ray, neutron emission and detection, radio frequency tools, nuclear magnetic resonance, acoustic imagery, acoustic density, acoustic calipers, gamma ray emission and detection, density logs, sonic logs and a range of other instrumentation to obtain detailed information concerning the formation surrounding a borehole.
  • electromagnetic and acoustic sensing devices cannot be operated from within a metal drill pipe in view of the inability of an electromagnetic or acoustic sensing device to operate through a metal drill pipe.
  • the use of sensing devices operable through a metal pipe may result in severe attenuation of any data signal, thereby limiting the accuracy of obtaining a data log of the formation.
  • tubing for use in both the drilling and casing phases of a borehole which does not prevent or severely attenuate the use of sensing equipment within the borehole.
  • tubing that enables the use of a full range MWD, LWD, LWT and MWT technologies.
  • the drilling borehole environment is an extremely abrasive, high stress environment that requires very high standards of performance and quality in drilling equipment. These standards and performance characteristics for drilling equipment are set forth, in part, by the American Petroleum Institute (API Specification 7 for Rotary Drill Stem Elements) and detail numerous specifications for drill pipes and casings (API Specification 5 for casings) for use in boreholes.
  • API Specification 7 for Rotary Drill Stem Elements
  • API Specification 5 for casings for use in boreholes.
  • tubing which meets API specifications for drillstring components which further provide the necessary conductivity to the operating frequencies of sensing equipment used in MWD, LWD, LWT and MWT operations.
  • composite tubing conductive to radio frequency and acoustic signals which also result in a reduction of attenuation of natural decay waves/particles (gamma rays, beta particles, etc.) passing through the tubing.
  • a composite tube does not have the abrasion resistance qualities of steel, there has been a need for a composite tube with an outer surface material that reduces abrasive wear to a drilling sub or casings caused by contact with the borehole.
  • Conductive fibres such as carbon provide electromagnetic shielding and are often used to enhance the shielding capabilities of insulating plastics.
  • the addition of carbon fibre to nylon increases signal attenuation. Accordingly, in that it is known that the choice of carbon fibre as a material for a reinforcing medium is detrimental to the objective of EM transparency, there has been a need for a composite tube design wherein the design facilitates the use of carbon fibre while providing acceptable EM transparency.
  • a composite body having signal attenuation properties for a physical and performance design point, the composite body comprising a plurality of fibre layers impregnated with a binder, wherein each fibre layer is selected from fibre materials having different mechanical and signal attenuation properties and wherein each fibre layer is orientated with respect to a reference axis in accordance with desired mechanical, signal attenuation and phase shift properties of the design point.
  • the fibre layers include any one of or a combination of fibreglass fibres, aramid fibre and carbon fibre wherein the carbon fibre is oriented at ⁇ 10° with respect to a reference axis to minimize signal attenuation and the binder is an epoxy resin.
  • the binder is cement selected from any one of or a combination of portland cement, portland-aluminous-gypsum cement, gypsum cement, aluminous-phosphate cement, portland-sulfoaluminate cement, calcium silicate-monosulfoaluminate cement, glass ionomer cement, or other inorganic cement.
  • the invention provides a composite tube for use in a drillstring, the composite tube comprising a plurality of resin-impregnated fibre layers of a first type and a second type wherein the first type layers are interspersed by layers of the second type, the composite tube adapted for receiving a logging tool.
  • the first layer type is wound at ⁇ 10° with respect to the longitudinal axis of the tube, the first layer type comprising 0-50% high modulus carbon fibre, 0-50% aramid fibre and 16-50% high strength fibre glass and the second layer type is wound at 90° with respect to the longitudinal axis of the tube, the second type comprising 100% high strength fibreglass.
  • the first layer type constitutes 90% of the total wall thickness of the tube and the second layer type is equally interspersed through the tube wall at 1-9 discrete radial positions.
  • the invention provides a composite tube wherein the first layer type is wound at + 10° with respect to the longitudinal axis of the tube, the first layer type comprising 25% high modulus carbon fibre, 25% aramid fibre and 50% high strength fibre glass.
  • the composite tube has a signal attenuation response of at least 70% at 20 Khz and a microstructure with a fibre volume fraction of approximately 60% .
  • the tube When used in a drillstring, the tube is preferably 7-31 feet long and meets the performance requirements detailed in Table 1 including tensile load, compressive load, torsional load, internal pressure, endurance limit, lateral stiffness, impact strength, tensile strength, and yield strength which meet or exceed the standards of the American Petroleum Institute Specification 7.
  • the composite tube further comprises an abrasion resistant coating on the outer surface of the tube and/or the resin-impregnated fibre layers include a ceramic powder blended with the resin.
  • the composite tube further comprises end-fittings integrally attached to the composite tube by additional fibre layers and resin and/or cement.
  • the end-fittings include:
  • At least one compression bearing surface for supporting a compression load between the end-fittings and the basic composite tube
  • At least one torsional transfer surface for transferring torsional load between the end-fittings and the basic composite tube
  • At least one axial tension surface for supporting an axial tension load between the end-fittings and basic composite tube.
  • the torsional transfer surface(s) comprises eight surfaces which are either parallel or tapered with respect to the longitudinal axis of the end-fittings.
  • the end-fittings are attached to the basic composite tube by additional winding of binder-impregnated fibre and where the additional winding is high modulus carbon fibre wound at 90°.
  • the end-fittings further comprise stabilizers which may include rutile or zirconium focussing lenses for use with micro pulse imaging radar.
  • the composite tube/end fitting junction is pre-stressed or pre-loaded to reduce the susceptability to fatigue damage.
  • the invention provides a drillstring member having a composite tube middle section with integral end-fittings, the composite tube middle section having a signal transparency comprising:
  • the basic composite tube including a plurality of binder- impregnated fibre layers of a first and second type wherein the first type layers are interspersed by layers of the second type and the first layers are wound at ⁇ 10° with respect to the longitudinal axis of the tube, the first layer type comprising 40% high modulus carbon fibre, 44% aramid fibre and 16% high strength fibre glass and the first layer constitutes 90% of the total wall thickness of the tube and wherein the second layer type is wound at 90° with respect to the longitudinal axis of the tube, the second type comprising 100% high strength fibre glass equally interspersed through the tube wall at a plurality of discrete radial positions;
  • end-fittings including:
  • a tube seat for seating the end-fitting within a basic composite tube
  • At least one compression bearing surface for supporting a compression load between the end-fittings and the basic composite tube
  • At least one torsional transfer surface for transferring torsional load between the end-fittings and the composite basic tube
  • a bending stress transfer surface for supporting a bending stress load between the end-fittings and basic composite tube; at least one axial tension surface for supporting an axial tension load between the end-fittings and basic composite tube.
  • a method of forming a composite tube with integral end-fittings comprising the steps of: a) winding a basic inner tube of a binder-saturated fibre on a steel mandrel; b) curing the binder to form a cured tube; c) removing the mandrel from the cured tube; d) cutting the cured tube to length to form a basic tube; e) inserting an alignment mandrel within the basic tube and seating end-fittings within the basic tube over the alignment mandrel; f) winding an outer layer of binder-saturated fibre over the basic tube and end- fittings to form composite tube with end-fittings.
  • an adhesive coating is added to the outer surface of the composite tube to increase wear resistance.
  • Further emobiments of the invention provide for pre-stressing the composite/end-fitting junction by methods such as compressing the cured tube and end-fittings during wrapping and curing of the outer fibre layers, ensuring the coefficient of thermal expansion of the composite tube is less than the coefficient of thermal expansion of the end-fittings wherein during wrapping and curing of the outer fibre layers a compressive force is induced on the end-fitting, adapting the end-fittings to receive a lock nut for imparting a compressive force on the composite/end-fitting junction or providing end-fittings which include an inner and outer end-fitting adapted to impart a compressive force on the composite/end-fitting junction.
  • Figure 1 is a graph of phase shift vs. frequency for a number of basic composite tube samples on a log x, linear y scale;
  • Figure 2 is a graph of signal attenuation vs. frequency for a number of basic composite tube samples on a log x, linear y scale
  • Figure 3 is a close-up view of the graph of the results of Figure 2 normalized to a 2.5" working thickness showing signal attenuation vs. frequency for basic composite tube samples on a linear x-y scale;
  • Figure 4 is a graph of the results of Figure 1 normalized to a 2.5" working thickness showing phase shift vs. frequency for basic composite tube samples on a linear x, log y scale;
  • Figure 5 is an assembly drawing of a composite tube and end-fittings in accordance with the invention.
  • Figure 6 is a cross-sectional drawing of an end-fitting in accordance with the invention.
  • Figure 6A is a cross-sectional drawing of the end-fitting of Figure 6 at the line 6A-6A;
  • Figure 6B is a cross-sectional drawing of the end-fitting of Figure 6 at the line 6B-6B;
  • Figure 6C is a cross-sectional drawing of the end-fitting of Figure 6 showing preferred dimensions for a nominal 6 3/4 - 7 inch tool;
  • Figure 7 is a drawing of an assembled composite tube with end-fittings in accordance with one embodiment of the invention showing a logging tool within the body of the assembly;
  • Figure 8 is a torsion load free-body diagram for the design of the torque transfer surface(s).
  • Figure 9 is a cross-sectional view of a composite tube/end-fitting assembly in which the end-fittings include an inner and outer end-fitting;
  • Figure 9A is a partial cross-sectional view of another embodiment of a composite tube/end- fitting assembly in which the end-fittings include an inner and outer end-fitting;
  • Figure 10 is a partial cross-sectional view of a composite tube/end-fitting assembly in which the end-fittings include a lock-nut;
  • Figure 11 is a partial cross-sectional view of a composite tube/end-fitting assembly in which the end-fittings include an inner and outer end-fitting;
  • Figure 12 is a comparison of a gamma ray log of a section of a wellbore comparing a conventional wire-line log with a logging while tripping log;
  • high modulus carbon fibre in a composite body affects the electromagnetic attenuation properties of the composite body. It is also known that materials such as fibreglass and aramid fibre do not significantly affect these properties. For particular applications, high modulus carbon fibre has superior strength and performance characteristics over fibreglass and aramid fibre and is, accordingly, well suited for certain applications. Thus, in the past, where it is desirable to provide a composite body having electromagnetic transparency properties, the use of carbon fibre is minimized.
  • the design of a composite body with particular strength and/or performance properties within particular physical dimensions requires that the composite body meets or exceeds the design conditions while remaining within the size restrictions. Accordingly, with the introduction of additional parameters, such as minimal electromagnetic signal attenuation, it has previously been considered that the use of a known attenuating material such as carbon fibre must be minimized or eliminated in order to meet this electromagnetic attenuation design requirement. However, in certain applications, in view of the physical size requirements of the composite body and/or the strength/physical performance requirements, the use of carbon fibre cannot be eliminated while still meeting the strength/physical performance requirements.
  • the subject application has recognized that the carbon fibre orientation within the composite body is related to the electromagnetic attenuation properties of the composite body, thus rendering it possible to design a composite body with the required high strength/physical size limitations while also achieving the desired electromagnetic attenuation properties.
  • the subject invention has recognized that the orientation of carbon fibre within a composite body and, in particular, a composite tube enables sensing equipment utilizing electromagnetic sensors to be placed within the composite tube which provide an acceptable data acquisition signal. Essentially, by dispersing the carbon fibre with glass fibre in conjunction with a low wrapping angle, a highly conductive annulus of conductive fibre is avoided.
  • this invention has developed a composite/metal tube for use in a drillstring for downhole drilling operations.
  • a segmented design is provided with end-fittings on either side of a composite middle section.
  • the end-fittings enable integration of the composite/metal drilling tube to an existing steel drillstring while the composite middle section enables the placement and use of logging while tripping, logging while drilling, measurement while tripping and measurement while drilling equipment within this section.
  • the composite middle section has an acceptable electromagnetic transparency in the range of OkHz-200kHz.
  • the design of a composite tube with integral end-fittings for use in a drillstring while having specific electromagnetic properties requires the composite tube section to have both the physical strength, performance and size characteristics of existing steel drilling tubes (as per API specifications, where applicable) as well as the required electromagnetic properties. Furthermore, the composite tube with integral end-fittings must provide a composite/metal junction which provides optimal performance characteristics, primarily a satisfactory durability in the high stress drilling environment.
  • the composite/metal tube has the following components:
  • electromagnetic transparency properties are also required to permit logging equipment to effectively record downhole characteristics. Reduced signal attenuation provides superior data acquisition.
  • Logging equipment may include both electrode devices and/or induction devices to obtain information from the formation. Electrode devices require direct contact with the mildly conductive borehole mud to inject currents into the formation. When measurements are performed in lower conductivity air-filled or oil-based boreholes, conventional electrode- based methods are not possible. As this measurement method is limited to direct contact with a borehole mud, measurements through neither a highly conductive all-steel drill sub nor a composite drill sub are possible.
  • An induction device measures the formation conductivity through the use of secondary eddy currents induced into the formation. This measurement is superior in lower conductivity air-filled or oil-based boreholes and it can also tolerate the more typically encountered mildly conductive mud environments. Induction logging has proven to be very versatile and today forms the primary means of evaluating formation resistivity. As in the case of electrode devices, measurements are not possible through an all-steel drill sub but are possible through a mildly conductive composite sub.
  • a constant amplitude and frequency alternating current is fed to a transmitter coil.
  • the resultant magnetic field produced around the transmitter coil induces eddy current flow in the formation.
  • the eddy currents will flow in paths coaxial with the borehole.
  • the eddy currents induce an alternating voltage in the detector coil that is a full 180° out of phase with the transmitter current.
  • the magnitude of the eddy currents are proportional to the conductivity of the formation.
  • the resistive component of the detector signal forms the basis of the induction measurement.
  • a 90° out of phase direct coupling signal is also received by the detector coil but is electronically filtered out.
  • composite material also allows for the use of acoustic transmitting and receiving devices to take measurements of the well bore diameters.
  • This travel time, ⁇ t, the specific acoustic time varies according to mineral composition, porosity, and the fluid present in the formation (in situ). Accordingly, further data, such as rock or mechanical properties, location of fractures can also be obtained. Imaging using acoustic reflection data is also possible.
  • the propagation of acoustic waves through composites and compensation for the composite acoustic properties can be undertaken - yielding the above whereas propagation through steel pipes is highly problematic.
  • the low density of the composite material allows for enhanced transition of gamma/neutron/beta materials through the body of the sub thereby allowing for more accurate detection of same with receivers located inside the sub.
  • the basic design of the composite tube requires low moisture abso ⁇ tion, heat resistance, and corrosion resistance.
  • the composite tube must also show the mechanical performance of an existing all-steel design as shown in Table 1. Calculations which follow refer to a nominal collar size of 6 3/4 - 7 inch. It is understood that similar calculations may be applied in the design of tools of different dimensions.
  • a basic composite tube was prepared by a computer controlled filament winding process. This process adds successive layers of a binder-impregnated fibre over a steel mandrel to build the basic tube.
  • the winding speed, spool location and spool fibre are controlled to enable the fibre, the fibre orientation and thickness to be controlled to build up successive layers of fibre in accordance with the desired end-product characteristics.
  • the fibre and fibre orientation are selected in accordance with the physical and electromagnetic properties of the design.
  • Binders are preferably either of organic or inorganic composition.
  • first type being a low angle wrap (for example, ⁇ 10° off the longitudinal axis of the tube) and the second type being circumferentially wrapped around the tube (90° to the longitudinal axis of the tube).
  • Each layer is wrapped with one half of the fibre aligned at its positive wind angle and the other half at the negative wind angle.
  • the first layer may comprise a number of different fibres within that layer such as carbon fibre, aramid fibre or fibreglass. For a given design having an electromagnetic transparency, the amount of carbon fibre is minimized while still permitting a given physical strength.
  • the second layer type may also comprise a number of different fibres within that layer. However, if the design requires electromagnetic transparency, carbon fibre would not be included in this layer.
  • the second layer type is equally interspersed through the composite tube wall at a number of discrete radial positions in order to improve the strength of the composite laminate.
  • the binder may be either a cement based composition or a standard epoxy resin.
  • cement based composition eliminates the need for high modulus carbon fibre for a significant portion of the drill sub enabling the replacement of the carbon fibre with high modulus aramid fibre.
  • the cement may be selected from any of one of or a selection of a portland cement, portland-aluminous-gypsum cements, gypsum cements, aluminous-phosphate cements, portland-sulfoaluminate cements, calcium silicate-monosulfoaluminate cements, glass ionomer cements, or other inorganic cements.
  • Techniques for the inco ⁇ oration of a cement based composition include coating glass fibres with an aqueous slurry of the cement composition as they are wound around the steel mandrel and thereafter air-curing.
  • the cement composition is added to the glass fibres during winding by placing a negative electrostatic charge on the fibres and passing them through the cement composition which has been charged to cause it to adhere to the fibres.
  • the cement composition is preferably fluidized and passed through a polarizing grid to provide the cement with a positive electrostatic charge using known fluidizing techniques. A voltage differential of about 20 kilovolts is preferred. Additional cement may also be added after winding with water or steam being added during heat curing in an autoclave.
  • the cement based binder is used to build a composite tube where it is desirable to impart a high degree of stiffness to the drill sub which may allow for either the reduction or elimination of carbon fibre within the tube. As indicated, the reduction of carbon fibre from within the tube will improve the transparency for electromagnetic signal and/or field propagation at a range of frequencies. Furthermore, the use of a cement binder may is also used to improve the abrasion resistance of the drill sub as well as lowering the density of the tube which is advantageous for particle-based sensing equipment.
  • a standard epoxy resin may be used as a binder. Evaluation of a specially formulated resin exhibiting low electrical attenuation properties was evaluated in a subscale test specimen and was found not to offer significant benefit in lowering the electrical attenuation over the standard epoxy resin binder.
  • the specific resin used for the test samples was a bisphenol F resin with a MTHPA curing agent.
  • the layer thickness is typically between 0.01 and 0.040 inches.
  • the layer thickness of the first type layers are 0.038 inches and 0.035 inches for the second type layers.
  • Curing is conducted as soon as all the filament winding is complete in a convection oven.
  • the cure schedule follows the resin manufacturers recommended procedure.
  • a typical cure consists of maintaining the oven temperature at 180°F for 4 hours, raising the temperature to 225 °F for 4 hours, raising the temperature to 300°F for 6 hours, turning the oven off and allowing the part to cool slowly to room temperature in the oven.
  • the baseline design for the composite tube used Grafil HR40 carbon fibre (Courtaulds Advanced Materials, Sacramento, CA), DuPont KevlarTM 149 and Owens-Corning E and S-2 glass.
  • the tube was fabricated with a number of laminate layers with thicknesses and fibre orientation angles as shown in Table 2.
  • Table 3 shows the mechanical properties of the baseline fibres.
  • the resin system utilized for the baseline design was Shell's DPL 862 resin.
  • Other fibres which may be used include 3M NextelTM, a ceramic fibre.
  • Other resins may be used such as the Bryte Technologies Inc. EX-1545 RTM System.
  • Lateral Stiffness The engineering of "stiffness" of a composite logging collar is accomplished through the use of a plurality of fibres which may be selected from but are not limited to carbon fibre, aramid fibre and glass fibres.
  • Standard oil field practices call for drill collars, subs, motors etc. to have a stiffness equivalent to 70-80% of a bar of solid steel of the same diameter. For example, a 6.75" diameter drill collar must be 70-80% as stiff as a solid bar of the same steel at the 6.75" diameter. This stiffness requirement is required to allow the driller to control the direction of drilling.
  • the compressional load is controlled by reducing the tension held on the drillstring by the driller using the cabling system and derrick to partially lift the drillstring from the wellbore in conjunction with the use of drill fluid to float the drillstring.
  • the driller is able to control the direction in which he is drilling by ensuring that the lower section has an "equivalence" throughout its component with respect to stiffness.
  • the composite tube was designed with a lateral stiffness of 70 - 80% of a similar steel section with the required inside and outside diameters of the tube, namely 2.25 inches, minimum, and 7.25 inches, maximum, respectively. Accordingly, with a lateral stiffness of a steel section of 2.9E9 lb-in 2 with a 29 msi (axial modulus of steel), the mimmum stiffness of the composite tube is 2.03E9 lb-in 2 . With a 7.25 inch outside diameter and 2.5 inch inside diameter, the minimum axial modulus must be at least 15.1 msi.
  • a baseline tube design was designed having an axial modulus of 17.8 msi.
  • the basic composite tube was analysed for stress and strain under a combined loading condition of 800,000 pound axial tension load and a 50,000 Ib-ft torsion load.
  • the laminate design at a section away from the shaft end was analysed using classical lamination theory. A description of this analysis is found in Mechanics of Composite Materials by Robert M. Jones (published by McGraw-Hill Book Company, 1975) and was used to determine layer stress and strain state under external loading conditions.
  • the analysis provides a point stress analysis of a laminate under in-plane loads.
  • the laminate constitutive relation is formulated and is used to determine mid-plane strains and curvatures which arise due to in- plane loads.
  • the mid-plane strains and curvatures are then used to determine the layer strains and, therefore, the stresses in each layer of the laminate.
  • the loads used in the program are input as running loads.
  • the axial and torsion running loads for the composite body are calculated below.
  • the maximum compressive impact load is 300,000 pounds.
  • Electromagnetic Transparency Testing of the Basic Composite Tube Tube Sample A was constructed as a control to compare variations in design with respect to the expected attenuation and phase response. Tube A also served as a reference in the manufacture of the test apparatus.
  • Tube Sample A was a 100% carbon fibre composition, constructed from Grafil HR-40 fibre, which has a lower conductivity in comparison to Grafil carbon fibre. As well, the HR-40 fibre has inferior mechanical properties making it an inappropriate choice for an EM transparent tube.
  • Tube Samples B & C were constructed from the mechanically superior Grafil 55-500 fibre of varying percentage concentrations.
  • the carbon fibre wrapping during construction was confined to the coaxial (ie. circumferential) orientation.
  • Tube Sample D was constructed of Grafil 55-500 carbon fibre with the coaxial carbon fibre wrapping reduced to the minimum allowed by the mechanical performance constraint.
  • Tube Samples E & F are duplicates of Tube Sample D but with differing resin properties and a reduced carbon fibre percentage concentration.
  • Tube Sample G was constructed with half the carbon fibre percentage concentration over the previous tube samples; E and F. KevlarTM fibre was substituted for the carbon fibre that was removed.
  • Table 7 A summary of the construction of these tubes and a summary of the electromagnetic testing results is shown in Table 7.
  • Table 7 A summary of the construction of these tubes and a summary of the electromagnetic testing results is shown in Table 7.
  • Table 7 A summary of the construction of these tubes and a summary of the electromagnetic testing results is shown in Table 7.
  • Table 7 A summary of the construction of these tubes and a summary of the electromagnetic testing results is shown in Table 7.
  • Table 7 A summary of the construction of these tubes and a summary of the electromagnetic testing results is shown in Table 7.
  • Table 7 Composite Tube Sample Construction; Attenuation and Phase Shift Data
  • test tubes were subjected to testing for their induction characteristics.
  • the test apparatus consisted of two coaxial encircling coils located on the interior (transmitter) and exterior (detector).
  • a signal generator was connected to the interior coil 5 and a constant amplitude, variable frequency (ac) signal was fed into the coil.
  • Measurements of voltage and phase were taken from the exterior coil with reference to the interior coil.
  • the skin depth equation describes the relationship between the amplitude and phase of an ac signal as it propagates through a conductive material.
  • the equation predicts that the 10 amplitude will be attenuated as an exponential function of distance and phase will be delayed (ie time delayed) as a function of distance. Quantitatively the equation is expressed as:
  • phase shift cos(c ⁇ t + distance / ⁇ ) expressed in radians
  • the attenuation and phase shift of each sample were tested over a frequency range of 5 to 70 kHz.
  • Table 8 shows the results of attenuation and phase shift testing conducted on the tube samples. The results are based on the individual response of each tube and are not normalized to a fixed working thickness. Table 9 presents the results after normalization to a working thickness of 2.5" .
  • Figures 1-4 are graphs of the results of attenuation and phase shift for the composite tube samples.
  • Figures 3 and 4 show the results normalized to a working thickness of 2.5".
  • Figure 3 presents a close-up of the normalized attenuation results on a linear x-axis and linear y-axis scale.
  • Tube Sample G with the percentage of carbon fibre reduced to 25 % demonstrated an attenuation response of 0.7651 and had no effect on phase shift.
  • the composite tube In addition to the physical and electromagnetic properties of the composite tube, the composite tube must be readily integrated within an existing drillstring. Accordingly, the design inco ⁇ orates a junction with end-fittings for integration of the composite tube to an existing drillstring as shown in Figures 5, 6, and 7.
  • Figure 5 is an assembly drawing of the composite tube and end-fittings in accordance with the invention showing the basic composite tube 12 assembled with the end-fittings 14. Outer wrapping 16 is shown connecting the basic composite tube 12 with the end-fittings 14.
  • Figure 6 is a cross-sectional drawing of an end-fitting showing details of the end-fittings.
  • Figures 6A and 6B show details of the cross-sections of the end-fittings at lines 6A-6A and 6B-6B respectively.
  • Figure 6C shows the preferred dimensions of the end-fittings for integration with a drillstring.
  • Figure 7 is a drawing of an alternate embodiment of the assembled composite tube/end-fitting.
  • the critical design issues for the end-fittings include body stiffness and strength in addition to load transfer between the composite body section and end-fittings.
  • the junction is designed to provide separate load paths for the axial compression and tensile loads from the composite sub body to the end-fittings in order to avoid relying on a bonded joint to carry loads for the life of the fitting.
  • the compression load is carried from the basic composite tube 12 directly against bearing surfaces 20, the axial tensile loads are carried against axial tension surfaces 22, the torsional forces are carried against the torsional transfer surfaces 24 and the bending stress forces are carried against the bending stress transfer surface 26.
  • the bending stress transfer surface 26 provides a section over which the bending load transfers from the end fitting 14 to the composite tube 16. This surface is required to prevent rotational bending fatigue from occurring in the end fitting 14. Rotational bending fatigue is a major cause of failure in downhole tools.
  • the bending stress transfer surface has a maximum diameter of 6.00 inches to maintain the strength required in the composite tube. This diameter is made as large as possible to minimize the bending stress at the shoulder 28. It has been shown that in order to prevent fatigue cracking, the minimum diameter of a reduced section of a drill sub is such that its moment of inertia (I) is no less than 29.5% of that calculated using the nominal O.D. of the drill sub. In this case, this minimum diameter is 5 inches.
  • the 4.25 inch diameter shown is less than this 5 inch minimum and consequently this section of the end fitting cannot carry the full bending load. Accordingly, the bending stress transfer surface 26 is tapered at 2 inches per foot to allow the bending load to be transferred from the end fitting 14 to the composite tube 16 prior to the 4.25 inch diameter.
  • the torsional transfer surfaces 24 provide a balance between the torsional capacity of the end fittings 14 and the composite tube 16, thus maximizing the overall torsional capacity of the assembly 10.
  • the 4.25 inch diameter is the minimum needed to meet the torsional requirements for the end fittings 14. Using this minimum diameter results in the maximum area available for the torsional transfer surfaces 24.
  • the axial tension surfaces are also provided with tapered surfaces 22.
  • end fittings 14 be manufactured from non-magnetic material to facilitate MWD tools. However, they may be manufactured from AISI 4145H MOD if magnetic properties are not a concern.
  • the metal/composite junction is designed to transfer torsion, axial compression, tensile and bending loads.
  • the design and analysis of the end-fitting considered the following:
  • the minimum diameter of the end-fitting was determined with the assumption that no yielding is permitted under the maximum loading environment.
  • the minimum factor of safety used in the analysis was 1.0 as stresses are calculated for impact environment and maximum axial and torsion load are assumed to occur at the same time.
  • the design of the tapered section of the fitting was based on the concept described in "The NCF (No Cut Fibre) Coupling", W. Rumberger, B. Spencer, Presented at the American Helicopter Society Meeting On Composites, June, 1985, Stamford, Connecticut.
  • Figure 8 shows how the torsion load is reacted by the polygon shape on the end-fitting.
  • a similar free body is used for the axial load except that the loading on the polygon surfaces is constant, not triangular, and both traps are used to react the axial tensile load.
  • the bearing stress created by the tensile load on the drill sub is calculated next and added to the stresses determined above for the torsion load.
  • This analysis includes the additional area of the conical taper in the inboard trap. This trap was not included in the calculation for reacting the torsion load because it is not a polygon. Using a similar free body diagram as presented previously the bearing load on the flats and conical taper can be calculated for the 800,000 pound axial load as shown below.
  • ⁇ BA 800,000/(sinl5)(74.91)
  • the total bearing stress on the tapered sections of the fitting are;
  • the ultimate bearing strength is 60 ksi. Since the calculated bearing stress is created by an impact load the margin is considered adequate even taking into account possible uneven load share between the two tapered sections.
  • the required area of hoop fibre to react the kick out load can be calculated as follows.
  • the fitting is designed to allow for adequate hoop fibre.
  • the hoop fibre is interspersed with the helical wound fibre.
  • the last load condition to consider is the compressive load.
  • the resulting bearing stress can be calculated as presented below:
  • the stress analysis shows that the drill sub is properly designed for all loading conditions.
  • a metal rod is placed within the basic composite tube and end-fittings 14 are placed over the metal rod.
  • Flange 29 is inserted within each end of the basic composite tube 12.
  • End plates are attached to the metal rod to lock the basic composite tube 12 and end- fittings 14 together for placement on a filament winder;
  • the outer surface of the composite tube 12 and the axial tension 22, torsional transfer 24 and bending stress transfer surfaces 26 of the end-fittings 14 are filament wound with resin impregnated fibre with a combination of helical and hoop wound fibre to an outside diameter corresponding to that of the outside diameter of the end-fittings 14.
  • an abrasion resistant coating may be blended within the binder or added after curing of the assembly on the outer surfaces of the composite tube.
  • the abrasion resistant coating is preferably a wear- resistant trowelable coating such as ArmorStoneTM CeraTrowel from DuraWear Corporation.
  • a stabilizer/wear pad 30 may be used either on the end-fittings 14 or on the composite body 15 16 in order to minimize the wear to the composite material.
  • the stabilizer/wear pad 30 may also include additional sensing elements such as rutile focussing lenses 32 as shown in Figure 7 for use with micro-pulse imaging radar equipment.
  • Stabilizers 30 may be integral or removable from the assembly 10.
  • Figure 7 also shows a logging tool 40 within the bore of the assembly 10. Examples of typical sensing equipment such as a neutron source and 20 detector 42, gamma ray detector 44, resistivity component 46 and acoustic ranging equipment 48 are also shown.
  • the ends of the assembly 10 are shown with respective threaded surfaces 50 and 52 for integration of the end-fittings 14 with a drillstring.
  • a resin including an amount of ceramic powder blended into the resin is contemplated to enhance the wear properties of the composite material.
  • Sealing of the metal/composite junction can also be implemented on a number of the junction surfaces using glues, gaskets and/or o-rings without affecting the function of the surfaces.
  • An example of a sealing system utilizing an o-ring is shown in Figure 9.
  • the end fittings are in two components, an inner fitting 14a and an outer fitting 14b joined by threads 14c.
  • the basic composite tube 12 and outer wrapping composite layers 16 are assembled as described above on the inner fitting 14a.
  • an o-ring 14d is provided which may be compressed by tightening outer fitting 14b against inner fitting 14a.
  • a further method of sealing the inner surfaces of the composite tube and junction may be utilized in which a solution of sodium silicate is pressurized within the assembly after curing of the fibre layers such that the sodium silicate is squeezed into any cracks or voids in the composite tube or at the junction and thereafter subjected to a secondary curing.
  • sealing could be achieved using a removable tube running through the bore of the composite tube and metal end-fittings.
  • the tube could run the entire length of the composite tube and end-fittings.
  • This inner composite tube would be provided with seals on its outer diameter at both ends for sealing the inner tube with respect to the outer composite tube and end-fittings and, hence, the composite/end-fitting junction.
  • metal sleeves could also be utilized to effect sealing of the composite/metal junction.
  • two separate sleeves would be utilized at both ends of the composite/end-fitting structure overlapping with the end-fitting and a short section of the inner composite tube so as to maintain the composite section in the middle of the tube.
  • Appropriate seals would be provided on each end of the sleeve to seal the composite/metal junction.
  • pre-stressing the composite/end-fitting junction may be implemented in order to reduce the risk of movement of the composite material with respect to the end-fitting while under load.
  • Several methods for the implementation of pre-stress can be utilized.
  • this assembly can be longitudinally compressed prior to and during the wrapping of the outer fibre layers. This can be achieved by compressing the end-fittings and basic composite tube whilst these components are on the assembly rod and by maintaining the appropriate compressive force during wrapping and curing of the outer layers. After curing, the compressive load is released thereby imparting a tensile load in the outer tube and, thus, a compressive load on the taper traps on the metal end-fittings.
  • the coefficient of thermal expansion of the composite tube can be made less than that of the steel end-fitting. In this situation, during curing and subsequent cooling, the composite tube would shrink faster than the metal end-fitting.
  • the composite would exert a compressive (radial) load on the metal end-fitting.
  • the geometry of the end-fitting could be adapted such that a lock nut system is implemented to impart a compressive load on the taper traps of the end-fittings.
  • a lock nut system is implemented to impart a compressive load on the taper traps of the end-fittings.
  • This can be achieved using systems as shown in Figures 9 and 9 A wherein the end-fittings are in two sections with an inner 14a and outer 14b end fitting.
  • a compression surface 14e is provided on the outer end fitting 14b which can be tightened against the outer fibre layers 16 after curing thereby imparting a compressive load on the taper traps of the metal end- fittings.
  • the geometry of the end-fitting could be adapted such that a lock-nut is used to impart a compressive load on the taper traps of the end-fitting as shown in Figure 10.
  • a nut 14f is threaded on a threaded section 14c of the metal end-fitting 14.
  • the nut 14f has a compression surface 14e which can be tightened against the outer fibre layers 16 after curing thereby imparting a compressive load on the taper traps of the metal end- fittings.
  • FIG. 11 A further example of a method of pre-stressing the joint is shown in Figure 11 wherein the end fittings are also provided as two sections as an inner 14a and outer 14b end-fitting.
  • a threaded section 14c is provided on both the inner and outer end- fittings.
  • the outer section is provided with a geometry such that the bending stress transfer surface 26 is incorporated on the outer end-fitting.
  • the outer end fitting may be tightened against the inner fitting.
  • the outer end-fitting may be tightened against the inner end- fitting thereby imparting a compressive and radial load on the junction.
  • TTS Tubular Testing System
  • Displacement was measured directly from the TTS actuator Linear Variable Differential Transformer (LVDT).
  • TheLVDT serial number 91203 had a ⁇ 0.5% % ( ⁇ 0.010 inch) full-scale error for the ⁇ 50 mm range used for this test.
  • Applied load, actuator displacement, and time were monitored continuously during testing and recorded to disk via a digital data acquisition system.
  • Torsional testing was conducted in clockwise (make-up) and counter-clockwise (break) directions to verify torsional capacity.
  • Torsional testing consisted of static torque up to 50,000 ft-lbs. make-up in 5,000 ft-lbs increments followed by a static torque to 45,000 ft-lbs break in 5,000 ft-lbs increments. Additional testing included cycling make-up torque at 20,000-25,000 ft-lbs followed by cycling break torque at 20,000-25,000 ft-lbs for 10 cycles each. Static torque to 50,000 ft- lbs make-up and 45,000 ft-lbs break was applied again after cyclic testing to verify torsional integrity.
  • the composite drill sub was successfully tested at a downhole training service facility in an environment typical to those of a drilling rig in a field setting.
  • the composite drill sub was subjected to typical downhole conditions as well as being subjected to a logging run in which the enhanced transparancy and propagation properties of the drill sub were compared with those of an all-steel logging sub.
  • the testing involved assembling a composite drill sub into the bottom hole assembly of a drillstring at the surface and tripping the drillstring back into the wellbore to a depth of 650 metres.
  • the presence of the composite drill sub in the drilling sub did not affect normal rig operations of 1) tripping in, 2)rotating the table, 3) power tonging drill pipe together, 4) chaining drill pipe apart or 5) circulating fluid in the wellbore.
  • a compensated neutron-gamma ray tool was lowered into the composite drill sub and a logging run to the surface initiated.
  • the 2.5" thick composite wall section introduces minimal gamma ray attenuation.
  • a 0.8" thick steel wall attenuates gamma ray propagation up to 60%.
  • a 2.5" thick steel wall is essentially opaque to gamma ray propagation measurements.
  • the composite drill sub has lower attenuation properties compared to steel. Neutron porosity measurements improve from within a composite drill sub as the composite fibre physically displaces wellbore fluid thereby minimizing the neutron moderating effect of wellbore fluid.
  • the overall logging speed can be increased and the operating time thereby reduced, indicating a fundamental improvement in the use of a composite drill sub for logging as compared to an all-steel design.

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Abstract

La présente invention concerne des structures de matériaux composites possédant des propriétés d'atténuation réduite de signaux. Cette invention concerne plus particulièrement des composants de train de tiges composites qui possèdent des propriétés électromagnétiques et acoustiques permettant d'utiliser des installations de détection électromagnétique, acoustique et nucléaire afin d'obtenir des données sur un puits de forage et depuis l'intérieur d'une tige de forage. Dans un mode de réalisation particulier, on intègre à un tube composite des inserts d'extrémité qui permettent de l'incorporer dans un train de tiges et d'utiliser ainsi des installations de diagraphie depuis l'intérieur dudit tube composite.
PCT/CA1996/000768 1995-12-05 1996-11-22 Structures de materiaux composites possedant une attenuation de signal reduite WO1997021117A1 (fr)

Priority Applications (4)

Application Number Priority Date Filing Date Title
CA 2237432 CA2237432A1 (fr) 1995-12-05 1996-11-22 Structures de materiaux composites possedant une attenuation de signal reduite
AU75589/96A AU7558996A (en) 1995-12-05 1996-11-22 Composite material structures having reduced signal attenuation
EP96937962A EP0865613A1 (fr) 1995-12-05 1996-11-22 Structures de materiaux composites possedant une attenuation de signal reduite
NO982427A NO982427L (no) 1995-12-05 1998-05-28 Legeme av komposittmateriale med redusert signalsvekking

Applications Claiming Priority (4)

Application Number Priority Date Filing Date Title
US56733795A 1995-12-05 1995-12-05
US08/567,337 1995-12-05
US08/740,665 US5988300A (en) 1995-12-05 1996-10-31 Composite material structures having reduced signal attenuation
US08/740,665 1996-10-31

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Cited By (12)

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GB2337546A (en) * 1998-05-18 1999-11-24 Baker Hughes Inc Drillpipe structures to accomodate downhole testing
WO2000047869A1 (fr) * 1999-02-09 2000-08-17 Baker Hughes Incorporated Procede et dispositif de protection d'un capteur d'une masse-tige
GB2354026A (en) * 1999-09-13 2001-03-14 Schlumberger Holdings Casing joint having a window to allow the transmission of electromagnetic signals to a remote sensing unit
GB2360532A (en) * 1999-08-30 2001-09-26 Schlumberger Holdings System and method for communicating with a downhole tool using electromagnetic telemetry and a fixed downhole receiver
US6710600B1 (en) 1994-08-01 2004-03-23 Baker Hughes Incorporated Drillpipe structures to accommodate downhole testing
US7383883B2 (en) 2005-08-15 2008-06-10 Schlumberger Technology Corporation Apparatus and method to detect a signal associated with a component
DE102007007766A1 (de) * 2007-02-16 2008-08-21 Rayonex Schwingungstechnik Gmbh Bauteil eines Bohrwerkzeugs für das Horizontalbohren, das einen eigenständigen Abschnitt des Bohrwerkzeugs bildet
US7671597B2 (en) 2005-06-14 2010-03-02 Schlumberger Technology Corporation Composite encased tool for subsurface measurements
WO2010022755A1 (fr) * 2008-08-29 2010-03-04 Statoilhydro Asa Ensemble protecteur de tige de forage
US8103443B2 (en) 2003-07-25 2012-01-24 Triangle Software Llc System and method for delivering departure notifications
CN103573259A (zh) * 2012-08-07 2014-02-12 中国石油化工股份有限公司 一种电磁随钻测量系统的偶极天线短节
CN103696755A (zh) * 2013-07-18 2014-04-02 西北工业大学 电磁无线随钻测量用绝缘短节及其制作方法

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US7026813B2 (en) * 2003-09-25 2006-04-11 Schlumberger Technology Corporation Semi-conductive shell for sources and sensors
CN104179490B (zh) * 2014-08-06 2017-02-15 中国石油集团渤海钻探工程有限公司 水平井连通设备井内校核方法
CN107187138B (zh) * 2016-03-15 2021-04-23 中国石油化工股份有限公司 一种井下工具用高强度复合材料及其制备方法
WO2018165256A1 (fr) * 2017-03-07 2018-09-13 Saudi Arabian Oil Company Procédé d'encapsulation d'agents de signalisation destinés à être utilisés en fond de trou
EP3592713A2 (fr) * 2017-03-07 2020-01-15 Saudi Arabian Oil Company Ciment de puits de forage possédant des enveloppes de capsule polymères

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EP0704717A2 (fr) * 1994-08-01 1996-04-03 Baker Hughes Incorporated Procédé et dispositif pour l'interrogation d'un puits

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US4504736A (en) * 1982-06-16 1985-03-12 Halliburton Company Gamma ray spectral tool for borehole use
US4592421A (en) * 1983-09-30 1986-06-03 Bayer Aktiengesellschaft Sucker rods
US4968545A (en) * 1987-11-02 1990-11-06 The Dexter Corporation Composite tube and method of manufacture
US5212495A (en) * 1990-07-25 1993-05-18 Teleco Oilfield Services Inc. Composite shell for protecting an antenna of a formation evaluation tool
US5138313A (en) * 1990-11-15 1992-08-11 Halliburton Company Electrically insulative gap sub assembly for tubular goods
US5132624A (en) * 1990-12-12 1992-07-21 Schlumberger Technology Corporation Method and apparatus for insulating electrical devices in a logging sonde using a fluorinated organic compound
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Cited By (26)

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Publication number Priority date Publication date Assignee Title
US6710600B1 (en) 1994-08-01 2004-03-23 Baker Hughes Incorporated Drillpipe structures to accommodate downhole testing
US6864801B2 (en) 1997-06-02 2005-03-08 Schlumberger Technology Corporation Reservoir monitoring through windowed casing joint
US6426917B1 (en) 1997-06-02 2002-07-30 Schlumberger Technology Corporation Reservoir monitoring through modified casing joint
GB2337546B (en) * 1998-05-18 2000-12-06 Baker Hughes Inc Drillpipe structures to accomodate downhole testing
GB2337546A (en) * 1998-05-18 1999-11-24 Baker Hughes Inc Drillpipe structures to accomodate downhole testing
US6429653B1 (en) 1999-02-09 2002-08-06 Baker Hughes Incorporated Method and apparatus for protecting a sensor in a drill collar
WO2000047869A1 (fr) * 1999-02-09 2000-08-17 Baker Hughes Incorporated Procede et dispositif de protection d'un capteur d'une masse-tige
GB2364084A (en) * 1999-02-09 2002-01-16 Baker Hughes Inc Method and apparatus for protecting a sensor in a drill collar
GB2364084B (en) * 1999-02-09 2003-07-09 Baker Hughes Inc Method and apparatus for protecting a sensor in a drill collar
US6727827B1 (en) 1999-08-30 2004-04-27 Schlumberger Technology Corporation Measurement while drilling electromagnetic telemetry system using a fixed downhole receiver
GB2360532B (en) * 1999-08-30 2002-03-06 Schlumberger Holdings Measurement while drilling electromagnetic telemetry system using a fixed downhole receiver
GB2360532A (en) * 1999-08-30 2001-09-26 Schlumberger Holdings System and method for communicating with a downhole tool using electromagnetic telemetry and a fixed downhole receiver
GB2354026B (en) * 1999-09-13 2002-04-17 Schlumberger Holdings Reservoir monitoring through modified casing joint
GB2354026A (en) * 1999-09-13 2001-03-14 Schlumberger Holdings Casing joint having a window to allow the transmission of electromagnetic signals to a remote sensing unit
US8103443B2 (en) 2003-07-25 2012-01-24 Triangle Software Llc System and method for delivering departure notifications
US7671597B2 (en) 2005-06-14 2010-03-02 Schlumberger Technology Corporation Composite encased tool for subsurface measurements
US7383883B2 (en) 2005-08-15 2008-06-10 Schlumberger Technology Corporation Apparatus and method to detect a signal associated with a component
DE102007007766A1 (de) * 2007-02-16 2008-08-21 Rayonex Schwingungstechnik Gmbh Bauteil eines Bohrwerkzeugs für das Horizontalbohren, das einen eigenständigen Abschnitt des Bohrwerkzeugs bildet
GB2474819A (en) * 2008-08-29 2011-04-27 Statoil Petroleum As Drill pipe protector assembly
WO2010022755A1 (fr) * 2008-08-29 2010-03-04 Statoilhydro Asa Ensemble protecteur de tige de forage
GB2474819B (en) * 2008-08-29 2012-08-15 Statoil Petroleum As Drill pipe protector assembly
US8905161B2 (en) 2008-08-29 2014-12-09 Statoil Petroleum As Drill pipe protector assembly
US9617801B2 (en) 2008-08-29 2017-04-11 Statoil Petroleum As Drill pipe protector assembly
CN103573259A (zh) * 2012-08-07 2014-02-12 中国石油化工股份有限公司 一种电磁随钻测量系统的偶极天线短节
CN103573259B (zh) * 2012-08-07 2016-01-13 中国石油化工股份有限公司 一种电磁随钻测量系统的偶极天线短节
CN103696755A (zh) * 2013-07-18 2014-04-02 西北工业大学 电磁无线随钻测量用绝缘短节及其制作方法

Also Published As

Publication number Publication date
MX9804443A (es) 1998-12-31
AU7558996A (en) 1997-06-27
NO982427L (no) 1998-07-31
CN1203671A (zh) 1998-12-30
EP0865613A1 (fr) 1998-09-23
NO982427D0 (no) 1998-05-28

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