CN106917596A - For the well kick detecting system and method and related well system of drill well bores - Google Patents

Abstract

A kick detection system for drilling a wellbore, comprising: an ultrasonic module for sending signals to returning drilling fluid from the wellbore and receiving corresponding backscattered signals; The scattered signal yields a flow characteristic of the returned drilling fluid, and a kick is detected based on the flow characteristic of the returned drilling fluid and the drilling-related data. A drilling system includes: a drill string for guiding a drill bit and drilling fluid into a wellbore; a conduit defining a passage for receiving the drill string and drilling fluid returning from the wellbore; and a kick detection system. A kick detection method is also described.

Description

Kick detection system and method for drilling a wellbore and related drilling system

technical field

The present invention generally relates to kick detection systems and methods for drilling wellbores and related drilling systems.

Background technique

The exploration and production of hydrocarbons from subterranean formations has been carried out for decades. Due to the limited productivity of aging land-based production wells, there has been increased interest in hydrocarbon recovery from subsea wellbores. Typically, for drilling offshore boreholes, a rotatable drill bit attached to a drill string is used to drill the borehole beneath the ocean floor. The drill string allows control of the drill bit from a surface location (typically, from an offshore platform or drill ship). Additionally, risers are deployed to connect platforms at the surface to wellheads on the seafloor. The drill string is passed through the riser to guide the drill bit into the wellbore.

During drilling, the drill bit rotates while the drill string delivers the necessary power from the surface platform. Simultaneously, drilling fluid is circulated from the surface platform through the drill string to the drill bit and then back to the surface platform through the space between the drill string and the casing or riser. The drilling fluid maintains static pressure against fluid pressure from the wellbore and cools the drill bit during operation. Additionally, the drilling fluid mixes with the material excavated during drilling of the wellbore and carries the material to the surface for disposal.

In some cases, the pressure of the fluid entering the wellbore from the formation may be higher than the pressure of the drilling fluid. This can result in an unwanted influx of fluid into the wellbore, known in the industry as a "kick." In some cases, a kick occurs resulting in potentially catastrophic equipment failure and attendant potential injury to the drilling operator and the environment.

Wellbore operators remain alert to the potentially devastating nature of such unwanted influxes and continuously monitor the inflow and outflow of drilling fluid at the surface to detect kicks. However, monitoring drilling fluid in surface platforms using conventional devices is difficult due to their size and complexity. Furthermore, there is a relatively long time (e.g., tens of minutes) between the moment a disturbance of the fluid occurs at the wellbore and the moment the disturbance is detected at the surface, i.e. when the operator at the surface is warned of a well kick , a well kick may have occurred.

Accordingly, it would be desirable to provide new and improved kick detection systems and methods for drilling wellbores and related drilling systems.

Contents of the invention

In one aspect, embodiments of the present invention relate to a kick detection system for drilling a wellbore comprising: an ultrasound module for sending a signal to returning drilling fluid from the wellbore and receiving corresponding backscatter signal; a processing device for deriving a flow characteristic of said returned drilling fluid based on said backscatter signal and detecting a kick based on said flow characteristic of said returned drilling fluid and drilling related data.

In another aspect, embodiments of the present invention relate to a drilling system comprising: a drill string for guiding a drill bit and drilling fluid into a wellbore; passage of drilling fluid back from the borehole; and a kick detection system according to an embodiment of the present invention.

In yet another aspect, embodiments of the present invention relate to a kick detection method for drilling a wellbore, comprising: sending a signal to drilling fluid returning from the wellbore and receiving a corresponding backscatter signal; based on the A backscatter signal yields a flow characteristic of the returned drilling fluid; a kick is detected based on the flow characteristic of the returned drilling fluid and drilling-related data.

Description of drawings

The above and other aspects, features and advantages of the present disclosure will become more apparent with reference to the following detailed description in conjunction with the accompanying drawings, in which:

Figure 1 is a schematic diagram of a drilling system in operation according to an embodiment of the present invention;

2 is a schematic diagram of a kick detection system according to an embodiment of the present invention;

3 is a schematic diagram of an ultrasonic sensor disposed on a catheter according to an embodiment of the present invention;

4 is a partial schematic diagram of a catheter provided with an ultrasound module according to an embodiment of the present invention;

5 is a schematic flow chart of a kick detection method for drilling a wellbore according to an embodiment of the present invention; and

FIG. 6 is a schematic flowchart of step 23 of FIG. 5 according to an embodiment of the present invention.

detailed description

One or more specific embodiments of the present invention will be described below. First of all, it should be pointed out that, in the process of describing these implementations, for the sake of concise description, it is impossible for this specification to describe all the features of the actual implementations in detail. It should be understood that, in the actual implementation process of any embodiment, just like in the process of any engineering project or design project, in order to achieve the developer's specific goals, or to meet system-related or business-related constraints , often a variety of specific decisions are made, and this changes from one implementation to another. In addition, it will be appreciated that while such development efforts may be complex and lengthy, the technology disclosed in this disclosure will be Some design, manufacturing or production changes based on the content are just conventional technical means, and should not be understood as insufficient content disclosed in the present invention.

Unless otherwise defined, the technical terms or scientific terms used in the specification and claims shall have the ordinary meanings understood by those skilled in the technical field to which the present invention belongs. "First" or "second" and similar words used in the specification and claims do not indicate any order, quantity or importance, but are only used to distinguish different components. "A" or "one" and similar words do not indicate a limitation of number, but mean that there is at least one. "Or" includes any one or all of the listed items. Words such as "comprises" or "comprises" and similar terms mean that the elements or items listed before "comprises" or "comprises" include the elements or items listed after "comprises" or "comprises" and their equivalent elements, and do not exclude other components or objects.

Figure 1 shows a schematic diagram of a drilling system 10 in operation according to an embodiment of the present invention. FIG. 2 shows a schematic diagram of a kick detection system 100 according to an embodiment of the present invention. In some embodiments, the drilling system 10 is configured for wellbore drilling for the exploration and production of hydrocarbons, such as fossil fuels. Non-limiting examples of wellbores include onshore wellbores and offshore wellbores. In some embodiments, drilling system 10 is configured to drill offshore wellbores.

As shown in FIG. 1 , the drilling system 10 includes a drilling string 14 for guiding a drill bit 15 and drilling fluid 101 to a wellbore 104, a drilling string 14 defined for receiving the drill string 14 and returning drilling fluid 101 from the wellbore 104. 102 , conduit 13 of channel 103 , and kick detection system 100 .

The drill string 14 includes drilling pipe (not shown) assembled to an offshore installation 106 , such as an offshore platform or drillship. A drill bit 15 is assembled to the end of the drill string 14 . During drilling operations, drilling fluid 101 is directed through the drill pipe into the wellbore 104 and the drill bit 15 is rotated to perform drilling below the seabed 105 .

One end of the conduit 13 is assembled to the offshore device 106 , and the other end of the conduit 13 is connected to the wellhead of the wellbore 104 .

During drilling, drill string 14 guides drill bit 15 into wellbore 104 and rotates drill bit 15 . Drilling fluid 101 is circulated from offshore installation 106 through drill string 14 to drill bit 15 and back to offshore installation 106 as return drilling fluid 102 through channel 103 .

Drilling fluid 101 maintains a hydrostatic pressure against fluid pressure in the formation and carries materials such as chopped or excavated material, including crushed or chopped rock, to the offshore installation during drilling of wellbore 104 106 while cooling the drill bit 15. In some embodiments, drilling fluid 101 may include water, oil, and various additives. Returned drilling fluid 102 may include a mixture of drilling fluid 101 and material excavated during drilling of wellbore 104 . On offshore installation 106 , the returned drilling fluid 102 may be processed to remove solids and then recycled for use as drilling fluid 101 .

The kick detection system 100 includes an ultrasound module 11 for sending a signal to the returning drilling fluid 102 from the wellbore 104 and receiving a corresponding backscatter signal, and an ultrasonic module 11 for deriving the returning drilling fluid 102 based on the backscatter signal. Flow characteristics and processing device 12 for detecting kicks based on the flow characteristics of the returned drilling fluid 102 and drilling related data.

In some embodiments, the ultrasound module 11 is located below the sea surface 107 . In some embodiments, the ultrasound module 11 is disposed near the wellbore 104 .

The ultrasound module 11 sends signals to the returning drilling fluid 102 as it passes through the channel 103, and the ultrasound module 11 receives corresponding signals due to reflections from particles (not shown) in the returning fluid 102. backscattered signal.

In some embodiments, the ultrasound module 11 is disposed outside the catheter 13 and sends signals to the catheter 13 . In some embodiments, the ultrasound module 11 is disposed on the catheter 13 . For example, the ultrasound module 11 is disposed on the outer surface of the catheter 13 , or is disposed in the catheter 13 or extends into the catheter 13 . In this case, the conduit 13 may also include a barrier (not shown) for isolating the ultrasound module 11 from the returning drilling fluid 102 , thereby providing thermal insulation and reducing pressure on the ultrasound module 11 .

In some embodiments, ultrasound module 11 includes one or more ultrasound sensors. FIG. 3 shows a schematic view of a plurality of ultrasound sensors 111 spaced apart from each other and arranged around a catheter 13 .

In some embodiments, as shown in FIG. 4 , conduit 13 includes a stand pipe 131 and a spool 132 . Riser 131 and conduit 132 define channel 103 that houses drill string 14 and returning drilling fluid 102 . The ultrasound module 11 is arranged on the pipeline 132 . The pipe 132 isolates the ultrasonic module 11 and provides a working environment for the ultrasonic module 11 , for example, it can provide a suitable temperature and pressure environment for the ultrasonic module 11 . In some embodiments, each end of conduit 132 is connected to riser 131 . In some embodiments, one end of the pipe 132 is connected to the riser 131, and the other end of the pipe 132 is connected to a lower marine riser insertion assembly (LMRP, Lower Marine Riser Package, not shown) or a riser joint (riser joint, not shown). show).

The ultrasound module 11 sends the received backscatter signals to the processing device 12 . Based on the backscatter signal, the processing device 12 derives flow characteristics of the returning drilling fluid 102, such as velocity of the returning drilling fluid 102, at least a portion of flow profiles, volumetric flow, or any combination thereof. In some embodiments, a suitable algorithm (such as a Doppler spectral analysis algorithm or a time-domain based matrix beam decomposition algorithm) may be used to derive the flow properties based on the backscatter signal.

The processing device 12 detects the kick based on the flow characteristics of the returned drilling fluid 102 and drilling related data.

In some embodiments, drilling-related data includes, but is not limited to, backscattered signals obtained by sending signals to the drilling fluid 101 flowing toward the wellbore 104, operational data related to drilling operations, fluid property data, or any combination thereof .

The backscattered signal of the drilling fluid 101 can be obtained by sending the signal to the drilling fluid 101 by another ultrasound module (not shown). In some embodiments, the other ultrasound module is located on the marine installation 106 or above or near the sea surface 107 ( FIG. 1 ). In some embodiments, the flow characteristics of the drilling fluid 101 may be derived based on the backscatter signal of the drilling fluid 101 , similar to the flow characteristics of the returning drilling fluid 102 .

In some embodiments, operational data related to drilling operations includes, but is not limited to, the drilling mode used to drill the wellbore 104, pump stroke number, formation analysis data, bit weight , pressure data including riser pressure and/or borehole pressure, or any combination thereof; drilling modes may include, but are not limited to, trip in mode, trip out mode, flow check mode (flow check mode), normal drilling mode (normal drilling mode) and mud circulation mode (mud circulation mode), etc. Drilling operations typically have an effect on drilling fluid 101 and returning drilling fluid 102, so operational data related to drilling operations can aid in kick detection.

For example, if the drilling fluid 101 is pumped faster (i.e., the number of pump strokes is greater), the velocity of the drilling fluid 101 is greater and a rough estimate of the drilling fluid 101 used in kick detection can be estimated based on the number of pump strokes. flow rate. As another example, changes in bit weight, changes in pressure indicated by pressure data, or interesting geological structures indicated by formation analysis data may aid in kick detection.

In some embodiments, the fluid property data may be indicative of the density, viscosity, or composition of the drilling fluid 101 or the returned drilling fluid 102 . In some embodiments, fluid property data includes, but is not limited to, mud weight, surface mud cut, or combinations thereof. In some embodiments, undesired changes in composition and density, etc., in the returned drilling fluid 102 indicated by the fluid property data may aid in kick detection.

In some embodiments, the backscatter signal of the drilling fluid 101 and the number of pump strokes may be used as the first part of the drilling-related data for deriving the flow characteristics of the drilling fluid 101 . In some embodiments, the operational data and fluid property data may serve as a second portion of drilling-related data for detecting a kick along with the flow properties of the returning drilling fluid 102 .

In some embodiments, the processing device 12 detects the kick based on a change in the difference between the flow characteristics of the returned drilling fluid 102 and the flow characteristics of the drilling fluid 101 obtained based on the first portion of the drilling-related data.

For example, processing device 12 identifies an ongoing or imminent kick when a change in the difference between the flow characteristics of returning drilling fluid 102 and the flow characteristics of drilling fluid 101 increases or increases faster than a threshold. In some embodiments, when the velocity, at least a portion of the fluid profile, or volume flow of the returning drilling fluid 102 increases faster (or faster than a threshold) than the velocity, at least a portion of the fluid profile, or the volume flow of the drilling fluid 101 , the processing device 12 identifies an ongoing or imminent well kick.

In some embodiments, the processing facility 12 changes based on the difference between the flow characteristics of the returned drilling fluid 102 and the flow characteristics of the drilling fluid 101 and drilling related data including operational data and/or fluid property data related to drilling operations. The second part to detect kicks. In some embodiments, the second part of the drilling-related data may be helpful when a kick is not easily determined based on changes in the difference alone, since some of the data in the second part of the drilling-related data may be to identify well kicks.

In some embodiments, the processing device 12 detects a kick based on a change in the flow of the returning drilling fluid 102 when the drilling-related data indicates any of a trip mode, a trip mode, a flow check mode, and a normal drilling mode. . In these drilling modes, drilling fluid 101 is absent (such as in trip-in and trip-out modes), or drilling fluid 101 is reduced (such as in flow check mode), or the flow characteristics of drilling fluid 101 are generally stable (such as in normal drilling mode), so the processing device 12 can detect a kick without the flow characteristics of the drilling fluid 101, for example, when the velocity of the returning drilling fluid 102, at least a portion of the fluid profile, or the volumetric flow increases more Faster than or faster than the threshold, the processing device 12 detects a kick. In some embodiments, the processing device 12 detects the kick based on the flow change of the returned drilling fluid 102 and the second portion of the drilling-related data when the downhole mode, the trip out mode, the flow check mode, or the normal drilling mode is indicated.

Referring to FIGS. 1 and 2 , in some embodiments, the processing facility 12 includes a first processing module 121 located below the sea surface 107 and a second processing module 122 located above the sea surface 107 . In some embodiments, the first processing module 121 obtains the flow characteristic based on the backscatter signal provided by the ultrasound module 11 through the transmission module 108 . In some embodiments, the second processing module 122 detects the kick based on the flow characteristics of the returned drilling fluid 102 and drilling related data. In some embodiments, the first processing module 121 is located on the seabed 105 . In some embodiments, the second processing module 122 is located on the marine installation 106 . In some embodiments, the kick detection system 100 includes a communication device 17 for sending information between the first processing module 121 and the second processing module 122 .

In some embodiments, processing device 12 provides an indication to blowout preventer stack 16 of drilling system 10 when a kick is detected. In some embodiments, an operator inputs instructions to BOP stack 16 . The blowout preventer stack 16 operates according to instructions from the processing facility 12 or from an operator to prevent a well kick.

In some embodiments, the kick detection system 100 includes an alarm device 18 for alerting an operator when a kick is detected. For example, an alarm is given by an alarm bell or a light having a warning color such as yellow or red. In some embodiments, the alarm device 18 is located on the marine installation 106 .

In some embodiments, the kick detection system 100 includes a display device 19 for displaying flow characteristics, drilling related data, kick warnings, or any combination thereof. In some embodiments, display device 19 is located on marine installation 106 .

In some applications, the fluid pressure in the formation may be higher than the drilling fluid 101 pressure. This can cause fluids in the formation to enter the channel 103 and join the returning drilling fluid 102, which results in a larger return flow (or influx). Such an influx acts as a kick and can lead to a blowout if not controlled and is harmful to the drilling operator and the environment. Therefore, it is desirable for a kick detection system to detect a kick in a timely manner. The kick detection system 100 is simple enough to be suitable for offshore applications, and the kick detection is fast, so that an alarm can be issued in time to reduce or avoid the damage of the kick.

Fig. 5 shows a schematic flowchart of a kick detection method 20 for drilling a wellbore according to an embodiment of the present invention. The kick detection method 20 includes the step 21 of sending a signal to the returned drilling fluid 102 and receiving the corresponding backscatter signal, the step 22 of obtaining the flow characteristics of the returned drilling fluid 102 based on the backscatter signal, and the step 22 of obtaining the flow characteristics based on the returned drilling fluid 102 . The step 23 of detecting a kick from the flow characteristics and drilling related data 102 .

In some embodiments, as shown in FIG. 6 , step 23 includes the step 231 of obtaining the flow characteristics of the drilling fluid 101 based on the first portion of the drilling-related data comprising the number of pump strokes or the backscatter signal of the drilling fluid 101, and based on A change in the difference between the flow characteristics of the drilling fluid 101 and the flow characteristics of the returning drilling fluid 102 to detect a kick 232 .

In some embodiments, step 232 includes changing the drilling fluid flow characteristics based on the difference between the flow characteristics of the drilling fluid 101 and the returning drilling fluid 102 and including operational data, fluid property data, or a combination thereof related to the drilling operation. A second portion of the correlated data is used to detect a kick (not shown).

In some embodiments, step 23 includes determining the flow of the returned drilling fluid 102 based on the backscatter signal when the drilling-related data indicates any one of a trip mode, a trip mode, a flow check mode, and a normal drilling mode. change, and the step of detecting a kick based on the change in flow (not shown).

In some embodiments, kick detection method 20 includes the step (not shown) of operating blowout preventer stack 16 to prevent a kick. In some embodiments, kick detection method 20 includes a step (not shown) of alerting an operator when a kick is detected. In some embodiments, the kick detection method 20 includes a step (not shown) of displaying flow characteristics, drilling related data, kick warnings, or a combination thereof.

Although the present invention has been described in detail in conjunction with specific embodiments, those skilled in the art can understand that many modifications and variations can be made to the present invention. It is, therefore, to be realized that the intent of the appended claims is to cover all such modifications and variations as are within the true spirit and scope of the invention.

Claims (20)

1. A kick detection system for drilling a wellbore, comprising: an ultrasound module for sending signals to drilling fluid returning from said wellbore and receiving corresponding backscattered signals; and A processing device for deriving a flow characteristic of the returned drilling fluid based on the backscatter signal, and detecting a kick based on the flow characteristic of the returned drilling fluid and drilling-related data. 2. The kick detection system of claim 1, wherein the first portion of the drilling-related data includes pump stroke counts or backscatter signals obtained by signaling drilling fluid flowing to the wellbore, the A processing device obtains a flow characteristic of the drilling fluid flowing to the wellbore based on the first portion of the drilling-related data, and based on the flow characteristic of the drilling fluid flowing to the wellbore and the returned A change in the difference between said flow characteristics of the drilling fluid detects a kick. 3. The kick detection system of claim 2, wherein the processing device detects a kick based on a change in the difference and a second portion of the drilling-related data, the second portion of the drilling-related data Sections include operational data, fluid property data, or combinations thereof related to drilling operations. 4. The kick detection system according to claim 1, wherein when the drilling-related data indicates any one of a tripping mode, a tripping mode, a flow checking mode and a normal drilling mode, the processing device is based on The backscatter signal determines a change in flow of the returning drilling fluid and detects a kick based on the change in flow. 5. The kick detection system of claim 1, wherein the processing facility comprises a first processing module located below the surface of the sea and a second processing module located above the surface of the sea. 6. The kick detection system of claim 5, comprising a communication device for sending information between the first processing module and the second processing module. 7. The kick detection system of claim 1 including an alarm device for alerting an operator when a kick is detected. 8. The kick detection system of claim 1, comprising a display device for displaying said flow characteristics, said drilling related data, kick warnings, or any combination thereof. 9. A drilling system comprising: the drill string, which guides the drill bit and drilling fluid into the wellbore; a conduit defining a passage for receiving the drill string and drilling fluid returning from the wellbore; A kick detection system comprising an ultrasound module for sending a signal to drilling fluid returning from the wellbore and receiving a corresponding backscatter signal, and an ultrasonic module for deriving the returned drilling fluid based on the backscatter signal A flow characteristic and processing device for detecting a kick based on said flow characteristic of said returned drilling fluid and drilling related data. 10. The drilling system of claim 9, wherein the ultrasound module includes a plurality of ultrasound sensors disposed on the conduit. 11. The drilling system of claim 9, wherein the conduit includes a barrier for isolating the ultrasonic module from the returning drilling fluid. 12. The drilling system of claim 9, wherein the conduit comprises: riser; and A conduit connected to the riser for positioning and isolating the ultrasound module and providing an operating environment for the ultrasound module. 13. The drilling system of claim 9, including a blowout preventer stack that operates in accordance with instructions from the processing facility to prevent a well kick. 14. A method of kick detection for drilling a wellbore, comprising: sending a signal to drilling fluid returning from said wellbore and receiving a corresponding backscattered signal; obtaining a flow characteristic of the returned drilling fluid based on the backscatter signal; and A kick is detected based on the flow characteristics of the returned drilling fluid and drilling related data. 15. The kick detection method of claim 14, wherein the first portion of the drilling-related data includes pump stroke counts or backscatter signals obtained by signaling drilling fluid flowing to the wellbore, the detection well Chung includes: deriving flow characteristics of the drilling fluid to the wellbore based on the first portion of the drilling-related data; A kick is detected based on a change in a difference between the flow characteristic of the drilling fluid flowing to the wellbore and the flow characteristic of the returning drilling fluid. 16. The kick detection method of claim 15, wherein said detecting a kick comprises detecting a kick based on a change in said difference and a second portion of said drilling-related data, a first portion of said drilling-related data. The second part includes operational data, fluid property data, or a combination thereof related to drilling operations. 17. The kick detection method according to claim 14, wherein the detection of a kick comprises: when the drilling-related data indicates any one of a tripping mode, a tripping mode, a flow checking mode and a normal drilling mode , determining a change in flow of the returned drilling fluid based on the backscatter signal, and detecting a kick based on the change in flow. 18. The kick detection method of claim 14, comprising operating a blowout preventer stack to prevent the kick. 19. The kick detection method of claim 14, including alerting an operator when a kick is detected. 20. The kick detection method of claim 14, comprising displaying said flow characteristics, said drilling related data, kick warnings, or any combination thereof.