WO2017105251A1 - Procédé d'évaluation de l'état d'intégrité d'un bouchon de barrière - Google Patents

Procédé d'évaluation de l'état d'intégrité d'un bouchon de barrière Download PDF

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Publication number
WO2017105251A1
WO2017105251A1 PCT/NO2016/050259 NO2016050259W WO2017105251A1 WO 2017105251 A1 WO2017105251 A1 WO 2017105251A1 NO 2016050259 W NO2016050259 W NO 2016050259W WO 2017105251 A1 WO2017105251 A1 WO 2017105251A1
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WO
WIPO (PCT)
Prior art keywords
plug
pipe string
well
plugging material
communication unit
Prior art date
Application number
PCT/NO2016/050259
Other languages
English (en)
Inventor
Morten Myhre
Arne Gunnar Larsen
Arnold ØSTVOLD
Markus IUELL
Original Assignee
Hydra Systems As
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
Application filed by Hydra Systems As filed Critical Hydra Systems As
Publication of WO2017105251A1 publication Critical patent/WO2017105251A1/fr

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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
    • E21B33/00—Sealing or packing boreholes or wells
    • E21B33/10—Sealing or packing boreholes or wells in the borehole
    • E21B33/13—Methods or devices for cementing, for plugging holes, crevices or the like
    • 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
    • E21B47/005—Monitoring or checking of cementation quality or level
    • 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
    • E21B47/06—Measuring temperature or pressure
    • 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
    • E21B47/14—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 using acoustic waves
    • E21B47/16—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 using acoustic waves through the drill string or casing, e.g. by torsional acoustic waves

Definitions

  • the invention concerns a method of assessing the integrity status of a barrier plug formed within a longitudinal section of a subterranean well.
  • the barrier plug is formed from a fiuidized and curable plugging material, for example cement slurry, and may be used in various types of well plugging operations. Such operations may include temporary or permanent plugging of a well, for example for abandonment thereof.
  • the present method may be used in any type of subterranean well, including petroleum wells, water wells and geothermal wells. As such, the present method is useful for assessing the integrity status of a barrier plug formed in e.g. a production well or an injection well.
  • the background of the invention relates to statutory regulations requiring pressure isolation in subterranean wells, e.g. petroleum wells, in various well situations, including plugging and abandonment of such wells.
  • a pressure-isolating barrier plug must therefore be formed above, along and/or below a permeable zone in a well, as required in the particular well.
  • such a barrier plug spans a complete cross section of the well along a longitudinal section thereof.
  • a longitudinal section includes a tubular pipe string, such as a casing- or liner string
  • the barrier plug must be formed so as to cover both the outside and the inside of the particular pipe string.
  • NORSOK D-010 Similar statutory regulations exist in other countries.
  • the background of the invention aiso relates to typical prior art methods used to verify the integrity of a barrier plug once formed from a fiuidized and curable plugging material, such as cement slurry.
  • Prior art 3 ⁇ 4f g3 ⁇ 4.di Siv3 ⁇ 4? 3 ⁇ 4a3 ⁇ 4es fcfo3 ⁇ 4r3 ⁇ 4sel
  • a pressure-isolating barrier plug formed within an open-hole section of a well, or inside a pipe string already affixed in the well, is typically allowed to set up and cure for a relatively short period of time. This is usually referred to as plug cementing.
  • a drill string or similar is then lowered down to the barrier plug to mechanically tag the plug, after which a given weight is set down on top of the plug to confirm mechanical firmness of the barrier plug.
  • a given fluid overpressure is also exerted on top of the barrier plug for a period of time to observe if the barrier plug is capable of
  • a well may also require a pressure-isolating barrier to be formed in an annulus outside a pipe string in the well.
  • a fluidized and curable plugging material typically cement slurry
  • squeeze cementing a fluidized and curable plugging material
  • the squeezed plugging material is then allowed to set up and cure for a relatively short period of time. Given that mechanical tagging in an annulus is difficult or impossible to perform, the integrity of such an annular barrier may therefore be verified using a positive pressure test, as described above.
  • a fluidized and curable plugging material typically cement slurry
  • the integrity may be verified through use of a negative pressure test, which usually involves reducing the annular fluid pressure above the annular barrier, and then observing the annular pressure for a period of time to observe if there is any pressure build-up above the annular barrier. Also these types of pressure tests provide little or no information about the internal firmness, distribution and quality of the plugging material internally in the annular barrier.
  • barrier plugs formed through use of the novel methods and tools disclosed in these publications are also subject to integrity verification methods using mechanical tag tests and positive pressure tests, as described initially.
  • Cement barrier plugs thus formed are also subject to another barrier verification method.
  • This verification method involves drilling out (i.e. removing) plug cement located inside the pipe string, lowering a suitable logging tool into the pipe string and down to the drilled out section, and then logging this section to acquire indicative data for assessing the integrity status of plug cement located in the annular section outside the pipe string.
  • a logging tool acquires acoustic data from the annular section outside the pipe string.
  • Such acoustic data represent indirect data requiring proper processing and interpretation to obtain a credible representation of the cement quality and
  • this annulus barrier verification method also requires removal (drill out) of the noted plug cement inside the pipe string before such a logging operation can be initiated. Obviously, these operations require valuable and costly rig time to be carried out, which generally is viewed as a significant disadvantage in the industry.
  • An object of the invention is to remedy or reduce at least one of said disadvantages of the prior art, or at least to provide a useful alternative to the prior art.
  • Another object of the invention is to provide a novel method rendering possible to assess the integrity status of a barrier plug formed within a longitudinal section of a subterranean well.
  • Yet another object of the invention is to provide a novel method that is a more efficient and more credible than said prior art methods. Further, it is an object of the invention to disclose various embodiments of this novel method, thereby providing versatility to the method and thus rendering possible to adapt the method as desired or required.
  • the invention concerns a method of assessing the integrity status of a barrier plug formed within a longitudinal section of a subterranean well comprising a wellbore, a pipe string placed within the wellbore, and an annuius located between the wellbore and the pipe string, the method comprising the following combination of steps:
  • said at least one sensor is configured to measure at least one parameter of a fluid
  • said at least one communication unit is configured to receive, from said sensor, measurements of the at least one fluid parameter, and to further transmit signals corresponding to said sensor measurements;
  • the present method is based on acquiring in situ measurements of curing-indicative parameters in said fluidized plugging material, and then transmitting signals corresponding to such measurements to the surface of the well. Such measurements are obtained from the time of placing the fluidized plugging material within said longitudinal section of the well, and then throughout, at least, the initial and predominant part of its curing process therein.
  • any suitable known methods and technical means including various communication methods and operative principles thereof, may be used in the present method.
  • Such communication methods may comprise use of any suitable telemetry means, including mud pulse telemetry (MPT), and associated decoders and programs for decoding and processing signals retrieved at the surface of the well.
  • MPT mud pulse telemetry
  • these methods and technical means may include any suitable amount and configuration of sensors, communication units, pulsers, moving means, such as actuators and motors, pressure-sensitive devices, release mechanisms, timers, power sources, electronic components, signal transmission components, such as transmitters and/or receivers, signal processing programs, fittings, connections, valves, ports, conduits, lines, electric components, wiring, switches, hydraulic components, etc. for acquiring, processing and transmitting such data signals to the surface of the well for further analysis and evaluation.
  • Such known methods and technical means will not be discussed in further detail herein.
  • step (B) dispose, in step (B), said at least one communication unit and said at least one sensor in any suitable manner, and at any suitable location, within the well.
  • step (B) it is also conceivable to separately drop or convey one or more entitles of said communication unit and/or said sensor into the well.
  • step (D) it is within the scope of the present method to deploy, in step (D), one or more sensors in any suitable manner, and using any suitable technical means, into the fluidized plugging material within the pipe string.
  • the fluidized plugging material may comprise cement slurry for formation of a cement barrier plug along said longitudinal section of the well.
  • Other types of fluidized plugging material also exist and may be suitable in the present method.
  • the at least one sensor may be configured to measure at least one of pressure and temperature in the fluidized plugging material. This is especially useful for monitoring and assessing the curing process in cement slurry. Typically, the fluid temperature will increase and the fluid pressure will decrease in cement slurry throughout its curing process.
  • other curing-indicative parameters than those of cement slurry also may be of interest.
  • signals corresponding to in situ measurements of curing- indicative parameters are acquired from each sensor deployed into the fluidized plugging material.
  • One or more communication units then transmit such signals to the surface of the well for retrieval and further analysis with respect to, at least, the curing status of the fluidized plugging material located within said longitudinal section.
  • the analysis is therefore based on direct, quantitative in situ measurements of such curing-indicative parameters, thereby allowing for direct and quantitative assessment of the integrity status of the barrier plug formed in the well.
  • the retrieved data and corresponding assessment are compared to empirical data and results obtained from observing the curing process of the fluidized plugging material in question under simulated and ideal conditions.
  • the method comprises selectively deploying, in step (D), a plurality of sensors into the fluidized plugging material, and along substantially the entire longitudinal section. Naturally, this provides a better overall representation of the curing process along substantially the entire longitudinal section.
  • the method may also comprise the following steps:
  • step (B) a plurality of sensors along an elongate carrier body
  • step (D) selectively deploying, in step (D), the elongate carrier body and its sensors into the fluidized plugging material in the pipe string, and within the longitudinal section.
  • the elongate carrier body may comprise a stiff rod along which the plurality of sensors are distributed.
  • the rod may have any appropriate cross-sectional shape and be formed from any suitable material, for example a lightweight and/or reinforced material, such as aluminium, fiberglass, carbon fibre or similar, or combinations thereof.
  • the term "stiff rod” is not meant to imply that the rod is completely rigid and inflexible. The rod may therefore be somewhat pliable, yet retaining some rigidity, whereby the rod may be classified as a semi-stiff or semi-piiable rod.
  • the elongate carrier body may comprise a flexible line along which the plurality of sensors are distributed.
  • the flexible line may have any appropriate cross-sectional shape and be formed from any suitable material, for example a lightweight and/or reinforced material, such as reinforced rubber or elastomer materials or similar.
  • the plug base may be a column of a viscous fluid positioned within the pipe string for supporting the fluidized plugging material.
  • a viscous fluid is known in the industry and is oftentimes referred to as a "viscous pill”.
  • the plug base may be a mechanical plug anchored to the pipe string for supporting the fluidized plugging material.
  • Such mechanical plugs are known in the industry and are used in various well operations. Any suitable type of mechanical plug may be used in the present method.
  • At least one communication unit may be connected to the mechanical plug
  • step (E) said communication unit is configured to transmit acoustic signals; and wherein the method comprises further transmitting, in step (E), said acoustic signals via the pipe string.
  • said communication unit may be positioned below the mechanical plug.
  • the method may comprise positioning, in step (B), at least one pressure sensor below the mechanical plug;
  • said pressure sensor is configured to measure a first pressure in a first fluid located below the mechanical plug
  • said communication unit is configured to receive, from said pressure sensor, measurements of the first pressure in the first fluid located below the mechanical plug, and to further transmit signals corresponding to said first pressure measurements to the surface of the well ;
  • the method also comprises measuring and further transmitting signals corresponding to said first fluid pressure over an extended period of time surpassing said period of time required to assess said curing status of the fluidized plugging material .
  • the first fluid pressure below the mechanical plug is allowed to be compared, over said extended period of time, with a second fluid pressure in a second fluid located above the f!uidized plugging material in the pipe string, thereby also allowing assessment and potential verification of the integrity of the barrier plug over said extended period of time.
  • At least one communication unit may be connected to an uppermost part of the elongate carrier body
  • step (E) said communication unit is configured to transmit signals in a liquid; and wherein the method comprises further transmitting, in step (E), said signals via a liquid located above the fluidized plugging material and extending to the surface of the well.
  • said communication unit may be buoyant for allowing the communication unit to float.
  • the communication unit may float in the fluidized plugging material or in the liquid located above the fluidized plugging material.
  • said liquid-transferred signals may comprise one of acoustic signals, electromagnetic signals and pulsed pressure signals.
  • said electromagnetic signals may comprise radio frequency signals.
  • the plug base is a mechanical plug anchored to the pipe string for supporting the fluidized plugging material
  • the elongate carrier body is a stiff rod along which the plurality of sensors are distributed;
  • stiff rod is movably connected to the mechanical plug so as to be longitudinally movable relative to the mechanical plug and thus the pipe string;
  • stiff rod is movable from an inoperative position where at least most of the rod is retracted below the mechanical plug, and an operative position where said sensors along the rod are extended into the fluidized plugging material above the mechanical plug;
  • step (D) wherein the method comprises selectively moving, in step (D), the stiff rod from said retracted, inoperative position to said extended, operative position.
  • the rod and the mechanical plug are configured so as to be movable relative to one another, thereby allowing the rod to be moved into the fluidized plugging material at an appropriate point in time.
  • the stiff rod may extend through or alongside the mechanical plug.
  • the rod may also be releasably encased in a protective housing, sleeve or similar.
  • Various methods of deploying the rod into the plugging material are envisaged. Such methods may be based on known methods of deploying downhole equipment into the confinement of a well, including use of e.g. suitable release mechanisms and structural elements thereof, such as spring-loaded mechanisms, which may be released via associated timers, actuators or similar.
  • At least an uppermost part of the stiff rod may be buoyant for facilitating longitudinal moving of the rod into said extended, operative position.
  • an uppermost part of the stiff rod may comprise a connection device selectively connectable to a separate connection line for deployment of the rod in step (D).
  • said uppermost part of the stiff rod may include a connector releasably connectable to a suitable connector attached to a lower end portion of said connection line.
  • connection line may comprise one of a wireline, coiled tubing and a drill string.
  • connection lines are known in the industry and will therefore not be discussed in further detail herein.
  • the plug base is a mechanical plug anchored to the pipe string for supporting the fluidized plugging material ;
  • the elongate carrier body is a flexible line along which the plurality of sensors are distributed;
  • the flexible line is movable from an inoperative position where at least most of the flexible line is releasably compacted at the mechanical plug, and an operative position where said sensors along the flexible line are extended into the fluidized plugging material above the mechanical plug;
  • step (D) wherein the method comprises selectively releasing and moving, in step (D), the free uppermost part of the flexible line from said compacted, inoperative position to said extended, operative position.
  • Reference to a compacted flexible line implies a flexible line that somehow has been reduced in extent from a somewhat extended configuration to a more compact configuration, for example via bundling, folding, coiling or similar.
  • the flexible line and the mechanical plug are configured so as to allow the compacted part of the flexible line to be released from the mechanical plug, thereby allowing the free part of the line to be moved and extended into the fluidized plugging material at an appropriate point in time.
  • the flexible line When in its compacted and inoperative position, the flexible line may be releasably encased within a protective housing, sleeve or similar associated with the mechanical plug.
  • a protective housing, sleeve or similar associated with the mechanical plug Various methods of deploying the compacted line into the plugging material are envisaged. Such methods may be based on known methods of deploying downhole equipment into the confinement of a well, including use of e.g. suitable release mechanisms, such as a spring-loaded mechanism released via an associated timer, actuators and connections therefore. For example, such equipment may be used to release the compacted line from said protective housing, sleeve or similar.
  • At least an uppermost part of the flexible line may be buoyant for facilitating movement of the flexible line into said extended, operative position.
  • an uppermost part of the flexible line may comprise a connection device selectively connectable to a separate connection line for deployment of the flexible line in step (D).
  • said uppermost part of the flexible line may include a connector releasably connectable to a suitable connector attached to a lower end portion of said connection line.
  • connection line may comprise one of a wireline, coiled tubing and a drill string, all of which are known In the industry and will therefore not be discussed in further detail herein.
  • At least one communication unit may be connected to the mechanical plug
  • step (E) said communication unit is configured to transmit acoustic signals; and wherein the method comprises further transmitting, in step (E), said acoustic signals via the pipe string.
  • said communication unit may be positioned below the mechanical plug.
  • the method may comprise positioning, in step (B), at least one pressure sensor below the mechanical plug;
  • said pressure sensor is configured to measure a first pressure in a first fluid located below the mechanical plug
  • said communication unit is configured to receive, from said pressure sensor, measurements of the first pressure in the first fluid located below the mechanical plug, and to further transmit signals corresponding to said first pressure measurements to the surface of the well ;
  • the method also comprises measuring and further transmitting signals corresponding to said first fluid pressure over an extended period of time surpassing said period of time required to assess said curing status of the fluidized plugging material.
  • the first fluid pressure below the mechanical plug is allowed to be compared, over said extended period of time, with a second fluid pressure in a second fluid located above the fluidized plugging material in the pipe string, thereby also allowing assessment and potential verification of the integrity of the barrier plug over said extended period of time.
  • At least one communication unit may be connected to an uppermost part of the elongate carrier body;
  • step (E) said communication unit is configured to transmit signals in a liquid; and wherein the method comprises further transmitting, in step (E), said signals via a liquid located above the fluidized plugging material and extending to the surface of the well.
  • said communication unit may be buoyant for allowing the communication unit to float.
  • said liquid-transferred signals may comprise one of acoustic signals, electromagnetic signals and pulsed pressure signals.
  • said electromagnetic signals may comprise radio frequency signals.
  • the method may also comprise positioning, in step (D), at least one sensor at the bottom of the longitudinal section.
  • step (D) at least one sensor at the bottom of the longitudinal section.
  • step (C) wherein the method comprises placing, in step (C), the fluidized plugging material inside the pipe string along the longitudinal section.
  • a plug only needs to be formed inside the pipe string in order to form a barrier plug spanning a complete cross section of the well along the longitudinal section.
  • step (C) of the method may comprise the following preceding sub-steps: (CI) lowering a perforation tool into the pipe string and down to the longitudinal section where the barrier plug is to be formed; and
  • step (C) the fluidized plugging material is also allowed, In step (C), to enter said annulus between the wellbore and the pipe string so as to form, upon curing, said barrier plug covering both the pipe string and said annulus along the longitudinal section of the well .
  • step (C) of the method may also comprise the following preceding sub-steps:
  • the washing tool may be moved in a suitable manner within the pipe string whilst washing and cleaning, thereby improving the cleaning efficiency thereof.
  • the first washing pass is from top to bottom within the longitudinal section of the well, and then from bottom to top in the next washing pass. This washing procedure may be repeated, as appropriate.
  • step (C5) occurs after sub-steps (CI) and (C2).
  • the directional means referred to in step (C5) may include suitable flow guides, angled fluid outlets, jetting nozzles, etc. for directing said washing fluid out into said annulus.
  • method steps (A) and (B) may be performed substantially simultaneously. This may prove advantageous in the event that, for example, one or both of said at least one communication unit and said at least one sensor is/are connected to a mechanical plug upon deployment thereof into the well.
  • Method steps (C) and (D) may also be performed substantially simultaneously. Such an endeavour may facilitate deployment of the at least one sensor into the fluidized plugging material in the pipe string.
  • Figure 1 shows, in side view, a portion of a subterranean well within which a
  • sealing cement barrier plug is to be formed along a longitudinal section thereof in order to plug and abandon the well;
  • Figure 2 shows, in side view, the well of Figure 1 after having installed a
  • said mechanical plug in a casing string in the well, and below the longitudinal section, said mechanical plug including a communication unit and a stiff rod with sensors shown in an inoperative and retracted position below the mechanical plug;
  • Figure 3 shows, in larger scale, features of a lower end of the stiff rod and the mechanical plug of Figure 2 whilst said stiff rod is in its inoperative and retracted position below the mechanical plug;
  • Figure 4 shows, in side view, the well of Figure 2 after having formed holes in the casing string along the longitudinal section above the mechanical plug, and after having washed and cleaned the inside and the outside of the casing string;
  • Figure 5 shows, in side view, the well of Figure 4 after having placed cement slurry along the longitudinal section above the mechanical plug, and across a complete cross section of the well ;
  • Figure 6 shows, in side view, the well of Figure 5 after having activated said stiff rod with sensors so as to extend the rod into an operative position above the mechanical plug, and after having activated the communication unit so as to transmit signals indicative of cement curing to the surface of the well for assessing the curing status of said cement slurry, and also transmitting signals representing a first fluid pressure below the mechanical plug;
  • Figure 7 shows, in larger scale, features of the mechanical plug of Figure 6 whilst the stiff rod is in its operative and extended position above the mechanical plug;
  • Figure 8 shows, in side view, the well of Figure 7 after curing of said cement slurry into a solid cement barrier plug along the longitudinal section, and whilst still transmitting said signals representing said first fluid pressure below the mechanical plug for assessing the integrity of the cement barrier plug;
  • Figure 9 shows, in larger scale, features of the mechanical plug of Figure 8 whilst still transmitting said signals representing said first fluid pressure below the mechanical plug.
  • FIG 1 shows a subterranean well 2 extending through a surrounding rock formation 4.
  • the well 2 comprises a well bore 6, a casing string 8 placed within the well bore 6, and an annulus 10 located between the wellbore 6 and the casing string 8.
  • the annulus 10 contains remnant fluids and solid particles 12, such as cement residues and particles settled out from drilling mud in the annulus 10.
  • a cement barrier plug 60 ' (see Figures 8 and 9) is to be formed within at least a longitudinal section L of the well 2, and across a complete cross section T thereof, thereby ensuring proper sealing of the well 2.
  • Figures 2 and 3 show the well 2 after having lowered a mechanical plug 14 into the casing string 8 and anchored it to the casing string 8 immediately below the
  • a communication unit 16 is positioned immediately below the mechanical plug 14 and is connected thereto.
  • a pressure pad 18 is embedded in the mechanical plug 14 at an upper side thereof.
  • the pressure pad 18 is connected to the communication unit 16 via an internal communication line 20 in the mechanical plug 14.
  • the purpose of the pressure pad 18 is to selectively activate, by virtue of exerting a given fluid overpressure onto the pressure pad 18, the communication unit 16 and associated means and operations.
  • Said activating fluid overpressure must be sufficiently high so as to avoid unintentional activation of said communication unit 16 and associated means and operations due to preceding manipulation of fluid pressures above the pressure pad 18.
  • Such a pressure manipulation may arise in context of washing and cleaning the casing string 8 and said annulus 10 along the longitudinal section L using a suitable washing tool, as discussed below in relation to Figure 4.
  • an axial opening 22 in the mechanical plug 14 connects the upper side thereof with a larger recessed opening 24 formed in the mechanical plug 14 at a lower side thereof, thereby providing a through opening in the mechanical plug 14.
  • An elongate housing 26 having an open upper part 26a and a closed lower part 26b is provided below the mechanical plug 14. The open upper part 26a is connected to the mechanical plug 14 and is aligned with said larger recessed opening 20 formed therein.
  • An elongate carrier body in the form of a stiff rod 28 is releasably disposed in an inoperative and retracted position within the elongate housing 26.
  • a lower end of the stiff rod 28 is located near said closed lower part 26b of the elongate housing 26, whilst an upper end portion of the stiff rod 28 extends through said openings 22, 24 in the mechanical plug 14 so as to terminate at the upper side thereof, where a releasable cover 30 protects the stiff rod 28 from any contamination and physical damage from above.
  • T e protective cover 30 is torn off and removed (not shown) when selectively deploying the stiff rod 28 into its extended and operative position above the mechanical plug 14.
  • each sensor 32 along the stiff rod 28 is connected, via internal wiring 34 in the rod 28, to a common contact probe 36 mounted at a lower end of the stiff rod 28, as shown in further detail in Figure 3.
  • the contact probe 36 is in moving contact with a contact rail 38 mounted longitudinally along the inside of the elongate housing 26.
  • An upper end of the contact rail 38 is connected to a contact box 40 embedded in the mechanical plug 14 at the lower side thereof.
  • the contact box 40 is also connected to the communication unit 16 via internal wiring 42 in the mechanical plug 14, as shown in further detail in Figure 3.
  • said moving contact arrangement in the elongate housing 26 ensures contact, hence ensures communication, between said sensors 32 and the communication unit 16 for any position of the stiff rod 28 within the elongate housing 26. This continuous contact is important should the stiff rod 28 not become fully deployed upon selective activation thereof.
  • said sensors 32 are configured to measure pressure and temperature of a surrounding fluid, such as cement slurry.
  • said communication unit 16 is configured to receive such measurements from the sensors 32, and then to further transmit, via so-called ping technology, corresponding acoustic signals through the casing string 8 onto the surface (not shown) of the well 2.
  • ping-technology is known in the art and will therefore not be discussed in further detail herein.
  • each such sensor 32 may comprise an assembly of a pressure sensor and a temperature sensor, or it may comprise an individual pressure sensor and an individual temperature sensor located at substantially the same position along the stiff rod 28.
  • individual pressure sensors may be located at positions dissimilar to individual temperature sensors located along the stiff rod 28. It is also to be understood that any suitable or desirable combination and/or positioning of sensors 32 may be used along the stiff rod 28. This also pertains to any other types of sensors that potentially could be provided along such a stiff rod 28 or other suitable type of elongate carrier body.
  • Figures 2 and 3 also show a driving means in the form of an electric motor 44 and a toothed pinion 46 drivingly connected to the motor 44 are embedded in the wall around said axial opening 22 in the mechanical plug 14.
  • the teeth of the pinion 44 protrude some distance into said axial opening 22 so as to engage cooperating teeth on a toothed rack 48 arranged along the stiff rod 28.
  • Activation of the electric motor 44 and associated rotation of the pinion 46 thus drives the toothed rack 48, and thus the stiff rod 28 along which the rack 48 is arranged, in a linear motion out of the elongate housing 26 and into the casing string 8 above the mechanical plug 14.
  • the communication unit 16 includes a movable signal probe 50 for selectively and physically engaging the casing string 8, thereby allowing transmission of said acoustic signals from the communication unit 16 via the casing string 8 onto the surface of the well 2, as described above.
  • the signal probe 50 is shown in a retracted and inoperative position in Figures 2-5.
  • the communication unit 16 also includes various electronic and physical components (not shown), such as a motor or actuator for the signal probe 50, a signal processing program for processing data received from the sensors 32, signal transmission components for transmitting acoustic signals via the signal probe 36 and onwards, and a power source including one or more batteries for powering equipment associated with or connected to the communication unit 16.
  • the communication unit 16 Is also connected to a pressure sensor 52 located below the mechanical plug 14 for measuring a first pressure PI in a first fluid 54 (i.e. a liquid and/or a gas) located in the casing string 8 below the mechanical plug 14.
  • the communication unit 16 is configured to receive and further transmit acoustic signals corresponding to such first pressure measurements in the first fluid 54 located below the mechanical plug 14. Similar to the signals derived from the sensors 32 along the stiff rod 28, the pressure data PI from the pressure sensor 52 are processed in the communication unit 16 and corresponding pressure signals are transmitted to the surface of the well 2 via the casing string 8, and via said ping technology.
  • Pressure data PI may take place for an extended period of time surpassing the period of time required to assess the curing status of a cement barrier plug 60 ' (see Figures 8 and 9) formed from cement slurry 60 (see Figure 5) and located above the mechanical plug 14.
  • Said acquisition allows such pressure data PI to be compared with measurements of a second pressure P2 acquired, over said extended period of time, from a second fluid 56 (i.e. a liquid and/or a gas) located above said cement barrier plug 60 ' .
  • a second fluid 56 i.e. a liquid and/or a gas
  • Figure 4 shows the well 2 after having formed a plurality of holes 58 (or perforations) in the casing string 8 along said longitudinal section L using a suitable perforation tool (not shown), and after having washed and cleaned the casing string 8 and said annulus 10 along the longitudinal section L using a suitable washing tool (not shown). By so doing, said solid particles 12 in the annulus 10 have been removed therefrom, thereby preparing the longitudinal section L for subsequent plugging and sealing thereof.
  • Figure 5 shows the well 2 shortly after having placed cement slurry 60 above the mechanical plug 14, and along the perforated longitudinal section L of the well 2 so as to span the complete cross section T thereof.
  • This process is described in said prior art publications WO 2012/096580 Al, WO 2013/133719 Al, WO 2013/133720 Al and WO 2015/034369 Al and will therefore not be described in further detail herein.
  • the cement slurry 60 forms said cement barrier plug 60 ' in the well 2.
  • Figures 6 and 7 show the well 2 after having activated the communication unit 16 by pressurizing the cement slurry 60 and thus exerting a given overpressure onto the pressure pad 18. Due to its internal configuration, activation of the communication unit 16 also activates said signal probe 50, said electric motor 44 and communication of data from said sensors 32 along the stiff rod 28 as well as pressure data PI from said pressure sensor 52 located below the mechanical plug 14.
  • a suitable moving means such as a motor or actuator (not shown), therefore moves and extends the signal probe 50 into physical contact with the casing string 8, thereby allowing transmission of acoustic signals to the surface via the casing string 8, as described above.
  • the communication unit 16 activates the electric motor 44 so as to rotate said toothed pinion 46 against said toothed rack 48 along the stiff rod 28.
  • This drives the stiff rod 28 and its sensors 32 out of the elongate housing 26 and into its operative and fully extended position within the cement slurry 60 above the mechanical plug 14.
  • the stiff rod 28 covers substantially the entire longitudinal section L, as shown in Figure 6.
  • the curing-indicative pressure and temperature signals retrieved at the surface of the well 2 are then analysed to assess, for each sensor position along the stiff rod 28, the curing status of the cement slurry 60 after said period of time. Typically, the temperature will increase and the fluid pressure will decrease in cement slurry 60 throughout its curing process. This analysis also allows assessment of the integrity status of the cement barrier plug 60 ' thus formed in the well 2.
  • Figures 8 and 9 show the well 2 after a period of time where said cement slurry 60 has cured so as to form a cement barrier plug 60 ' spanning the complete cross section T of said longitudinal section L of the well 2. At this point in time, only signals corresponding to pressure measurements PI from said pressure sensor 52 below the mechanical plug 14 are transmitted for an extended period time to assess and potentially verify the integrity of the cement barrier plug 60 ' , as described above in relation to Figures 2 and 3.
  • the present method does not acquire and transmit any measurements from the fluidized plugging material 60 (e.g. cement slurry) located within said annulus 10 outside the casing string 8.
  • the fluidized plugging material 60 e.g. cement slurry
  • the curing status of the fluidized plugging material 60 at any measuring location within the casing string 8 is representative, or at least indicative, of the curing status thereof at substantially the same level in the annulus 10 outside the casing string 8.
  • obtaining curing-indicative data from a plurality of sensors 32 distributed along the longitudinal section L will provide a more credible overall representation of the curing status (and final curing) of the fluidized plugging material 60 when measured over said period of time in the well 2.
  • support for such assumptions may be obtained from practical tests setting out to simulate various well conditions, curing scenarios, sensor configurations and sensor distributions in and along such a plugging material 60.
  • Such tests may provide empirical data fo making credible assumptions with respect to the curing status of fluidized plugging material 60 along the longitudinal section L, and across the entire cross section T thereof, thereby lending credibility to the present method as a superior method of verifying the integrity of a barrier plug 60 ' thus formed in the well 2.

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  • Engineering & Computer Science (AREA)
  • Physics & Mathematics (AREA)
  • Life Sciences & Earth Sciences (AREA)
  • Mining & Mineral Resources (AREA)
  • Geology (AREA)
  • Environmental & Geological Engineering (AREA)
  • Fluid Mechanics (AREA)
  • General Life Sciences & Earth Sciences (AREA)
  • Geochemistry & Mineralogy (AREA)
  • Geophysics (AREA)
  • Acoustics & Sound (AREA)
  • Remote Sensing (AREA)
  • Quality & Reliability (AREA)
  • Examining Or Testing Airtightness (AREA)
  • Measuring Fluid Pressure (AREA)

Abstract

La présente invention concerne un procédé d'évaluation de l'état d'intégrité d'un bouchon de barrière (60') formé dans un puits (2), comprenant : (A) la disposition d'une base de bouchon (14) à l'intérieur d'un train de tiges (8) dans le puits (2), et au-dessous d'une section longitudinale (L) ; (B) la disposition d'une unité de communication (16) et d'au moins un capteur (32) dans le puits (2), ledit capteur (32) étant configuré pour mesurer au moins un paramètre d'un fluide, et ladite unité de communication (16) étant configurée pour recevoir et émettre des signaux correspondant auxdites mesures de capteur ; (C) le placement d'un matériau de bouchage fluidisé formant un bouchon (60) dans le train de tige (8) au-dessus de la base de bouchon (14), et le long de la section longitudinale (L) ; (D) le déploiement sélectif dudit capteur (32) dans le matériau de bouchage fluidisé (60) dans le train de tiges (8) ; (E) avec ledit capteur (32), la mesure d'au moins un paramètre indicatif de durcissement du matériau de bouchage fluidisé (60) sur une période de temps ; et avec ladite unité de communication (16), la réception de mesures de capteur au cours de ladite période de temps, et en outre la transmission de signaux correspondants à la surface du puits (2) ; (F) l'extractions desdits signaux transmiss à la surface du puits (2) ; et (G) l'analyse des signaux extraits et l'évaluation de l'état de durcissement du matériau de bouchage fluidisé (46) après ladite période de temps.
PCT/NO2016/050259 2015-12-17 2016-12-08 Procédé d'évaluation de l'état d'intégrité d'un bouchon de barrière WO2017105251A1 (fr)

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US11795443B2 (en) 2017-10-16 2023-10-24 The Broad Institute, Inc. Uses of adenosine base editors
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