This disclosure relates generally to equipment and techniques used in conjunction with a subterranean well and, in an example described below, more particularly provides perforating systems and flow control for use with well completions.
Perforating systems are designed to form perforations through a well casing or other wellbore lining. The perforations permit fluid communication between an earth formation penetrated by the wellbore and an interior of the casing. In this manner, fluids can be produced from the formation into the casing and then to surface. In other examples, fluids can be injected from the interior of the casing into the formation via the perforations.
It will, therefore, be readily appreciated that improvements are continually needed in the arts of constructing and operating perforating systems, and controlling flow through perforations. Such improvements can be useful in a wide variety of different types of well completions.
Representatively illustrated in
Using the system 10, multiple zones 12a-c of an earth formation 12 penetrated by a wellbore 14 are to be individually perforated and fractured. Although three zones 12a-c are depicted in the drawings and described herein, any number of zones may be completed using the system 10 and method. In addition, although the zones 12a-c in the
In the
The cement 18 could be a Portland cement composition or any other type of seal or sealant for isolating the zones 12a-c from each other in an annulus 20 formed between the wellbore 14 and the casing 16. In other examples, external casing packers, swellable seals or other sealing devices could be used in place of the cement 18. The scope of this disclosure is not limited to use of any particular type of cement, or to use of any cement in the formation 12.
The wellbore 14 is illustrated in the figures as being generally horizontal or highly deviated from vertical. Although the system 10 and method provide certain advantages in situations where a well completion is to be performed in a horizontal or highly deviated wellbore, the wellbore 14 could be generally vertical or otherwise deviated in keeping with the scope of this disclosure.
As depicted in
For example, the perforating assembly 22a could be made up of materials that are friable, frangible, dissolvable, subject to galvanic corrosion, or otherwise dispersible or degradable in a well environment. The disintegration, dispersal, degrading, dissolution, etc., of the perforating assembly 22a may begin at any point in the method, such as, at introduction of the perforating assembly into the well, in response to contact with a particular activating fluid (for example, a fluid having a particular pH level or chemical composition) already present or later introduced into the well or released from a container, in response to shock produced when a perforator 28 of the perforating assembly is fired to form the perforations 24a, in response to exposure to an elevated temperature or pressure, or in response to another event or stimulus (or combination of events and/or stimuli). However, note that it is not necessary for the perforating assembly 22a to break up, disintegrate, dissolve, disperse, degrade or otherwise cease to exist as a distinct structural entity in keeping with the scope of this disclosure.
In the
The perforator 28 in this example comprises an explosive shaped charge-type perforator or perforating gun, in which one or more explosive shaped charges are contained in an outer tubular gun body (see
The firing head 30 in this example functions to detonate the shaped charges in the perforator 28 when desired, for example, by initiating detonation of a detonating cord extending to each of the shaped charges. The firing head 30 may initiate the detonation mechanically, electrically, chemically or in any other manner, or in response to any event, stimulus or condition (or any combination of events, stimuli and/or conditions). The scope of this disclosure is not limited to use of any particular type of firing head.
The control module 32 in this example is used to control when or if the perforator 28 is fired, such as, by controlling when or if the firing head 30 detonates the shaped charges. The control module 32 may cause the firing head 30 to fire the perforator 28 in response to any predetermined number or combination of events, stimuli or conditions, such as, elapse of time, pressure or pattern of pressure variations, flow or pattern of flow variations, temperature, vibration or pattern of vibration changes, acceleration or pattern of acceleration variations, etc. The scope of this disclosure is not limited to any particular number or combination of events, stimuli or conditions that will cause the control module to activate the firing head 30.
The flow restrictor 34 in this example is used to restrict flow through an annulus 36 formed radially between the perforating assembly 22a and the casing 16. As depicted in
In other examples, the flow restrictor 34 could be in the form of a tortuous path, outwardly extending stiff fibers or bristles, or a gauge ring or other enlarged diameter on the perforating assembly 22a. In further examples, the perforating assembly 22a could be dimensioned so that flow through the annulus 36 is significantly restricted, without use of a separate flow restrictor. Thus, the scope of this disclosure is not limited to use of any particular type of flow restrictor, or to use of a flow restrictor at all in the perforating assembly 22a.
Although the perforator 28, firing head 30, control module 32 and flow restrictor 34 are depicted in the drawings as being separate connected-together components of the perforating assembly 22a, in other examples any or all of the perforating assembly components could be integral or combined. For example, the firing head 30 and control module 32 could be a single integrated component, the perforator 28, firing head, control module and flow restrictor 34 could be combined in a single outer housing, etc. Thus, the scope of this disclosure is not limited to any particular structural form of the perforating assembly 22a.
In the
The perforating assembly 22a may be conveyed to a desired location by flowing a corresponding volume of the fluid 38 through the flow passage 26. In a simplified example, the volume of fluid required to displace the perforating assembly 28 a certain distance is given by the formula: V=A×D, in which V is the required volume, A is the cross-sectional area of the flow passage 26, and D is the distance to the desired location.
As those skilled in the art will appreciate, this simplified example does not account for variations in the flow passage 26 cross-sectional area, leakage of the fluid 38 past the flow restrictor 34, etc. Described more fully below is a “calibration” method whereby the volume required to displace the perforating assembly 22a to a desired location along the wellbore 14 can be determined (see
Once it is known what volume of the fluid 38 is required to be flowed through the flow passage 26 to displace the perforating assembly 22a to the desired location, this volume may be measured by use of various techniques or equipment, such as, by counting pump strokes, by use of a flow meter, etc. The scope of this disclosure is not limited to use of any particular technique or equipment for measuring the volume of the fluid 38.
Once the perforating assembly 22a is at the desired location for forming the perforations 24a, the perforator 28 is fired to thereby form the perforations. In one example, the control module 32 may be configured to require the perforating assembly 22a to remain motionless for a predetermined period of time, prior to the perforator 28 being fired. In other examples, the control module 32 could cause the firing head 30 to fire the perforator 28 immediately upon detecting that the perforating assembly 22a is positioned at the desired location, whether or not the perforating assembly is motionless. The scope of this disclosure is not limited to any particular combination or sequence of events, stimuli or conditions that will cause the perforator 28 to be fired at the desired location.
Referring additionally now to
The fracturing fluid may be the same as, or may be pumped concurrently with, the fluid 38 used to displace the perforating assembly 22a through the flow passage 26. Thus, the zone 12a can be fractured immediately after the perforations 24a are formed. In other examples, the fracturing fluid could be different from the fluid 38, or the fractures 40a may not be formed immediately after the perforations 24a are formed (for example, a period of time may elapse after the perforations are formed, e.g., to allow sufficient time for the perforating assembly 22a to dissolve, degrade, be dispersed, etc., prior to the fracturing operation). The scope of this disclosure is not limited to any particular timing, combination or sequence of events associated with forming the perforations 24a and the fractures 40a.
In addition to the actual fracturing of the zone 12a, the fracturing operation may include a variety of different techniques or procedures of the type well known to those skilled in the art. For example, various stages may be pumped as part of the fracturing operation, such as, including pads, gels, breakers, proppant, stimulation fluids, conformance agents, permeability enhancers, etc. The scope of this disclosure is not limited to use of any particular number or combination of fluids, substances or other agents in procedures associated with the fracturing operation.
After or during the fracturing operation (including any associated propping, breaking, stimulating, conformance or other procedures), one or more plugs or diverters 42a is/are used to isolate the zone 12a from pressure in the flow passage 26, so that further fracturing of the zone is prevented. The diverter(s) 42a may plug the perforations 24a during the fracturing operation (e.g., so that flow is diverted from perforations taking more flow to perforations taking less flow), or the diverter(s) may plug the perforations at the conclusion of the fracturing operation. The scope of this disclosure is not limited to any particular timing of the diverter(s) 42a preventing outward flow through any or all of the perforations 24a.
The diverter(s) 42a may be any type of plugging device or substance capable of entirely preventing or substantially restricting flow outward into the zone 12a via the perforations 24a. The diverter(s) 42a could in some examples be discrete plugging devices, such as, frac balls or those plugging devices described more fully in U.S. Pat. Nos. 9,523,267, 9,567,824, 9,567,825, 9,567,826, 9,708,883, 9,816,341, or in U.S. application Ser. Nos. 15/567,779, 15/138,685, 15/138,968, 15/615,136 or 15/609,671. The discrete plugging devices may be dispensed into the flow passage 26 using any of the techniques described more fully in the above-mentioned US patents and applications, or in U.S. application Ser. Nos. 15/745,608, 15/162,334, 15/837,502, 62/588,150 or 62/638,059. The entire disclosures of the above-listed US patents and applications are hereby incorporated herein, for any purpose, by this reference. However, it should be clearly understood that discrete plugging devices and dispensing techniques other than those described in the above-listed patents and application may be used, in keeping with the scope of this disclosure.
The diverter(s) 42a could in some examples be in particulate, gel or other non-discrete form. For example, substances such as sand, calcium carbonate, poly-lactic acid (PLA), ploy-glycolic acid (PGA), polyvinyl alcohol (PVA), anhydrous boron compounds, particulate nylon, etc., may be used. Many such plugging substances are described in the US patents and applications listed above, although other substances may be used in other examples.
The diverter(s) 42a may be dissolvable, dispersible, melt-able, corrodible, or otherwise degradable in the well. The diverter(s) 42a may self-degrade, or a particular activating fluid or other condition or stimulus may be required to cause the diverter(s) to degrade. In some examples, the diverter(s) 42a may comprise a mixture or combination of degradable and non-degradable materials. In other examples, the diverter(s) 42a may not be degradable in the well at all. The scope of this disclosure is not limited to any particular form, composition or degradability of the diverter(s) 42a.
The diverter(s) 42a may enter the perforations 24a and seal against a surface or face of the zone 12a or the fractures 40a. In other examples, the diverter(s) 42a may seal off the perforations 24a at an interior of the casing 16, as depicted in
As depicted in
The perforating assembly 22b may be conveyed or displaced to the desired location in the same manner as described above for the perforating assembly 22a (such as, by flowing a particular volume of the fluid 38 through the flow passage 26), or the perforating assembly 22b could be conveyed or displaced using another technique (such as, using wireline, slickline, coiled tubing, jointed tubing, a downhole tractor, etc.).
The perforating assembly 22b may be conveyed or displaced to the location for forming the perforations 24b after or while the fractures 40a are being formed, or after or while the diverter(s) 42a are being used to prevent flow into the zone 12a. For example, the perforating assembly 22b could be introduced into the well and displaced through the wellbore 14 by flow of the fluid 38 while the fluid is also being used to form the fractures 40a or place the diverter(s) 42a. Thus, the scope of this disclosure is not limited to any particular relative timing between conveyance of the perforating assembly 22b, forming the fractures 40a and placing the diverter(s) 42a.
The zone 12b is fractured after the perforations 24b are formed. To form fractures 40b in the zone 12b (see
After or during the fracturing operation (including any associated propping, breaking, stimulating, conformance or other procedures), one or more plugs or diverters 42b (see
Referring additionally now to
The perforating assembly 22c may be conveyed or displaced to the desired location in the same manner as described above for the perforating assemblies 22a,b, or the perforating assembly 22c could be conveyed or displaced using another technique. The perforating assembly 22c may be conveyed or displaced to the location for forming the perforations 24c after or while the fractures 40b are being formed, or after or while the diverter(s) 42b are being used to prevent flow into the zone 12b.
Referring additionally now to
The diverter(s) 42a,b may dissolve, melt, corrode, disperse or otherwise degrade after the zones 12a-c have been fractured. In some examples, the diverter(s) 42a,b may flow to surface with fluids 44a-c produced from the respective zones 12a-c. The scope of this disclosure is not limited to any particular technique or process for permitting flow between the zones 12a-c and the flow passage 26 after all of the zones have been fractured. Note that, in some examples, the well may be an injection well instead of, or in addition to, a production well, in which case production of the fluids 44a-c may not be an ultimate goal of the well completion.
Referring additionally now to
The perforator 28 in the
The shaped charges 48, detonating cord 50 and detonator 52 can be conventional components of the type well known to those skilled in the art, and so they are not described further herein. However, it should be understood that other mechanisms or techniques (such as, bullet-type perforators, percussive detonators, drills, etc.) may be used to form perforations, without departing from the scope of this disclosure.
The firing head 30 in the
A mechanical or other type of safety mechanism 60 may be used to prevent activation of the switch 54, for example, during transport of the perforating assembly 22 to a wellsite, or immediately prior to deployment of the perforating assembly 22 into a well. In some examples, the fail-safe switch 54 could be a three-way switch that electrically connects electrical leads of the detonator 52 to each other, to thereby preclude an electrical potential from being created across the leads, until the switch is activated by the safety mechanism 60.
Additional switches 55, 57 may be connected in series with the fail-safe switch 54 between the controller-actuated switch 56 and the detonator 52. In the example depicted in
After the fail-safe switch 54 is activated, the switch 56 can be activated by the control module 32 downhole. In this example, the control module 32 comprises a controller 62, a memory 64, a clock or timer 66, a pressure sensor 68, a temperature sensor 70 and an accelerometer or other type of motion sensor 72. An optional collar locator 74 may be included in some examples.
The controller 62 may be a programmable logic controller (PLC), or another type of controller capable of activating the switch 56 in response to a pre-programmed combination of events, stimuli or conditions as sensed, determined or measured using the timer 66, pressure sensor 68, temperature sensor 70, motion sensor 72 and/or collar locator 74. The memory 64 may be used to store the combination of events, stimuli or conditions.
The memory 64 may in some examples be used to store well parameters, such as, casing collar 75 locations, expected downhole temperatures, expected hydrostatic pressures, desired perforating location, etc. In this manner, the perforating assembly 22 can be programmed so that it fires in response to events, stimuli or conditions (or combination thereof) unique to a particular well completion, including unique to a particular zone to be perforated.
In one example, the memory 64 may store instructions that cause the controller 62 to activate the switch 56 only after a certain minimum amount of time has elapsed since the perforating assembly 22 was deployed into the well (as measured by the timer 66), only if a certain level of pressure is detected by the pressure sensor 68, only if a certain level of temperature is detected by the temperature sensor 70, and only if the perforating assembly 22 has remained motionless for a certain period of time (e.g., as detected using the motion sensor 72 and the timer 66).
If the collar locator 74 is included in the control module 32, the controller 62 may in addition only activate the switch 56 if a certain number of casing collars 75 (see
In other examples, different numbers and/or combinations of sensors, memory, controllers, switches, etc., may be used in the control module 32. Thus, the scope of this disclosure is not limited to any particular configuration of the control module 32.
The flow restrictor 34 in the
Although not depicted in
The self-destruct capability can prevent a “live” perforating assembly from being left downhole or retrieved to surface in an unknown or unsafe state. Alternatively, if, for example, the perforating assembly 22 can reliably be dissolved or otherwise degraded downhole, the self-destruct capability may not be used.
Referring additionally now to
Note that the flow restrictor 34 in the
As depicted in
As depicted in
Flow of the fluid 38 can be ceased, to ensure that the perforating assembly 22b remains motionless, and the perforator 28 will eventually fire (e.g., after a certain period of time, and at or above a certain minimum pressure level and temperature level, as described above). In some examples, the perforator 28 may form the perforations 24b as soon as the control module 32 determines that the perforator is at the desired location for forming the perforations, whether or not the perforating assembly 22b is motionless, or in response to a signal transmitted from the surface.
A decreased pressure and/or increased flow rate may be detected by an operator at surface as an indication that the flow restrictor 34 has passed the open perforations 24a. Then, the operator may detect an increased pressure and/or decreased flow rate when the diverter(s) 42a prevent flow into the zone 12a. These or other indications may be used by the operator to confirm the operation's progress and to determine when flow of the fluid 38 should be ceased, so that the perforator 28 is positioned at the desired location for forming the perforations 24b.
The configuration of the perforating assembly 22b and diverter(s) 42a in
Referring additionally now to
In the
Referring additionally now to
In the
As depicted in
The container 78 may be dissolvable, melt-able or otherwise degradable downhole to thereby release the diverters 42 into the portion of the flow passage 26 between the flow restrictor 34 and the remainder of the perforating assembly 22 after deployment into the well. In some examples, the container 78 may be designed to release the diverters 42 in response to firing of the perforator 28 (e.g., due to a mechanical or pressure shock wave caused by the firing), in which case the diverters can engage or otherwise prevent flow through the perforations 24 after the perforator has been fired.
Referring additionally now to
In the
As depicted in
Additional diverter(s) 42b may be deployed into the flow passage 26 for displacement with the perforating assembly 22 by the flow of the fluid 38. The diverter(s) 42b can engage the perforations 24b or otherwise prevent flow out of the perforations after the perforator 28 has been fired.
Referring additionally now to
As depicted in
As depicted in
Referring additionally now to
In the
When the perforator 28 is fired, the shaped charge or other device 80 pierces, opens, breaks, fractures, disperses or otherwise causes the diverter(s) 42 to be released from the container 78. In this example, the container 78 may be made of a friable or frangible material and/or may be configured to conveniently break open in response to firing of the device 80.
Referring additionally now to
In the
Alternatively, the firing of the device 80 could release or break the tether 76, thereby allowing the container 78 with the diverter(s) 42 therein to separate from the remainder of the perforating assembly 22. The diverter(s) 42 could be released from the container 78 in response to dissolution, corrosion, dispersal, melting, breaking or other degrading of the container.
In the
Friction between the drag device arms 84 and the interior surface of the casing 16 imparts a drag force via the tether 76 to the remainder of the perforating assembly 22, thereby ensuring that the perforator 28 will remain “behind” or uphole of the diverter(s) 42 and container 78, as the perforating assembly 22 is displaced through the flow passage 26 by the flow of the fluid 38. In this manner, the diverter(s) 42 will continue downhole to previously formed perforations, rather than engage perforations formed by the perforator 28 to which the container 78 is attached.
Note that the drag device 82 may be used with any of the perforating assemblies 22 and methods described herein, in which the diverter(s) 42, 42a-c are conveyed through the flow passage 26 concurrently with a perforating assembly (for example, see
Referring additionally now to
In the
In other examples, the diverter(s) 42 could be attached to the exterior of the perforating assembly 22 using frangible or friable fasteners, clamps or other attachment devices that break in response to shock produced when the perforator 28 is fired. The scope of this disclosure is not limited to any particular technique for releasing the diverter(s) 42 from the exterior of the perforating assembly 22 downhole.
As depicted in
The diverter(s) 42 may be released from the perforating assembly 22 after the perforating assembly is introduced into the well (e.g., due to contact with an activating fluid or elevated temperature in the well), or in response to firing of the perforator 28.
As depicted in
As depicted in
In other examples, the diverter(s) 42 may be contained between the flow restrictors 34, without being attached, bonded, etc., to the outer housing 46. For example, the “lower” (further downhole) flow restrictor 34 could dissolve or otherwise degrade downhole (for example, in response to contact with an activating fluid in the well) to release the diverter(s) 42 from the perforating assembly 22.
As depicted in
Note that a separate flow restrictor 34 is not depicted for the
Referring additionally now to
However, as will be appreciated by those skilled in the art, multiple casing strings are typically hung from a wellhead facility, so it should be understood that the single casing 16 is depicted in
In the
The perforating assembly 22 may be contained in a tubular housing 106 connected above the flow head 104. The housing 106 and associated connections, valves, etc., may be of the type commonly referred to by those skilled in the art as a “lubricator,” although other types of housings may be used if desired.
The perforating assembly 22 may be deployed into the flow passage 26 by opening the valves 96 between the pump 102 and the wellhead 94, and operating the pump 102 to flow the fluid 38 into the well. Any of the perforating assemblies 22, 22a-c described herein may be deployed using this technique.
If it is desired to deploy diverter(s) 42 with the perforating assembly 22, the diverter(s) may also be contained in the housing 106 with the perforating assembly. Diverter(s) 42 may be positioned above and/or below the perforating assembly 22 in the housing 106.
Diverter(s) 42 may be separately deployed into the well by use of a dispenser 108, for example, connected to the flow head 104. The dispenser 108 may comprise a container 110 for containing the diverter(s) 42 and a valve 98 for selectively permitting the diverter(s) to enter a flow line 112 connected between the pump 100 and the flow head 104. Alternatively, any of the dispensers described in the US patents and applications listed above may be used for the dispenser 108.
The diverter(s) 42 may be deployed into the well by opening the valve 98 and the valves 96 between the pump 100 and the flow head 104, and between the flow head and the wellhead 94, and operating the pump 100 to flow the fluid 38 into the well. The diverter(s) 42 may be deployed from the dispenser 108 before and/or after a perforating assembly 22 is deployed.
It is contemplated that the perforating assembly 22 and the diverters 42 will not necessarily displace through the flow passage 26 with the fluid 38 at a same speed for a given flow rate. This difference in speeds may be used to achieve a desired spacing between the perforating assembly 22 and the diverters 42 in the well (for example, so that the diverters 42 engage previously formed perforations 24 when, or just after, the perforating assembly 22 arrives at a desired location for forming new perforations).
In a simplified example, the following equation may be used to determine a spacing between the diverters 42 and the perforating assembly 22: S=(SD−SPA)×T, in which S is the spacing, SD is the speed of the diverters 42 at a given fluid 38 flow rate, SPA is the speed of the perforating assembly 22 at the given flow rate, and T is the elapsed time. The diverters 42 and perforating assembly 22 may also, or alternatively, be released into the flow passage 26 at different times, in order to achieve a desired spacing between them.
In the
For example, the pressure pulses can be detected by the pressure sensor 68 of the control module 32 (e.g., see
A telemetry control system 120 at the surface installation 92 can be used to control operation of the variable flow restrictor 118. For example, the control system 120 can actuate the variable flow restrictor 118 to send appropriate pressure pulses to the perforating assembly 22 downhole to cause the perforator 28 to fire when a predetermined volume of the fluid 38 has been flowed into the flow passage 26 (such as, a sufficient volume to position the perforator at the desired location for forming the perforations 24), e.g., as determined by a flow meter (not shown) connected to the control system 120. As another example, the control system 120 could actuate the variable flow restrictor 118 to send appropriate pressure pulses to the perforating assembly 22 downhole to cause the perforating assembly to self-destruct (e.g., as described above in relation to the
Note, however, that the scope of this disclosure is not limited to use of any particular form of telemetry for communicating between the surface installation 92 and the perforating assembly 22 downhole. In some examples, the variable flow restrictor 118 could instead be an acoustic telemetry transmitter, and the control module 32 could include an appropriate acoustic telemetry receiver, for communicating between the surface installation 92 and the perforating assembly 22 downhole. The scope of this disclosure is also not limited to use of telemetry between the surface installation 92 and the perforating assembly 22 downhole for any particular purpose.
Referring additionally now to
In the
Eventually, the pig 114 will engage a restriction 116 positioned at a known distance along the flow passage 26. An operator at surface will note a pressure increase and/or a flow rate decrease as an indication that the pig 114 has engaged the restriction 116.
In the
Since the restriction 116 is at a known distance along the flow passage 26, and the volume of the fluid 38 required to displace the pig 114 to the restriction is measured in the
In a simplified example, the following equation may be used: VPA=VPR×(DPA/DPR), in which VPA is the volume to displace the perforating assembly 22 to the desired location, VPR is the volume to displace the pig 114 to the restriction 116, DPA is the distance to the desired location of the perforating assembly, and DPR is the distance to the restriction.
The above equation results from assumptions, including that the flow passage 26 has a consistent cross-sectional area to the restriction 116, and that the perforating assembly 22 and the pig 114 displace the same in response to the flow of the fluid 38. In some circumstances (for example, long horizontal wellbores with long productive intervals), inaccuracies due to these assumptions may be acceptable. To reduce the inaccuracies, differences in the flow passage 26 cross-sectional area can be accounted for, and the pig 114 can be configured to displace the same as the perforating assembly 22 in response to the fluid flow (or the differences between the displacements of the pig and the perforating assembly could be empirically determined and accounted for).
Referring additionally now to
As depicted in
The use of separate, spaced apart pressure sensors 68a,b in the perforating assembly 22 enables detection of a pressure differential between correspondingly spaced apart sections of the flow passage 26. In the
It is contemplated that, as the flow restrictor 34 nears the existing perforations 24a, the pressure as detected by the pressure sensor 68b will decrease, due to flow of the fluid 38 out of the flow passage 26 via the perforations. A further pressure differential variation will be detected by the pressure sensors 68a,b when the flow restrictor 34 passes at least one of the open perforations 24a. In response to a predetermined pressure differential condition or pattern of variation (as detected by the pressure sensors 68a,b) indicating that the flow restrictor 34 is in a certain position relative to the perforations 24a (and, therefore, that the perforator 28 is in a desired location for forming perforations 24b), the controller 62 can cause the perforator to fire and form the perforations 24b as depicted in
As an alternative, or in addition, to use of the pressure sensor 68b with the flow restrictor 34, a noise or acoustic sensor 122 could be included in the flow restrictor (or otherwise spaced apart from the perforator 28). The acoustic sensor 122 can communicate with the controller 62, for example, via the tether 76.
It is contemplated that, as the flow restrictor 34 nears the existing perforations 24a as depicted in
Note that, in the
In this manner, the diverters 42 can be desirably released into the flow passage 26 just prior to the perforator 28 being positioned at the desired location for forming the perforations 24b. The diverters 42 can, thus, engage and prevent flow through the perforations 24a after the zone 12a has been fractured, and before the new perforations 24b are formed. However, in other examples, the diverters 42 could be released from the container 78 by detonating the shaped charge 80 after or when the perforator 28 is positioned at the desired location for forming the perforations 24b.
Alternatively, the diverters 42 could be released from the container 78 in response to firing of the perforator 28. For example, the container 78 could be opened, fractured or dispersed in response to a shock wave or pressure wave caused by the firing of the perforator 28.
Note that the diverters 42 are released into the flow passage 26 “below” or downhole of the perforator 28 and the newly formed perforations 24b. In this manner, the fluid flow 38 used to fracture or otherwise treat the zone 12b will also carry the diverters 42 to the previously formed perforations 24a. The diverters 42 will engage the perforations 24a or otherwise prevent flow of the fluid 38 into the zone 12a and thereby divert the fluid flow to the newly formed perforations 24b and into the zone 12b, in order to fracture or otherwise treat the zone 12b.
Referring additionally now to
As depicted in
As depicted in
The perforator 28 is fired after the perforator is positioned at the desired location for forming the new perforations 24b. The perforator 28 may be fired using any of the methods described herein. For example, the control module 32 may close the switch 56 (see
Simultaneous with firing of the perforator 28, the charge 80 may also be detonated, in order to release the diverters 42 into the flow passage 26. Alternatively, the diverters 42 could be released from the container 78 in response to firing of the perforator 28. For example, the container 78 could be opened, fractured or dispersed in response to a shock wave or pressure wave caused by the firing of the perforator 28.
Note that the diverters 42 are released into the flow passage 26 “below” or downhole of the perforator 28 and the newly formed perforations 24b. In this manner, the fluid flow 38 used to fracture or otherwise treat the zone 12b will also carry the diverters 42 to the previously formed perforations 24a. The diverters 42 will engage the perforations 24a or otherwise prevent flow of the fluid 38 into the zone 12a and thereby divert the fluid flow to the newly formed perforations 24b and into the zone 12b, in order to fracture or otherwise treat the zone 12b.
In other examples, the diverters 42 may be released into the flow passage 26 prior to or after the firing of the perforator 28. Thus, the scope of this disclosure is not limited to any particular sequence of releasing the diverters 42 relative to firing the perforator 28.
In the above examples, the fluid flowed through the flow passage 26 is indicated in the drawings with reference number 38. However, it should be clearly understood that it is not necessary for the fluid 38 depicted in each of the drawings, or in each step of the described methods, to be the exact same fluid. That is, the reference number 38 is used to represent any fluid that may be used to displace a perforating assembly, diverters, etc., through the flow passage 26, or to form the fractures 40 or otherwise treat the formation 12. For example, in a stimulation operation, the fluid 38 could represent various fluids used in corresponding various stages of the operation, including but not limited to pads, fracturing fluids, gels, spacers, acids, permeability modifiers, conformance agents, brine, etc. Thus, the scope of this disclosure is not limited to use of any particular fluid, or to use of the same fluid, in the system 10 and method examples described herein.
It may now be fully appreciated that the above disclosure provides significant advancements to the arts of constructing and operating perforating systems, and controlling flow through perforations. In examples described above, multiple zones can be completed economically, expeditiously and conveniently using unique configurations of the perforating assembly 22 and associated methods. In some examples, a previously perforated zone 12a may be treated (e.g., fractured, acidized or otherwise stimulated) while a perforating assembly 22 is being displaced by flow of the treatment fluid 38 through the passage 26, and while diverters 42 used to prevent flow into the zone 12a are also being displaced (e.g., with, “ahead of” or “behind” the perforating assembly) by the fluid flow.
The present disclosure provides to the art a well completion system 10. In one example, the well completion system 10 can include fluid 38 flow through a flow passage 26 of a casing 16 having first perforations 24a formed therein, and one or more first diverters 42a deployed into the flow passage 26 downhole of a perforating assembly 22. The one or more first diverters 42a and the perforating assembly 22 are concurrently displaced through the flow passage 26 by the fluid 38 flow.
In any of the well completion system 10 examples described herein, one or more second diverters 42b may be deployed into the flow passage 26 uphole of the perforating assembly 22, so that the second diverters 42b and the perforating assembly 22 may be concurrently displaced by the fluid 38 flow through the flow passage 26.
In any of the well completion system 10 examples described herein, the first diverters 42a may block the fluid 38 flow through the first perforations 24a.
In any of the well completion system 10 examples described herein, the perforating assembly 22 may be configured to degrade after the perforating assembly 22 forms second perforations 24b through the casing 16.
In any of the well completion system 10 examples described herein, one or more second diverters 42b may be deployed into the flow passage 26 uphole of the perforating assembly 22, and the second diverters 42b may block flow through the second perforations 24b.
In any of the well completion system 10 examples described herein, first fractures 40a may be formed into an earth formation 12 by the fluid 38 flow through the first perforations 24a concurrently with the perforating assembly 22 and the first diverters 42a being displaced through the flow passage 26 by the fluid 38 flow.
In any of the well completion system 10 examples described herein, the first diverters 42a may prevent the fluid 38 flow outward through the first perforations 24a after the first fractures 40a are formed, and the fluid 38 flow may be thereby diverted to flow outward through second perforations 24b formed by the perforator 28.
In any of the well completion system 10 examples described herein, second fractures 40b may be formed by the fluid 38 flow outward through the second perforations 24b.
In any of the well completion system 10 examples described herein, the first diverters 42a may be contained in a container 78, and the first diverters 42a may be released from the container 78 downhole prior to, simultaneously with or after second perforations 24b are formed through the casing 16 by the perforator 28.
In any of the well completion system 10 examples described herein, the perforating assembly 22 may include a flow restrictor 34 that restricts flow through an annulus 36 formed between the perforating assembly 22 and the casing 16.
In any of the well completion system 10 examples described herein, the perforating assembly 22 may be displaced by the fluid 38 flow to a desired location along the flow passage 26, and a perforator 28 of the perforating assembly 22 may fire only if the perforating assembly 22 remains motionless at the desired location for a predetermined period of time.
In any of the well completion system 10 examples described herein, the perforating assembly 22 may include a collar locator 74, and a perforator 28 of the perforating assembly 22 may fire only if the collar locator 74 detects a predetermined number of casing collars 75.
In any of the well completion system 10 examples described herein, the perforating assembly 22 may include a collar locator 74, and a perforator 28 of the perforating assembly 22 may fire only if an output of the collar locator 74 indicates that the perforating assembly 22 has remained motionless at the desired location for a predetermined period of time.
In any of the well completion system 10 examples described herein, the first diverters 42a may be retained between a flow restrictor 34 and a perforator 28 of the perforating assembly 22.
In any of the well completion system 10 examples described herein, the first diverters 42a may be contained in a container 78 between the flow restrictor 34 and a perforator 28 of the perforating assembly 22.
In any of the well completion system 10 examples described herein, the first diverters 42a may be contained in a container 78 that is configured to degrade downhole and release the first diverters 42a from the container 78.
In any of the well completion system 10 examples described herein, a flow restrictor 34 may be connected to the perforating assembly 22 by a tether 76.
In any of the well completion system 10 examples described herein, the first diverters 42a may be releasably attached to the tether 76.
In any of the well completion system 10 examples described herein, the first diverters 42a may be released from the tether 76 downhole.
In any of the well completion system 10 examples described herein, the perforating assembly 22 may include a drag device 82 that frictionally engages an interior surface of the casing 16 as the perforating assembly 22 displaces through the flow passage 26.
In any of the well completion system 10 examples described herein, the perforating assembly 22 may include at least one sensor 68a,b, 122 that detects the fluid 38 flow out of the first perforations 24a at a location longitudinally spaced apart along the flow passage 26 from a perforator 28 of the perforating assembly 22.
In any of the well completion system 10 examples described herein, the at least one sensor may comprise an acoustic sensor 122.
In any of the well completion system 10 examples described herein, the at least one sensor may comprise first and second pressure sensors 68a,b longitudinally spaced apart along the flow passage 26.
In any of the well completion system 10 examples described herein, the perforator 28 may be positioned at a desired location for forming second perforations 24b when the at least one sensor 68a,b, 122 detects the fluid 38 flow out of the first perforations 24a.
In any of the well completion system 10 examples described herein, the well completion system 10 may include a telemetry control system 120 that sends a signal to the perforating assembly 22 downhole.
In any of the well completion system 10 examples described herein, the signal may comprise a pressure pulse signal.
In any of the well completion system 10 examples described herein, a perforator 28 of the perforating assembly 22 may fire in response to receipt of the signal by a control module 32 of the perforating assembly 22.
A well completion method is also provided to the art by the present disclosure. In one example, the method can include the steps of: flowing fluid 38 through a flow passage 26 of a casing 16 lining a wellbore 14; deploying one or more diverters 42 and a perforating assembly 22 into the flow passage 26; displacing the diverters 42 and the perforating assembly 22 together through the flow passage 26 by the fluid 38 flow; and ceasing the fluid 38 flow, thereby placing a perforator 28 of the perforating assembly 22 at a desired location for forming new perforations 24b through the casing 16.
In any of the well completion method examples described herein, the deploying step may comprise deploying the diverters 42 into the flow passage 26 prior to deploying the perforating assembly 22 into the flow passage 26, so that the diverters 42 precede the perforating assembly 22 through the flow passage 26.
In any of the well completion method examples described herein, the deploying step may comprise deploying the diverters 42 into the flow passage 26 after deploying the perforating assembly 22 into the flow passage 26, so that the diverters 42 follow the perforating assembly 22 through the flow passage 26.
In any of the well completion method examples described herein, the diverters 42 may block the fluid flow through the new perforations 24b.
In any of the well completion method examples described herein, the ceasing step may comprise the diverters 42 blocking the fluid 38 flow through the new perforations 24b.
In any of the well completion method examples described herein, the method may include the perforating assembly 22 degrading downhole after the perforating assembly 22 forms the new perforations 24b through the casing 16.
In any of the well completion method examples described herein, the method may include forming first fractures 40a into an earth formation 12 by the fluid 38 flow, the first fractures 40a forming concurrently with the displacing of the perforating assembly 22 and the diverters 42 through the flow passage 26 by the fluid 38 flow.
In any of the well completion method examples described herein, the diverters 42 may prevent the fluid 38 flow outward through existing perforations 24a after the first fractures 40a are formed, and the fluid 38 flow may be thereby diverted to flow outward through the new perforations 24b formed by the perforator 28.
In any of the well completion method examples described herein, second fractures 40b may be formed by the fluid 38 flow outward through the new perforations 24b.
In any of the well completion method examples described herein, the diverters 42 may be contained in a container 78, and the diverters 42 may be released from the container 78 downhole prior to, simultaneously with or after the new perforations 24b are formed through the casing 16 by the perforator 28.
In any of the well completion method examples described herein, the flowing step may comprise restricting the fluid 38 flow through an annulus 36 formed between the perforating assembly 22 and the casing 16.
In any of the well completion method examples described herein, the method may include firing the perforator 28 in response to the perforating assembly 22 remaining motionless at the desired location for a predetermined period of time.
In any of the well completion method examples described herein, the perforating assembly 22 may include a collar locator 74, and may include firing the perforator 28 in response to the collar locator 74 detecting a predetermined number of casing collars 75.
In any of the well completion method examples described herein, the perforating assembly 22 may include a collar locator 74, and may include firing the perforator 28 only if an output of the collar locator 74 indicates that the perforating assembly 22 has remained motionless at the desired location for a predetermined period of time.
In any of the well completion method examples described herein, the method may include retaining the diverters 42 between a flow restrictor 34 and the perforator 28.
In any of the well completion method examples described herein, the method may include containing the diverters 42 in a container 78 between the flow restrictor 34 and the perforating assembly 22.
In any of the well completion method examples described herein, the method may include containing the diverters 42 in a container 78, and degrading the container 78 downhole, thereby releasing the diverters 42 from the container 78.
In any of the well completion method examples described herein, the method may include connecting a flow restrictor 34 to a remainder of the perforating assembly 22 by a tether 76.
In any of the well completion method examples described herein, the method may include releasably attaching the diverters 42 to the tether 76.
In any of the well completion method examples described herein, the method may include releasing the diverters 42 from the tether 76 downhole.
In any of the well completion method examples described herein, the perforating assembly 22 may include a drag device 82, and the displacing step may comprise the drag device 82 frictionally engaging an interior surface of the casing 16 as the perforating assembly 22 displaces through the flow passage 26.
In any of the well completion method examples described herein, the perforating assembly 22 may include at least one sensor 68a,b, 122, and the method may include the at least one sensor 68a,b, 122 detecting the fluid 38 flow out of existing perforations 24a at a location longitudinally spaced apart along the flow passage 26 from the perforator 28.
In any of the well completion method examples described herein, the detecting step may comprise the at least one sensor 122 detecting acoustic noise due to the fluid 38 flow through the existing perforations 24a.
In any of the well completion method examples described herein, the at least one sensor may comprise first and second pressure sensors 68a,b longitudinally spaced apart along the flow passage 26.
In any of the well completion method examples described herein, the perforator 28 may be positioned at the desired location for forming the new perforations 24b when the at least one sensor 68a,b, 122 detects the fluid 38 flow out of the existing perforations 24a.
In any of the well completion method examples described herein, the method may include a telemetry control system 120 sending a signal to the perforating assembly 22 downhole.
In any of the well completion method examples described herein, the sending step may comprise generating a pressure pulse signal.
In any of the well completion method examples described herein, the method may include the perforator 28 firing and thereby forming the new perforations 24b in response to receipt of the signal at the perforating assembly 22.
A perforating assembly 22 for use in a subterranean well is provided to the art by the present disclosure. In one example, the perforating assembly 22 can include a perforator 28, and a control module 32 including a memory 64, a motion sensor 72, 74, a timer 66, and a controller 62 that causes the perforator 28 to fire in response to a lack of motion sensed by the motion sensor 72, 74 for a predetermined period of time.
In any of the perforating assembly 22 examples described herein, the perforating assembly 22 may include a collar locator 74, and the controller 62 may cause the perforator 28 to fire in response to the lack of motion sensed by the motion sensor 72 for the predetermined period of time after detection of a predetermined number of casing collars 75 by the collar locator 74.
In any of the perforating assembly 22 examples described herein, the perforating assembly 22 may include a collar locator 74, and the perforator 28 of the perforating assembly 22 may fire only if the collar locator 74 detects a predetermined number of casing collars 75.
In any of the perforating assembly 22 examples described herein, the perforating assembly 22 may include a collar locator 74, and the perforator 28 of the perforating assembly 22 may fire only if an output of the collar locator 74 indicates that the perforating assembly 22 has remained motionless for a predetermined period of time.
In any of the perforating assembly 22 examples described herein, one or more diverters 42 may be retained between a flow restrictor 34 and the perforator 28 of the perforating assembly 22.
In any of the perforating assembly 22 examples described herein, the diverters 42 may be contained in a container 78 between the flow restrictor 34 and the perforating assembly 22.
In any of the perforating assembly 22 examples described herein, the container 78 may be configured to degrade downhole and release the diverters 42 from the container 78.
In any of the perforating assembly 22 examples described herein, a flow restrictor 34 may be connected to a remainder of the perforating assembly 22 by a tether 76.
In any of the perforating assembly 22 examples described herein, one or more diverters 42 may be releasably attached to the tether 76.
In any of the perforating assembly 22 examples described herein, the perforating assembly 22 may include a drag device 82 configured to frictionally engage an interior surface of a casing 16.
Another perforating assembly 22 for use in a subterranean well provided to the art by the present disclosure can include a perforator 28, and one or more diverters 42 attached to the perforator 28.
In any of the perforating assembly 22 examples described herein, the diverters 42 may be attached exterior to the perforator 28.
In any of the perforating assembly 22 examples described herein, the diverters 42 may be secured to an outer housing 46 of the perforating assembly 22.
In any of the perforating assembly 22 examples described herein, the diverters 42 may be retained between a flow restrictor 34 and the perforator 28.
In any of the perforating assembly 22 examples described herein, the diverters 42 may be contained in a container 78 between the flow restrictor 34 and the perforating assembly 22.
In any of the perforating assembly 22 examples described herein, the container 78 may be configured to degrade downhole and release the diverters 42 from the container 78.
In any of the perforating assembly 22 examples described herein, a flow restrictor 34 may be connected to the perforating assembly 22 by a tether 76.
In any of the perforating assembly 22 examples described herein, the diverters 42 may be releasably attached to the tether 76.
In any of the perforating assembly 22 examples described herein, the perforating assembly 22 may include a control module 32 including a memory 64, a motion sensor 72, 74, a timer 66, and a controller 62 that causes the perforator 28 to fire in response to a lack of motion sensed by the motion sensor 72, 74 for a predetermined period of time.
In any of the perforating assembly 22 examples described herein, the perforating assembly 22 may include a collar locator 74, and the controller 62 may cause the perforator 28 to fire in response to the lack of motion sensed by the motion sensor 72 for the predetermined period of time after detection of a predetermined number of casing collars 75 by the collar locator 74.
In any of the perforating assembly 22 examples described herein, the perforating assembly 22 may include a collar locator 74, and the perforator 28 of the perforating assembly 22 may fire only if the collar locator 74 detects a predetermined number of casing collars 75.
Another well completion method provided to the art by the present disclosure can include the steps of: flowing fluid 38 through a flow passage 26 of a casing 16 lining a wellbore 14; deploying a perforating assembly 22 into the flow passage 26; displacing the perforating assembly 22 through the flow passage 26 by the fluid 38 flow at a predetermined flow rate for a predetermined flow time; and ceasing the fluid 38 flow at an end of the predetermined flow time, thereby placing a perforator 28 of the perforating assembly 22 at a desired location for forming perforations 24 through the casing 16.
In any of the well completion method examples described herein, the method may include displacing a plug 114 to a predetermined location along the flow passage 26, thereby determining a volume of the fluid 38 corresponding to displacement of the perforating assembly 22 to the desired location along the flow passage 26.
In any of the well completion method examples described herein, the predetermined location may comprise a restriction 116 in the flow passage 26.
In any of the well completion method examples described herein, the deploying may comprise deploying one or more diverters 42 into the flow passage 26 prior to deploying the perforating assembly 22 into the flow passage 26, so that the diverters 42 precede the perforating assembly 22 through the flow passage 26.
In any of the well completion method examples described herein, the deploying step may comprise deploying one or more diverters 42 into the flow passage 26 after deploying the perforating assembly 22 into the flow passage 26, so that the diverters 42 follow the perforating assembly 22 through the flow passage 26.
In any of the well completion method examples described herein, the ceasing step may comprise one or more diverters 42 blocking the fluid 38 flow through the perforations 24 in the casing 16.
In any of the well completion method examples described herein, the method may include the perforating assembly 22 degrading downhole after the perforating assembly 22 forms the perforations 24 through the casing 16.
In any of the well completion method examples described herein, the method may include forming fractures 40 into an earth formation 12 by the fluid 38 flow concurrently with the displacing of the perforating assembly 22 through the flow passage 26 by the fluid 38 flow.
In any of the well completion method examples described herein, the flowing step may comprise restricting the fluid 38 flow through an annulus 36 formed between the perforating assembly 22 and the casing 16.
In any of the well completion method examples described herein, the method may include firing the perforator 28 in response to the perforating assembly 22 remaining motionless at the desired location for a predetermined period of time.
In any of the well completion method examples described herein, the perforating assembly 22 may include a collar locator 74, and the method may include firing the perforator 28 in response to the collar locator 74 detecting a predetermined number of casing collars 75.
In any of the well completion method examples described herein, the method may include retaining one or more diverters 42 between a flow restrictor 34 and the perforator 28.
In any of the well completion method examples described herein, the method may include containing the diverters 42 in a container 78 between the flow restrictor 34 and the perforator 28.
In any of the well completion method examples described herein, the method may include containing the diverters 42 in a container 78, and degrading the container 78 downhole, thereby releasing the diverters 42 from the container 78.
In any of the well completion method examples described herein, the method may include connecting a flow restrictor 34 to the perforating assembly 22 by a tether 76.
In any of the well completion method examples described herein, the method may include releasably attaching one or more diverters 42 to the tether 76.
In any of the well completion method examples described herein, the method may include releasing the diverters 42 from the tether 76 downhole.
In any of the well completion method examples described herein, the perforating assembly 22 may be displaced to the desired location, without use of a collar locator 74.
Although various examples have been described above, with each example having certain features, it should be understood that it is not necessary for a particular feature of one example to be used exclusively with that example. Instead, any of the features described above and/or depicted in the drawings can be combined with any of the examples, in addition to or in substitution for any of the other features of those examples. One example's features are not mutually exclusive to another example's features. Instead, the scope of this disclosure encompasses any combination of any of the features.
Although each example described above includes a certain combination of features, it should be understood that it is not necessary for all features of an example to be used. Instead, any of the features described above can be used, without any other particular feature or features also being used.
It should be understood that the various embodiments described herein may be utilized in various orientations, such as inclined, inverted, horizontal, vertical, etc., and in various configurations, without departing from the principles of this disclosure. The embodiments are described merely as examples of useful applications of the principles of the disclosure, which is not limited to any specific details of these embodiments.
In the above description of the representative examples, directional terms (such as “above,” “below,” “upper,” “lower,” “upward,” “downward,” etc.) are used for convenience in referring to the accompanying drawings. However, it should be clearly understood that the scope of this disclosure is not limited to any particular directions described herein.
The terms “including,” “includes,” “comprising,” “comprises,” and similar terms are used in a non-limiting sense in this specification. For example, if a system, method, apparatus, device, etc., is described as “including” a certain feature or element, the system, method, apparatus, device, etc., can include that feature or element, and can also include other features or elements. Similarly, the term “comprises” is considered to mean “comprises, but is not limited to.”
Of course, a person skilled in the art would, upon a careful consideration of the above description of representative embodiments of the disclosure, readily appreciate that many modifications, additions, substitutions, deletions, and other changes may be made to the specific embodiments, and such changes are contemplated by the principles of this disclosure. For example, structures disclosed as being separately formed can, in other examples, be integrally formed and vice versa. Accordingly, the foregoing detailed description is to be clearly understood as being given by way of illustration and example only, the spirit and scope of the invention being limited solely by the appended claims and their equivalents.
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