Patent Application
20180371881
The following descriptions and examples are not admitted as being prior art by virtue of their inclusion in this section.
Many operations are performed in providing well services to create a safe and functioning oil well. For example, some oil wells use casing that is cemented in place in the borehole. This casing may be run to keep a borehole from collapsing or to satisfy environmental or safety regulations for the drilling site. However, running casing has been performed using a specific rig tool, sometimes referred to as a Casing Running Tool (CRT). This CRT may be replaced with another rig tool configured to cement the casing in place. Changing from one rig tool to another involves coordination, planning, and time to remove the first rig tool and then set up and run the second rig tool. Changing from one rig tool to another also requires the use of very expensive rig time, potentially affecting the overall profitability of the well.
This summary is provided to introduce a selection of concepts that are further described below in the detailed description. This summary is not intended to identify key or essential features of the claimed subject matter, nor is it intended to be used as an aid in limiting the scope of the claimed subject matter.
In accordance with an embodiment, an oilfield tool is provided that includes a Casing Running Tool (CRT) adapted to run casing into a borehole. In addition, the oilfield tool may include a dynamic device launching tool adapted to launch dynamic devices and a swivel adapted to engage a fluid supply line. The oilfield tool is used to run casing and cement the casing into the borehole without requiring modification of the oilfield tool configuration. Dynamic devices launched by the dynamic device launching tool traverse through the CRT and alter their circumferential configuration to engage an inner surface of the casing and to separate a sealant (e.g., a cement slurry, a resin, among others) provided via the fluid supply line from other borehole fluids.
In accordance with another embodiment, a method for oilfield borehole preparation is provided that includes configuring an oilfield tool. The oilfield tool may include a CRT, a dynamic device launching tool coupled to the CRT and adapted to launch dynamic devices, and a swivel adapted to engage a fluid supply.
The method may further include running casing into a borehole using the oilfield tool and cementing the casing into the borehole using the same oilfield tool. The dynamic devices traverse via the CRT and, in some applications, function to separate a sealant from other borehole fluids.
In accordance with another embodiment, an oilfield system for running and cementing casing is provided. The oilfield system may include an oilfield tool comprising a CRT, a dynamic device launching tool coupled to the CRT and adapted to launch dynamic devices, and a swivel coupled to the dynamic device launching tool and coupled to a fluid supply interface. The system may further include a sealant supply device and a borehole fluid supply device.
The oilfield system is configured to run casing into a borehole. A sealant is introduced from the sealant supply device via the fluid interface. The sealant follows a first dynamic device traversing the CRT. The first dynamic device subsequently engages an inner circumference of the casing.
A borehole fluid is introduced from the borehole fluid supply device via the fluid supply interface via the fluid interface. The borehole fluid follows a second dynamic device traversing the CRT. The second dynamic device subsequently engages an inner circumference of the casing. An increasing pressure may rupture the first dynamic device, providing sealant to the annulus surrounding the casing.
Other or alternative features will become apparent from the following description, from the drawings, and from the claims.
Certain embodiments will hereafter be described regarding the accompanying drawings, wherein like reference numerals denote like elements. It should be understood, however, that the accompanying drawings illustrate only the various implementations described herein and are not meant to limit the scope of various technologies described herein. The drawings are as follows:
Reference throughout the specification to “one embodiment,” “an embodiment,” “some embodiments,” “one aspect,” “an aspect,” or “some aspects” means that a particular feature, structure, method, or characteristic described in connection with the embodiment or aspect is included in at least one embodiment of the present disclosure. Thus, the appearance of the phrases “in one embodiment” or “in an embodiment” or “in some embodiments” in various places throughout the specification are not necessarily all referring to the same embodiment. Furthermore, the particular features, structures, methods, or characteristics may be combined in any suitable manner in one or more embodiments. The words “including” and “having” shall have the same meaning as the word “comprising.”
Moreover, inventive aspects lie in less than all features of a single disclosed embodiment. Thus, the claims following the Detailed Description are hereby expressly incorporated into this Detailed Description, with each claim standing on its own as a separate embodiment.
Production of hydrocarbons or other fluids from geological formations requires the use of several technologies. Referring generally to
To prevent the collapse of the boreholes 120 and 125 among other reasons, an outer casing 130 and an inner casing 135 have been run into the boreholes. Although two casings 130, 135 have been shown, for the purposes of description only the outer casing 130 has been cemented into the outer borehole 120.
Cementing results in the outer sealant 140 filling the outer annulus 150 located between the exterior wall of the outer casing 130 and the interior wall of the outer borehole 120. Cementing the outer casing 130 helps in securing the outer casing 130 in place and in sealing the formation surrounding the outer casing 130, and sealing the outer annulus 150, among other reasons.
Generally, both the outer casing 130 and the inner casing 135 are cemented or sealed in place. However, the inner casing 135 has not been depicted as cemented in order to show in more detail how the outer sealant 140, formed during the cementing of the outer casing 130, is drilled through during the formation of the inner borehole 125. After running the inner casing 135 into the inner borehole 125, the resulting space surrounding the exterior of the inner casing 135 and the interior of the outer casing 130 and the exterior wall of the inner borehole 125 is the inner annulus 155.
Running casing and cementing the casing have previously been performed during separate operations using separate oilfield tools. Changing from one oilfield tool to another takes up valuable rig time. As further shown in
A swivel 180 is shown in this exemplary embodiment for applications in which rotating of the string is required. In other embodiments, a swivel 180 may be omitted and the sealant pumped through the top drive. A side-entry T-piece (not shown) may be used in place of the swivel 180.
The CRT 160 is adapted and configured to run casing. The CRT 160 has a CRT interior passageway 162 that is of a smaller interior diameter than the interior diameter of the inner casing 135. In some cases, the ratio of the diameter of the inner casing 135 to the diameter of the CRT interior passageway 162 of the CRT 160 can be as high as 3 to 1, or 5 to 1 in other cases. Of course, these ranges are exemplary and embodiments of this disclosure may differ as appropriate.
At least in part because of this difference in the interior diameters, the oilfield tool 100 comprises a dynamic device launching tool 170. In this exemplary embodiment, the dynamic device launching tool 170 comprises a first dynamic device 172, a first dynamic device release 173, a second dynamic device 174, and a second dynamic device release 175. More dynamic devices or less dynamic devices may be used or held by the dynamic device launching tool 170 depending upon the application. In some cases, a dynamic device 172, 174 may be added to the dynamic device launching tool 170 while the oilfield tool 100 is rigged up.
The dynamic devices 172, 174 may be referred to as darts or plugs. In some applications, dynamic devices 172, 174 function to wipe down and seal against the inner surface of the casing 135. In other applications, the dynamic devices 172, 174 separate diverse types of borehole fluids from one another. Depending upon the application, first and second dynamic devices 172, 174 may provide sealing, wiping, and separating, or other functions.
The swivel 180 may contain an operational interface 187 (e.g., electrical, mechanical, or hydraulic, among others) for operating the dynamic device launching tool 170. In some applications, the dynamic device launching tool 170 may also be controlled wirelessly (not shown).
The dynamic device launching tool 170 comprises a dynamic device interior passage 176 communicatively coupled to the CRT interior passageway 162. A dynamic device 172, 174 released by a dynamic device release 173, 175 traverses through the inner casing 135 via the dynamic device interior passageway 176 and the CRT interior passageway 162.
Once within the inner casing 135, the dynamic device 172, 174 circumferentially expands from a reduced diameter form to an expanded diameter form to establish a contacting seal with the inner surface of the inner casing 135 (refer to
Operation of the oilfield tool 100 will be discussed in more detail as follows.
Turning generally to
A sealant (e.g., cement slurry, resin, among others) 245 provided by sealant supply 240 via the fluid inlet 185 of swivel 180 follows the first dynamic device 172 into the casing 230. The sealant 240 and first dynamic device 172 traverse into casing 230 via the dynamic device interior passageway 176 and the CRT interior passageway 162. The first dynamic device 172 circumferentially expands from a reduced diameter to an expanded diameter in order to substantially separate the sealant 245 from a first borehole fluid 252. As the sealant 245 is pumped into the casing 230, the first borehole fluid 252 is displaced via the annulus 240 and removed.
At this general time, the second dynamic device 174 is still retained by the second dynamic device release 175. The second dynamic device 174 may be provided when the oilfield tool 100 is made up or added to the dynamic device launching tool 170 at some point when required by the cementing operation.
Turning generally now to
The rupture device 178 may be a rupture disk or the use of rupture-able material. After exceeding a certain pressure, the rupture device 178 ruptures, allowing the sealant 245 to flow into the annulus 240 surrounding the casing 230. The second borehole fluid 254 is pumped into the casing 230 until the sealant 245 is fully distributed within the annulus 240. In some cases, the second borehole fluid 254 will be introduced into the casing 230 until the second dynamic device 174 is adjacent to the first dynamic device 172, as shown in
After the sealant 245 hardens, the first and second dynamic devices 172, 174 may be drilled out and an inner casing (not shown) run in and cemented in place. In some cases, multiple internal layers of casing may be run into a borehole. Depending upon the application, some casing may not be cemented in place.
Referring generally to
In some embodiments, the action described as configuring an oilfield tool 310 can be further detailed as comprising providing a CRT 312, providing a dynamic device launching tool 314 and providing a swivel 316, as shown in
The oilfield tools may be made up prior to the running of casing. The making up of the oilfield tools can be done at the wellsite or prior to delivery to the wellsite. According to some applications, embodiments of the oilfield tools may be made up in the following order from bottom to top:
The oilfield tool can then be used to pick-up up, run, circulate or reciprocate casing, depending upon the requirements of the application. Casing is made up until the desired depth is reached. Once the casing is at the desired depth, the casing can be circulated, reciprocated or rotated prior to commencing cement operations.
In some embodiments, a sealant hose may be connected to the swivel to allow sealant to be pumped into the well system without passing through the top drive. Control and power lines may also need to be connected to the dynamic device launching tool via the swivel, i.e. with a swivel mechanism for each line comprising a dynamic device (e.g., such as via the operational interface).
Once circulation is complete, the internal blow out preventer (IBOP) (not shown) may be closed and sealant or other fluids can be pumped through the swivel, dynamic device launching tool and CRT. In other embodiments, sealant may be pumped directly through the top drive and a side entry T-piece used in place of the swivel. In such an embodiment, the controls for the dynamic device launching tool may be relocated as appropriate.
A first dynamic device (sometimes referred to as a bottom dynamic device) may be launched ahead of the sealant to isolate the sealant from any previous borehole fluids and/or to wipe the internal surface of the casing wall. This first dynamic device may allow circulation to continue once the first dynamic device has reached the bottom of the casing.
After the sealant has been pumped into the casing, the dynamic device launching tool can launch a second dynamic device (sometimes referred to as a top dynamic device) that will isolate the sealant from other borehole fluids following the sealant. The second dynamic device will create a pressure tight seal once it has reached the bottom of the casing, thereby allowing a casing pressure test to be performed.
Either before or after the casing pressure test is complete, float valves in the bottom of the casing can be tested by allowing fluid to pass backwards through them. Upon completion of the casing pressure test and the float test, the oilfield tool equipment can be rigged down or wracked back. If the oilfield tool is required for further operations, new first and second dynamic devices can be loaded into the dynamic device launching tool in readiness for re-use.
Referring generally to
A distal end of the inner arms 420 may be slidably and pivotally coupled to the body of the outer arms 430. In this embodiment, the coupling is shown as a pin and groove assembly in which the groove 435 is provided in a portion of the outer arm 430. Other mechanisms may be used as appropriate.
The outer arms 430 may interact with a sealing/wiping/separating component 440 attached around the outer arms 430. In some embodiments, the sealing/wiping/separating component 440 may be a resilient material, fabric, folded structure, or expandable material. In other cases the sealing/wiping/separating component 440 may be composed of multiple component pieces that work together to form an effective, drillable material that interacts to seal/wipe the inner circumferential surface of the casing or to separate borehole fluids and sealants.
In this illustrative example, in
When the dynamic device 400 is released, the dynamic device 400 transitions to an expanded diameter form to engage the larger inner circumferential area of the casing. The outer arms 430 and sealing/wiping/separating component 440 are all adapted to expand to contact or otherwise engage the inner surface of the casing.
As seen in
Referring generally to
After the casing has been run in, a sealant supply engaged to the sealant inlet 576 introduces sealant into the oilfield tool 500. As the sealant flows through the sealant inlet 576, the first dynamic device 572 is released ahead of the sealant and travels into the casing below the oilfield tool 500. The first dynamic device 572 may provide the functionality of separating the sealant from the borehole fluid already in the casing. In some applications, this may be the only function of the first dynamic device 572.
When the appropriate amount of sealant has been introduced into the system, borehole fluid is provided via the borehole fluid inlet 578. As borehole fluid is introduced into the oilfield tool 500, the second dynamic device 574 is released and provides a separation or barrier between the sealant and the introduced borehole fluid. As with the first dynamic device 572, in some applications separation of fluids may be the only function of the second dynamic device 574.
Elements of the embodiments have been introduced with either the articles “a” or “an.” The articles are intended to mean that there are one or more of the elements. The terms “including” and “having” are intended to be inclusive such that there may be additional elements other than the elements listed. The term “or” when used with a list of at least two elements is intended to mean any element or combination of elements.
Although only a few example embodiments have been described in detail above, those skilled in the art will readily appreciate that many modifications are possible in the example embodiments without materially departing from this disclosure. Accordingly, all such modifications are intended to be included within the scope of this disclosure as defined in the following claims.
In the claims, means-plus-function clauses are intended to cover the structures described herein as performing the recited function and not only structural equivalents, but also equivalent structures. Thus, although a nail and a screw may not be structural equivalents in that a nail employs a cylindrical surface to secure wooden parts together, whereas a screw employs a helical surface, in the environment of fastening wooden parts, a nail and a screw may be equivalent structures.
It is the express intention of the applicant not to invoke 35 U.S.C. § 112, paragraph 6 for any limitations of any of the claims herein, except for those in which the claim expressly uses the words ‘means for’ together with an associated function.
| Number | Date | Country | Kind |
|---|---|---|---|
| 17167725.5 | Apr 2017 | EP | regional |
