WO2018172796A1 - Système de télémétrie hybride pour des opérations de forage - Google Patents

Système de télémétrie hybride pour des opérations de forage Download PDF

Info

Publication number
WO2018172796A1
WO2018172796A1 PCT/GB2018/050778 GB2018050778W WO2018172796A1 WO 2018172796 A1 WO2018172796 A1 WO 2018172796A1 GB 2018050778 W GB2018050778 W GB 2018050778W WO 2018172796 A1 WO2018172796 A1 WO 2018172796A1
Authority
WO
WIPO (PCT)
Prior art keywords
drillpipe
installing
wireline
cable according
drill string
Prior art date
Application number
PCT/GB2018/050778
Other languages
English (en)
Inventor
Philip Head
Original Assignee
Enteq Upstream Plc
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 GBGB1704605.3A external-priority patent/GB201704605D0/en
Priority claimed from GBGB1705793.6A external-priority patent/GB201705793D0/en
Application filed by Enteq Upstream Plc filed Critical Enteq Upstream Plc
Priority to CA3057433A priority Critical patent/CA3057433A1/fr
Priority to GB201913573A priority patent/GB2574963A/en
Priority to US16/607,328 priority patent/US20200378204A1/en
Publication of WO2018172796A1 publication Critical patent/WO2018172796A1/fr
Priority to NO20191229A priority patent/NO20191229A1/en

Links

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
    • E21B47/12—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
    • 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
    • E21B17/02—Couplings; joints
    • E21B17/028—Electrical or electro-magnetic connections
    • 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
    • E21B19/00—Handling rods, casings, tubes or the like outside the borehole, e.g. in the derrick; Apparatus for feeding the rods or cables
    • E21B19/16—Connecting or disconnecting pipe couplings or joints
    • 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
    • E21B23/00—Apparatus for displacing, setting, locking, releasing or removing tools, packers or the like in boreholes or wells
    • E21B23/14—Apparatus for displacing, setting, locking, releasing or removing tools, packers or the like in boreholes or wells for displacing a cable or a cable-operated tool, e.g. for logging or perforating operations in deviated wells

Definitions

  • the present invention relates to a telemetry system, in particular, one disposed in a drillpipe.
  • the conventional manner of drilling a borehole comprises lowering a drill bit into the earth, the drill bit being powered, for instance, by the rotation of the drillpipe, or by fluids circulating through the drillpipe and thence back up to the surface through the space between the drillpipe and the borehole.
  • the drillpipe is made up of sections, new sections being added periodically at the top of the drillpipe string to allow the drill bit to be lowered further.
  • Much useful data can be garnered from sensors included in the drillpipe, such as temperature and pressure. To retrieve this information at the surface requires some form of media to transmit it through.
  • Known systems include using pressure waves through the circulating mud, and electromagnetic pulses. Better rates of transfer and less attenuation may be achieved however by using an electrical conducting element.
  • the simplest way of installing a conducting cable, or indeed any line, along the drillpipe string is to wait until drilling has ceased and lower a single length down the drillpipe string. Where it is necessary to take readings from instrumentation means before the drillpipe is completed however, the cable must be lowered into the drillpipe string, only to be withdrawn each time a new drillpipe section is added to the drillpipe string.
  • One known method comprises a drillpipe incorporating conducting elements. The conducting elements of adjoining sections of drillpipe are electrically connected by inductive couplings, Such a system is expensive, and requires signal boosts. Many telemetry systems rely upon a segmented cable running through the drillpipe, cable sections being added in order to allow fresh sections of drillpipe to be added.
  • the object of the present invention is to provide an apparatus and method for disposing reliable telemetric equipment in drillpipes and the like in an efficient manner. According to the present invention, there is provided a system of installing a telemetry cable in a drill string as defined in claim 1.
  • the cable may be prepared offsite, terminated and tested to a required length with a small adjustable length section (up to 40ft) so rapid installation is possible.
  • the upper termination of the cable is in a side pocket of a tool joint, the tool joint can also include sensors such as pressure and temperature.
  • wired drillpipe can then be added, to communicate from the wireline terminating at the tool joint to surface.
  • Preparing the cable offsite, terminated and tested to a required length with a small adjustable length section (up to 40ft) allows rapid installation.
  • the upper termination of the cable may be in a side pocket of a tool joint, the tool joint can also include sensors such as pressure and temperature.
  • a second wireline may be installed from the tool joint to the top of the added driUpipe, the wireline is allowed to form a loop inside the driUpipe, the upper end of the wireline has a one way anchor, a electrical termination and acoustic transmitter/receiver.
  • a line of acoustic transmitters and recievers may be included, which listen and transmit to the acoustic transmitter/receiver of the wireline anchored inside the drill pipe.
  • the wireline acoustic transmitter is fished and anchored to the top of the new drillpipe added, this may be repeated until the wireline can accommodate no new drillpipe.
  • a new sensor sub is installed in the drillpipe and the wireline electrical termination docked into the sensor sub.
  • Figure 1 shows a section side view of a cased drilled hole, with new drillpipe and drilling assembly installed, with a side pocket electrical termination tool joint fitted at the rig floor. Adjacent to the well is a pre- assembled / terminated wireline of approximately a similar length.
  • Figure 2 shows a similar view to figure 1 with the pre- assembled wireline installed inside the drill pipe, the lower wet connector termination connected to its mating connector in the drilling assembly, at the surface is a means of rapidly hanging off a pre-assembled terminated cable.
  • FIG. 3 shows in more detail the surface termination hang of sequence.
  • Figure 4 shows a subsequent step in the surface hang off sequence, the cable termination is lowered and installed into the tool joint side pocket connector, surplus cable is applied to hang from the cable termination and a cable termination block, the hanging weight of the cable is supported by a disposable support line.
  • Figure 5 shows a subsequent step in the hang off sequence to figure 4, while the hanging weight of the cable inside the drillpipe is still supported a sliding support is lowered down the cable and comes to rest on top of the upper electrical termination. It is then locked to the remaining supporting cable inside the drillpipe. The surplus support cable is then cut and removed so that new drillpipe can be added.
  • Figure 6 shows a similar view to figure 5 with a joint of wired drillpipe added. This allows the rig to drill new hole and supply fast data to the rig floor.
  • Figure 7 shows an overview of the hybrid telemetry system, with internal wireline from the drilling assembly to the side pocket tool joint and then wired drillpipe back to surface.
  • Figure 8 shows a schematic of the side pocket tool joint, incorporating a sensor package to measure annulus measurements such as pressure and temperature.
  • Figure 9 shows an alternative embodiment of the hybrid telemetry system shown in figure 7, with two sets of internal wireline being used, one from the drilling assembly to the side pocket tool joint, and then a further section of internal wireline, this being connected to a wired drillpipe back to surface.
  • Figure 10 shows a further embodimeny, with a second wireline installed in a second wet connector of the sensor sub, and the wireline forming a U loop, its upper end has a one way anchor which holds the upper assembly where it is pulled up to by a retrieval mechanism, theupper assembly comprises a electrical termination and an acoustic transmitter / receiver.
  • Figure 11 shows a similar view to figure 10 with the retrieval mechanism removed and a new joint of dillpipe added.
  • Figure 12 shows side view of the well in the embodimeny of figure from surface to total depth, at surface it shows the acoustic transmitter inside the drillpipe talking to a series of acoustic transmitters/recievers inside the riser or BOP stack
  • Figure 13 shoiw a similar view to figure 12 with the drillpipe in a lower position.
  • Figure 14 is a similar view to figure 13, the drillpipe is at its lowest position before a new joint can be added, the retrival mechanism fishes the one way anchor and takes it to the top of the drillpipe.
  • Figure 15 is a similar view to figure 14, the wireline inside the drillpipe can no longer accommodate new drillpipe to be added, so has to be terminated in a sensor sub.
  • Figure 16 is a similar view to figure 15 with a new wireline added and docked into the sensor sub to link all the wirelines to its upper termination.
  • Its upper termination includes the previously mentioned electrical termination, anchor assembly and acoustic transmitter/receiver.
  • Figure 17 is a similar view to figure 16 with a new joint of drillpipe added.
  • Figure 18 is a more detailed side section view of the sensor sub of figure 10, with electical terminations of a lower and upper wireline.
  • FIGS 1 to 7 there is shown a borehole 1, lined by a casing 2 which has been cemented in place, a rig floor is shown as 3.
  • a drilling assembly 4 consisting of a directional drilling system 5, steering and sensor package 6 is lowered into the well on drillpipe 7, when it has reached the bottom of the well 8 a side pocket tool joint 9 is installed into the drillstring, the total length of the drill string would be known to within a +/- 5 to 10 feet.
  • a off-site prepared wireline 10 with upper and lower terminations is lowered into the inside of the drillpipe, its lower end has a wet electrical connector termination 11, this lands and docks into a mating termination on top of the telemetry module of the sensor package 6. At surface, surplus cable has to be accommodated into the drillpipe.
  • the wireline is terminated into a termination block 12 at a known shorter length of the drillpipe.
  • the hanging weight of the wireline is supported from the termination block 12 by a suitable strong cable 13.
  • the wireline 15 is first slacked off, so that it rests in a helical path 15' on the inside of the drillpipe.
  • a flexible lighter gauge Kevlar braided cable 14 continues the wireline 15' signal transmission capability to a upper electrical termination 16.
  • the upper termination can be lowered and docked into an internal side pocket electrical connector 17, the surplus cable 13 is allowed to hang from the docked connector 18 forming a U shape to the termination block 12.
  • a cable clamp and support 19 is lowered down the support cable 13 and locates into the top of the cable termination 16, and locks the two items 16, 19 into the side pocket.
  • the cable clamp 19 locks onto the support cable 13 at 20.
  • the remaining or disposable section of support cable 22 can be removed by cutting at 21.
  • Allowing the surplus cable of the wireline 15' to adopt a helical shape causes the wireline 15' to abut against the inner surface of the drillpipe sections making up the drillstring.
  • the friction of this abutment supports the weight of the wireline, meaning that less strain is placed on the wireline during installation.
  • new drillpipe 23 can be added to drill new hole, the new drillpipe being wired drillpipe having conductors within the drillpipe section walls and electrical connectors at the joints of each drillpipe section, so that a conductive path is established along multiple drillpipe sections. Additionally, these wired drillpipe sections can have sensors within the drillpipe to gather telemetry which is them transmitted through the conductive path. This is well understood equipment and available commercially as Intellipipe(R). In this way, a fast cost effective telemetry path is established from the drilling assembly to surface, but avoiding the cost of using wired drillpipe sections over the entire length of the drillpipe string.
  • Figure 8 shows a side pocket docking port with annular sensor capability.
  • the electrical termination of the wireline goes to an inductive coil 30, which transmits the signal across the tool joint via contactless telemetry to a coil 31 in the upper tool joint.
  • a sensor package 32 could measure annular parameters such as pressure, temperature etc., and these too could be processed and transmitted back to surface, providing vital information of what is happening in the wellbore annulus.
  • the hybrid telemetry system may use more than one section of internal wireline, allowing greater lengths of conventional, non- wired drillpipe section to be used.
  • a first wireline 15' and docked connector 28 is disposed between the drilling assembly and an internal side pocket 27.
  • a clamp connector 30 is then deployed in the same manner as the clamp 20 shown in figure 7.
  • the clamp connector 30 includes a second wireline 25 extending from it, and the clamp connector 30 makes an electric connection with the docked connector 28.
  • Further conventional drillpipe sections can then be added, with the wireline 25 suspended by a support line (not shown) and threaded through new drillpipe sections as they are added in a similar manner to that described in relation to figures 1 to 7.
  • the second wireline 25 is then connected to a docking connector 38 with a clamp 39 in exactly the same manner as described in to figures 1 to 7, the docking connector 38 having an electrical connection to a conductor running through the drillpipe section added above this, such as drillpipe sections of the Intellipipe (R) design.
  • a conductor running through the drillpipe section added above this, such as drillpipe sections of the Intellipipe (R) design.
  • Lengths of conventional drillpipe sections and lengths of wired drillpipe sections can in this way be alternated depending on where the operators what wired drillpipe telemetry, so that the cost of using the wired drillpipe sections is minimised and reliability and speed of installation is increased.
  • the upper termination block of the wireline has been described as docking with a side pocket connector, where a side pocket is usually considered to be a cavity in a drillpipe section communicating with the inner bore of the drillstring, but which does not occlude the inner bore.
  • the drill pipe connector could also secured to the drill pipe in some manner so that the connection of the termination block of the electrical wireline can be made to the connector attached to the drill pipe section (whether as a wired drill pipe section, or in order to continue the drill pipe telemetry connection in a 'daisy chain' manner).
  • the drill pipe connector could for example be secured to the inner surface of the drill pipe, or could comprise a spider that spans the throughbore of the drill pipe section.
  • the acoustic transmitter / reciver 36 is continuously transmitting to an array of acoustic transmitter / recievers 37 either mounted in the riser or the BOP stack.
  • Many joints of drillpipe can be added, because there is an excess of extra wireline 38 forming a U shape inside the drillpipe.
  • the fishing tool again goes inside the drillpipe and fishes the one way anchor 39 to just below the rig floor.
  • a sensor sub 40 and wire termination is added.
  • the sensor sub could measure external pressure and temperature and be useful for both well control and gather other well data.
  • the wireline is in effect daisy chained together in controlled lengths and joined together at each sensor sub using electrical connectors. So a fast cost effective telemetry path is established from the drilling assembly to surface.
  • Figure 18 shows a side pocket docking port with annular sensor capability.
  • the wireline electrical termination 50 of the wireline plugs into a matching electrical connector 51 this goes to a sensor module 52 which converts the sensor signals to a telemetry signal and transmits that onto the wireline.
  • a second connector 53 allows a new wireline 54 to be added to extend the wireline inside the drillpipe and its end termination 55 plugs into the matching terminator 53 in the sensor sub.
  • the sensor package 52 could measure annular parameters such as pressure, temperature etc, and these too could be processed and transmitted back to surface, providing vital information of what is happening in the wellbore annulus.

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  • Engineering & Computer Science (AREA)
  • Geology (AREA)
  • Mining & Mineral Resources (AREA)
  • Life Sciences & Earth Sciences (AREA)
  • Physics & Mathematics (AREA)
  • General Life Sciences & Earth Sciences (AREA)
  • Fluid Mechanics (AREA)
  • Environmental & Geological Engineering (AREA)
  • Geochemistry & Mineralogy (AREA)
  • Geophysics (AREA)
  • Remote Sensing (AREA)
  • Mechanical Engineering (AREA)
  • Earth Drilling (AREA)
  • Arrangements For Transmission Of Measured Signals (AREA)

Abstract

La présente invention concerne un système d'installation d'un câble de télémétrie (15) dans un train de tiges de forage (5), le train de tiges de forage comprenant une pluralité de sections de tuyau de forage, le train de tiges de forage ayant un connecteur électrique de tuyau de forage au fond du train de tiges de forage, un câble électrique pouvant transporter un signal électrique est disposé dans le train de tiges de forage, se terminant par un connecteur électrique de câble inférieur (11) pouvant se raccorder au connecteur électrique de tuyau de forage inférieur, et un bloc de terminaison supérieur.
PCT/GB2018/050778 2017-03-23 2018-03-23 Système de télémétrie hybride pour des opérations de forage WO2018172796A1 (fr)

Priority Applications (4)

Application Number Priority Date Filing Date Title
CA3057433A CA3057433A1 (fr) 2017-03-23 2018-03-23 Systeme de telemetrie hybride pour des operations de forage
GB201913573A GB2574963A (en) 2017-03-23 2018-03-23 Hybrid telemetry system for drilling operations
US16/607,328 US20200378204A1 (en) 2017-03-23 2018-03-23 Hybrid Telemetry System for Drilling Operations
NO20191229A NO20191229A1 (en) 2017-03-23 2019-10-15 Hybrid telemetry system for drilling operations

Applications Claiming Priority (4)

Application Number Priority Date Filing Date Title
GB1704605.3 2017-03-23
GBGB1704605.3A GB201704605D0 (en) 2017-03-23 2017-03-23 Hybrid telemetry system for drilling operations
GB1705793.6 2017-04-11
GBGB1705793.6A GB201705793D0 (en) 2017-04-11 2017-04-11 Daisy chain wireline telemetry system for drilling operations

Publications (1)

Publication Number Publication Date
WO2018172796A1 true WO2018172796A1 (fr) 2018-09-27

Family

ID=62111110

Family Applications (1)

Application Number Title Priority Date Filing Date
PCT/GB2018/050778 WO2018172796A1 (fr) 2017-03-23 2018-03-23 Système de télémétrie hybride pour des opérations de forage

Country Status (5)

Country Link
US (1) US20200378204A1 (fr)
CA (1) CA3057433A1 (fr)
GB (1) GB2574963A (fr)
NO (1) NO20191229A1 (fr)
WO (1) WO2018172796A1 (fr)

Cited By (1)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
GB2584450A (en) * 2019-06-03 2020-12-09 Enteq Upstream Plc Telemetry safety & life of well monitoring system

Citations (3)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US20100328096A1 (en) * 2005-09-16 2010-12-30 Intelliserv, LLC. Wellbore telemetry system and method
WO2012107108A1 (fr) * 2011-02-11 2012-08-16 Statoil Petroleum As Transmission de signaux et d'énergie électrique dans des puits d'hydrocarbures
US20160002984A1 (en) * 2013-03-01 2016-01-07 Halliburton Energy Services, Inc. A wireline connector including an electromagnet and a metal

Patent Citations (3)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US20100328096A1 (en) * 2005-09-16 2010-12-30 Intelliserv, LLC. Wellbore telemetry system and method
WO2012107108A1 (fr) * 2011-02-11 2012-08-16 Statoil Petroleum As Transmission de signaux et d'énergie électrique dans des puits d'hydrocarbures
US20160002984A1 (en) * 2013-03-01 2016-01-07 Halliburton Energy Services, Inc. A wireline connector including an electromagnet and a metal

Cited By (1)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
GB2584450A (en) * 2019-06-03 2020-12-09 Enteq Upstream Plc Telemetry safety & life of well monitoring system

Also Published As

Publication number Publication date
NO20191229A1 (en) 2019-10-15
CA3057433A1 (fr) 2018-09-27
GB2574963A (en) 2019-12-25
GB201913573D0 (en) 2019-11-06
US20200378204A1 (en) 2020-12-03

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