JP2022538699A - Guidance method for multilateral directional drilling - Google Patents

Abstract

A guidance method for guiding drilling of a well while reducing trajectory drift. Each drilled well incorporates signaling devices that are used together or in a selected order to guide the drilling of additional wells. With the gradual addition of signaling devices, spacing, positioning and coupling of wells, especially multilateral wells, are centralized and precise.

Description

The present invention relates to a method for guiding, positioning and spacing multiple wellboreholes in various environments such as high temperature, irregular formation geology, and more particularly the present invention relates to multilateral drilling operations. It relates to an efficient method for effectively controlling trajectory drift in .

It is clear that precision is required in drilling. The operation is very expensive, and the complexity or improper alignment, spacing, and coupling of wells can exacerbate capital expenditure costs to prohibitive levels. Therefore, over the decades, the prior art has evolved to promulgate advanced solutions. Although many of the solutions have been embodied in the petroleum industry as applied to SAGD operations for well combinations, the technology, beyond well combinations, is particularly beneficial in the geothermal industry. The usefulness of certain multilateral drilling accuracy has not been addressed. Examples of relatively modern developments are presented in the following paragraphs.

Clark et al., in U.S. Pat. No. 6,201,501, published Oct. 15, 2009, describe a method for drilling multilateral wellbore by drilling and casing a main wellbore in which a multilateral bifurcation is installed. teaching. The first lateral wellbore from the multilateral bifurcation is drilled and cased. Subsequently, a second lateral wellbore is drilled from the multilateral bifurcation using magnetic ranging during drilling so as to have a controlled relationship to the first lateral wellbore. This methodology is focused on the petroleum industry and therefore does not provide further details regarding the large number of lateral wells. Trajectory deviations are not explicitly addressed.

In US Patent Application Publication No. 2018/0111003, published Nov. 1, 2018, Donderici et al. is doing. As such, it is used to improve the interpretation of measurements from the second well. The methods are instructed to use a relative approach. As such, the correct location of each wellbore may not be accurately identified, but the relative location of the wellbore can be accurately identified. This has resulted in better positioning of the well combinations.

In US Pat. No. 6,200,003, published Sep. 22, 2016, Donderici et al. disclose a method and system for magnetic ranging and geosteering. In this disclosure, paragraph [0019] indicates the following.
“As described herein, the present disclosure describes exemplary ranging methods and systems that utilize magnetic dipole beacons to guide one wellbore toward another wellbore. In a generalized embodiment, the beacon directs a low frequency magnetic field into the formation from a first wellbore, and the low frequency magnetic field is directed to one or more magnetic fields in a second wellbore. Sensed by dipoles (acting as receivers) The beacon and/or receiving dipoles are magnetic dipoles, and in certain embodiments one or both may be triaxial magnetic dipoles. In either embodiment, the magnetic field emitted by the beacon forms a natural path of access to the first wellbore, and as a result, the second wellbore can be steered to align with the direction of the magnetic field. , which will automatically establish the ideal approach towards the first wellbore.”

The system is clearly useful for two well systems to maintain consistency during drilling.

In a further development, Yao et al., in US Pat. The configuration incorporates numerous sensor nodes that convey data that is ultimately used in mathematical transformations to ensure accuracy in downhole drilling.

US Patent Application Publication No. 2004/0020003, published Nov. 7, 2013, discloses a system and method for optimal spacing of horizontal wellbores. Methods and systems employ magnetic dipole beacons to direct one wellbore toward another wellbore. One embodiment includes a beacon for directing a low frequency magnetic field from the first wellbore into the formation. These magnetic fields are then sensed by one or more dipoles in the second wellbore. The beacons and/or receiving dipoles are magnetic dipoles, and this disclosure states that in some embodiments one or both may be triaxial magnetic dipoles. The magnetic field emitted by the beacon forms a natural path of access to the first wellbore. Consequently, the second wellbore can be steered to align with the magnetic field direction, which establishes a favorable approach towards the first wellbore.

Rodney, in U.S. Patent No. 6,200,400, published Feb. 28, 2017, teaches ranging while a drilling system having a drill string with a magnetic source induces a magnetic moment in the casing string. The magnetic source includes at least one dipole with a non-perpendicular tilt to the longitudinal axis of the drill string. A triaxial magnetometer is provided for detecting a magnetic field from an induced magnetic moment and has a sensor that provides a signal indicative of the rotational orientation of the magnetic source. A processing unit determines the relative distance and orientation of the casing string from measurements by the sensors and the triaxial magnetometer.

In view of the prior art, directed multilateral wellbore directionality in which wellborees are positioned in a predetermined manner with predetermined spacing, drilling from one or more directions without deleterious trajectory drift It is desirable to facilitate drilling with

The present invention, in embodiments, achieves these properties, among others, in methods and configurations that have applicability in the geothermal industry as well as the oil and gas industry.

U.S. Patent Application Publication No. 2009/0255661 U.S. Patent Application Publication No. 2018/0313203 U.S. Patent Application Publication No. 2016/0273345 U.S. Patent Application Publication No. 2017/0122099 International Application No. PCT/US2012/036538 U.S. Patent No. 9,581,718

It is an object of one embodiment of the present invention to provide a methodology for more efficiently locating, connecting and spacing wellbores in subterranean formations.

A further object of an embodiment of the present invention is a method for drilling into a geological formation in a predetermined configuration, comprising:
drilling a well having an entrance well and an exit well in the formation;
drilling with signaling for communication between the inlet wellbore and the outlet wellbore to form a continuous wellbore having an interconnecting wellbore portion between the inlet wellbore and the outlet wellbore; a step, wherein the interconnecting wellbore segments have predetermined geometries with respect to the entrance wellbore and the exit wellbore within the formation;
an inlet wellbore, an exit wellbore, and an interconnecting wellbore segment for drilling a second interconnecting wellbore segment operably connected to the continuous wellbore in a predetermined geometric configuration within the formation; and signaling for communication from at least one of.

Interconnecting well sections may be conditioned to further enhance the heat recovery effectiveness of the process.

Conditioning is continuous drilling that introduces a sealant compound to at least seal interconnecting wellbore portions such that casings, liners, or other heat transfer degrading elements are avoided. Can be effected by at least one of a combination of discontinuous, during, after, and in sequence.

More specifically, conditioning may include introducing at least one composition not derived from the formation, unit operations, and combinations thereof.

To increase the effectiveness of the method, the conditioning operation may be dynamically altered in response to signaling data from at least one of the entry wellbore drilling operation and the exit wellbore drilling operation.

Depending on the particular circumstances, unit operations may include controlling the temperature of the drilling fluid, precooling the rock face in the formation to be drilled, cooling the drilling rig, It is possible to change the pore spacing of the pores.

Modification of the pore space includes activating the pore space for subsequent processing to render the pore space impervious to formation fluid ingress into the interconnect or discharge of working fluid into the formation; There can be sealing of the hole space during drilling in a continuous operation, sealing of the hole space during drilling in a discontinuous operation, and combinations thereof.

Operational conditioning changes may be based on signaling data from signaling between the entry wellbore and the exit wellbore.

A further object of an embodiment of the present invention is a method for drilling into a geological formation in a predetermined configuration, comprising:
drilling a well having an entrance well and an exit well in the formation;
drilling a partial wellbore proximally or distally from at least one of the entrance wellbore and the exit wellbore to signal for communication with at least one of the entrance wellbore and the exit wellbore;
drilling an interconnecting well section that serially connects the inlet well and the outlet well with signaling for communication with at least one of the inlet well, the outlet well, and the partial well; The object is to provide a method comprising steps and .

For convenience, the inlet and outlet wells may be co-located for footprint reduction. If the geological formation has irregular and inconsistent temperature gradients, it may be necessary to position the inlet and outlet wells at spaced apart locations.

The partial wellbore is proximate from at least one of the entrance wellbore and the exit wellbore for signaling communication with at least one of the entrance wellbore, the exit wellbore, and the interconnecting wellbore. can be proximal or distal. This allows an even greater degree of wellbore formation and positioning despite the possibility of inconsistent, discontinuous, or completely different temperature gradients.

A series of wells and a second series of interconnected wells formed for further signal transmission to guide drilling of further interconnected well segments and series of wells in operative connection in a predetermined configuration within the formation. It can be implemented from parts. In this manner, a network of wells can be formed with precision to capture a wide area of heat-producing formations.

Having thus generally described the invention, reference is now made to the accompanying drawings.

Industrial Applicability The present invention has applicability in drilling technology.

Figure 2 is a flow diagram showing the general steps of the method; 1 is a schematic diagram of a multilateral wellbore arrangement; FIG. FIG. 3 is a plan view of FIG. 2; FIG. 5 is a diagram of a variation of the wellbore arrangement according to a further embodiment; FIG. 10 is another variation of the wellbore arrangement according to a further embodiment; FIG. 10 is a further variation of wellbore arrangements of multilateral arrangements; FIG. 10 is another variation of wellbore arrangement in a multilateral arrangement; FIG. 10 is a still further variation of the wellbore arrangement of the multilateral arrangement; FIG. 5 is a diagram of another embodiment according to the invention with a multilateral wellbore having a significantly reduced footprint; 1 is a schematic diagram of a closed loop system applicable to geothermal embodiments; FIG. Fig. 4 is a schematic diagram of a further embodiment of the invention;

Like numbers used in the figures indicate like elements.

Referring now to Figure 1, a general flow diagram of the overall steps in the method is shown.

FIG. 2 is a schematic diagram of one embodiment of the present invention, indicated generally by numeral 10. As shown in FIG. In the example, the U-shaped wellbore is shown as a horizontal wellbore interconnecting wells 12 and 14 with a pair of spaced apart generally vertical wellbore 12 (entrance) and 14 (exit). an interconnecting well section 16; This well may be pre-existing from an unused well, ie, a SAGD deployment, or may be newly drilled. The technology further discussed herein is particularly useful in repurposing unused oil wells, and in the forthcoming disclosure many aspects of the disclosed technology will be used for geothermal It will become apparent that it can be easily added to or substituted into existing oil and gas environments as easily as it is positioned in industry.

In the example shown, a plurality of dependent laterally horizontal wells 18, 20, 22, and 24 extend from branches 26 and 28 and are shown in the example as horizontal wells. In this approach all wells are commonly connected to their respective vertical wells 12 or 14 . Signal devices may be positioned along the vertical wells 12, 14 and the interconnecting wells 16 in the pre-existing U-shaped wellbore situation. These signaling devices are shown and depicted schematically by reference numeral 30 . Suitable signaling devices may be selected from the device solutions known in the art and may comprise receivers, transmitters, transceivers among others. For purposes of examples of suitable equipment, references to Baker Hughes, Scientific Drilling, Halliburton, etc. may be made for reference.

The system measures one of the following: drilling rate, spacing between wells, integrity of well-to-furnace connections, bit wear, temperature, and fluid flow rate in the drilled wells. It can be modified or selected so that at least one can be monitored.

The field is technically mature, so a detailed description is not necessary.

In situations where there is no pre-existing U-shaped well, the well can be drilled in any configuration as the first foundation well, and the signaling device left permanently in place or retrieved over time. placed into the wellbore at appropriate times in the process.

Once positioned, in one embodiment, it provides a “master” for signal communication with the directional drilling of the second lateral wellbore 20 . A drilling arrangement (not shown) is equipped with capacity to receive the guidance signal as a slave from signaling device 30, and a further signaling device 32 can be left along the path of horizontal wellbore 20. Additional communications with drilling arrangements and signaling devices 30, 32 are also possible.

Having established the second wellbore 20 with the signaling device 32 , it can act as a master for guidance signaling for the third lateral wellbore 22 . The previously mentioned drilling arrangement functions in a similar manner to this drilling procedure. Additional signaling devices 34 are positioned along the path of wellbore 22 . With this arrangement, the second wellbore benefits from the guidance of signaling devices 30 and 32, either jointly or independently, in any consecutive or non-consecutive order. As will be appreciated, this has the effect of significantly reducing trajectory drift during drilling due to the position and location of multiple sensors.

With respect to the third lateral wellbore 22, the drilling arrangement has the capacity to receive guidance signals as slaves from signaling devices 30, 32, and 34, and a further signaling device 36 along the path of the horizontal wellbore 22. can be left As such, this wellbore will benefit from the guidance of devices 30, 32, and 34, as in the previous example.

Finally, in the context of the example above, a signaling device 38 may be positioned in the fourth lateral wellbore 24 to communicate with devices 30, 32, 34, and 36. FIG.

It is understood that the signaling device progressively reduces the drift for each additional multilateral portion as it becomes cumulative towards the last multilateral wellbore. This allows the use of pre-existing/unused/abandoned wells as the original wells are of lesser importance in a multilateral context. The original "master" situation becomes less important as more lateral wells are added to form a multilateral configuration.

As detailed in the prior art, much of the existing technology in this area of technology focuses on two wells or injection and production well systems that are unique in a SAGD environment. However, the accuracy associated with this technology allows for excellent applications in the field of geothermal technology, and mention of that capability is made here.

Although interconnecting portion 16 is shown as horizontal, the geometry can be at any suitable angle to maximize heat recovery within the formation. To that end, Figure 2 shows another possibility.

3 is a plan view from above of the well arrangement of FIG. 2; FIG.

Referring now to FIG. 4, a variation of the arrangement of wells positioned within the geothermal gradient G, commonly referred to as the "overlap" arrangement, is shown. In this embodiment, each multilateral arrangement 40 in the polymerization has its own inlet wells 12, 12', 12", 12''' and outlet wells 14, 14', 14", 14'''. can have Where feasible, each polymerization 40 may be commonly connected to a single inlet wellbore 12 and a single outlet wellbore 14 . The attraction of the polymerization arrangement is the potential for greater heat recovery in a smaller footprint.

Figure 5 shows a further variant referred to as a "fork" arrangement. In this arrangement, the multilateral wellbore arrangements 40 may be arranged in a spaced coplanar relationship or a spaced parallel planar arrangement. Such an arrangement is suitable when the overall footprint of the system is not an issue. Polymerization of the multilateral wellbore 40 may be performed at any angle to be effective in capturing thermal energy from within a gradient G that is irregular and/or distributed, as shown. It may be tilted.

Turning now to FIG. 6, there is shown an arrangement of multilateral wells 20, 22, 24, 26, and 28 distributed in a radially spaced array relative to the interconnecting wells 16 previously mentioned. It is An example arrangement is coaxial, but other variations will be appreciated by those skilled in the art.

Wells 20, 22, 24, 26, and 28 all have common connections with vertical wells 12 and 14 and branches 26 and 28, not shown, although parts have been removed for clarity. It is understood that you have This radial distribution is of particular value in geothermal environments as more heat can be extracted from a given heat generating volume. Given the directional drilling advance described in this disclosure, such an arrangement is possible and customizable depending on the surrounding environment.

FIG. 7 shows a further variant. In this embodiment, pairs of arrangements shown in Figure 6 are interlaced with similar wells 18', 20', 22', 24', and 26'. The accuracy of the drilling methods established here are easy to combine with each other. This arrangement enhances heat recovery, for example in a geothermal zone, without impacting the footprint. This clearly has capital expenditure benefits and also allows for even greater energy supply capacity within a given area.

FIG. 8 shows another variation of the arrangement from FIG. 7 in which pairs are spaced apart but in thermal contact.

The arrangements depicted in FIGS. 7 and 8 are useful for reducing temperature deviations from heel to toe of the wellbore. As an example, the direction of fluid flow in wells 18, 20, 22, 24, and 26 associated with FIG. Can be against current. In this approach, the heel of one well will be in thermal contact with the toe of another well, ie countercurrent flow.

Referring now to Figure 9, another embodiment of the present invention is shown. In this embodiment, separate multilateral wellbores 40 may be geographically spread out in formation G. This embodiment connects multilateral wellbore such as 42 and 44 back together at termination 46 for connection with exit wellbore 14 . A second set of multilateral wells 42' and 44' may be coplanar or in a parallel plane with multilateral wells 42 and 44 and may also return together at termination 46'. The advantage of this arrangement is that the inlet/outlet footprint 48 is relatively small while the thermal energy recovery capability is very high. This allows for increased productivity on a single site in footprint 48 without requiring large parcels of land.

In all instances, inlets 12 and outlets 14 comprise known ancillary components, namely power generators, energy storage devices, grid connection arrangements, cogeneration systems, among others. This has been omitted from FIGS. 1-9 for clarity. Furthermore, it is understood that the geothermal system will be a closed loop, which means that the inlets, branches, multilateral well intervening generators, etc., and the exit wells are the smallest connecting conduits located at aboveground locations. This means that a continuous circuit will be formed at A general reference to this can be made in connection with FIG.

Auxiliary or intervening equipment is referenced 50 positioned above the ground 52 . The closed loop below ground 52 is exaggerated in the example. Reference numeral 54 represents a terrestrial transceiver capable of communicating with any one or all of devices 30, 32, 34, 26 and 28.

Alternatively, in contrast to the master and slave communication arrangement described, signaling communication may be provided to all devices simultaneously, selectively, sequentially, or in a predetermined order. This will depend on the details of each individual situation.

FIG. 11 shows a variation on the embodiment in which a partially drilled well or borehole 56 may be positioned in close proximity to other multilateral arrangements and provided with signaling/transceiving devices 56. FIG. A signaling/transceiving device 56 can communicate with other such devices 30, 38, 54 to guide the formation of wellbore arrangements as previously described herein. Borehole 56 may be further drilled to integrate with other wellbore as indicated by dashed line 60 . Any number of boreholes 56 may be included to form a more networked wellbore arrangement within the formation.

10 Embodiments of the Invention
12, 12', 12", 12''' inlet wells, vertical wells
14, 14', 14", 14''' exit wells, vertical wells
16 Interconnecting Well Sections
18, 20, 22, 24 lateral wells
26, 28 branch
18, 18', 20, 20', 22, 22', 24, 24', 26, 26', 28 multilateral wells
30, 32, 34, 36, 38 signaling devices
40 Multilateral alignment, polymerization
42, 42', 44, 44' multilateral wells
46, 46' end
48 footprint
50 Auxiliary and intervening devices
52 Ground
54 Ground transceiver
56 Wells, boreholes, signaling/transceiving equipment
G Temperature Gradient, Strata

Claims (20)

A method for drilling in a geological formation in a predetermined configuration, comprising:
drilling a well having an entrance well and an exit well in the formation;
in signal transmission for communication between the inlet wellbore and the outlet wellbore to form a continuous wellbore having an interconnecting wellbore portion between the inlet wellbore and the outlet wellbore; drilling, wherein the interconnecting wellbore segments have predetermined geometries in the formation relative to the entrance wellbore and the exit wellbore;
for drilling a second interconnected well portion operably connected to the continuous wellbore in a predetermined geometric configuration within the formation; signaling for communication from at least one of the interlocking wellbore segments. 2. The method of claim 1, wherein the entrance wellbore and the exit wellbore are co-located. 3. The method of claim 1 or 2, wherein the geological formation has irregular and inconsistent temperature gradients. proximally or from at least one of said inlet wellbore and said outlet wellbore for signaling for communication with at least one of said inlet wellbore, said outlet wellbore, and said interconnecting wellbore portion; 4. The method of any one of claims 1-3, further comprising drilling a partial wellbore distally. from said continuous wellbore and said second interconnected wellbore to guide drilling of further interconnected wellbore and continuous wellbore in a predetermined configuration and in operative connection within said formation; 5. The method of any one of claims 1 to 4, further comprising establishing further signaling for communication. 6. The method of any one of claims 1-5, wherein signaling for communication comprises transmitting and receiving between the wellbore. 7. The method of any one of claims 1-6, wherein the step of signaling for communication is performed simultaneously between the wellbore. 8. A method according to any one of claims 1 to 7, wherein the step of signaling for communication is performed between wells in a predetermined order. The step of drilling is performed independently from separate locations for the entrance wellbore and the exit wellbore for intersection to form the continuous wellbore with the interconnecting wellbore portions. A method according to any one of claims 1 to 8. 3. The method of claim 2, further comprising providing ground signaling devices, underground signaling devices, and combinations thereof proximate individual locations to guide excavation. 11. The method of any one of claims 1-10, wherein the formation is a heat generating formation. 12. The method of any one of claims 1-11, wherein the formation is a geothermal formation. further comprising conditioning at least said interconnecting wellbore segments to facilitate heat recovery by inducing fluid flow through said continuous wellbore without casing or liner material in said interconnecting wellbore segments; 13. A method according to any one of claims 1-12. The conditioning step comprises at least one of a combination of continuous, discontinuous, during, after, and sequence of drilling of at least one of said inlet well, said outlet well, and said interconnect. 14. The method of claim 13, wherein the method is provided by one. dynamically adjusting the condition in response to signaling data from at least one of the entry wellbore drilling operation, the exit wellbore drilling operation, and the interconnecting wellbore segment drilling operation; 14. The method of claim 13, further comprising modifying. A method for drilling in a geological formation in a predetermined configuration, comprising:
drilling a well having an entrance well and an exit well in the formation;
drilling a partial wellbore proximally or distally from at least one of the entrance wellbore and the exit wellbore for signaling communication with the entrance wellbore and/or the exit wellbore; and
an interconnecting well serially connecting said inlet wellbore and said outlet wellbore with signaling for communication with at least one of said inlet wellbore, said outlet wellbore, and said partial wellbore; A method comprising: drilling a well section; 17. The method of claim 16, further comprising forming a second wellbore having an entrance wellbore and an exit wellbore from the partial wellbore. 18. The method of claim 16 or 17, wherein the partial wellbore comprises a plurality of individual spaced wellbore. 19. The method of claim 18, further comprising signaling between a plurality of separate spaced apart wellbores to form a connected continuous wellbore. 20. The method of any one of claims 16-19, wherein signaling comprises transmitting and receiving between wells.

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