US20180371881A1 - Tool, method and system for well services - Google Patents
Tool, method and system for well services Download PDFInfo
- Publication number
- US20180371881A1 US20180371881A1 US15/960,658 US201815960658A US2018371881A1 US 20180371881 A1 US20180371881 A1 US 20180371881A1 US 201815960658 A US201815960658 A US 201815960658A US 2018371881 A1 US2018371881 A1 US 2018371881A1
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- United States
- Prior art keywords
- casing
- tool
- dynamic device
- oilfield
- borehole
- Prior art date
- Legal status (The legal status is an assumption and is not a legal conclusion. Google has not performed a legal analysis and makes no representation as to the accuracy of the status listed.)
- Abandoned
Links
- 238000000034 method Methods 0.000 title claims abstract description 20
- 239000012530 fluid Substances 0.000 claims abstract description 54
- 239000000565 sealant Substances 0.000 claims abstract description 47
- 239000004568 cement Substances 0.000 claims abstract description 13
- 238000002360 preparation method Methods 0.000 claims description 2
- 238000007789 sealing Methods 0.000 description 10
- 230000009471 action Effects 0.000 description 4
- 230000015572 biosynthetic process Effects 0.000 description 3
- 238000005755 formation reaction Methods 0.000 description 3
- 239000000463 material Substances 0.000 description 3
- 230000004048 modification Effects 0.000 description 3
- 238000012986 modification Methods 0.000 description 3
- 239000003129 oil well Substances 0.000 description 3
- 238000005516 engineering process Methods 0.000 description 2
- 230000007246 mechanism Effects 0.000 description 2
- 239000011347 resin Substances 0.000 description 2
- 229920005989 resin Polymers 0.000 description 2
- 230000000717 retained effect Effects 0.000 description 2
- 238000000926 separation method Methods 0.000 description 2
- 239000002002 slurry Substances 0.000 description 2
- 230000002730 additional effect Effects 0.000 description 1
- 230000004888 barrier function Effects 0.000 description 1
- 230000008878 coupling Effects 0.000 description 1
- 238000010168 coupling process Methods 0.000 description 1
- 238000005859 coupling reaction Methods 0.000 description 1
- 238000005553 drilling Methods 0.000 description 1
- 230000007613 environmental effect Effects 0.000 description 1
- 239000004744 fabric Substances 0.000 description 1
- 229930195733 hydrocarbon Natural products 0.000 description 1
- 150000002430 hydrocarbons Chemical class 0.000 description 1
- 238000004519 manufacturing process Methods 0.000 description 1
- 230000008569 process Effects 0.000 description 1
- 239000012858 resilient material Substances 0.000 description 1
- 238000003860 storage Methods 0.000 description 1
- 230000007704 transition Effects 0.000 description 1
Images
Classifications
-
- E—FIXED CONSTRUCTIONS
- E21—EARTH DRILLING; MINING
- E21B—EARTH DRILLING, e.g. DEEP DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
- E21B43/00—Methods or apparatus for obtaining oil, gas, water, soluble or meltable materials or a slurry of minerals from wells
- E21B43/02—Subsoil filtering
- E21B43/10—Setting of casings, screens, liners or the like in wells
-
- E21B23/002—
-
- E—FIXED CONSTRUCTIONS
- E21—EARTH DRILLING; MINING
- E21B—EARTH DRILLING, e.g. DEEP DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
- E21B23/00—Apparatus for displacing, setting, locking, releasing, or removing tools, packers or the like in the boreholes or wells
- E21B23/08—Introducing or running tools by fluid pressure, e.g. through-the-flow-line tool systems
-
- E—FIXED CONSTRUCTIONS
- E21—EARTH DRILLING; MINING
- E21B—EARTH DRILLING, e.g. DEEP DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
- E21B23/00—Apparatus for displacing, setting, locking, releasing, or removing tools, packers or the like in the boreholes or wells
- E21B23/08—Introducing or running tools by fluid pressure, e.g. through-the-flow-line tool systems
- E21B23/12—Tool diverters
-
- E—FIXED CONSTRUCTIONS
- E21—EARTH DRILLING; MINING
- E21B—EARTH DRILLING, e.g. DEEP DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
- E21B33/00—Sealing or packing boreholes or wells
- E21B33/10—Sealing or packing boreholes or wells in the borehole
- E21B33/13—Methods or devices for cementing, for plugging holes, crevices, or the like
- E21B33/14—Methods or devices for cementing, for plugging holes, crevices, or the like for cementing casings into boreholes
-
- E—FIXED CONSTRUCTIONS
- E21—EARTH DRILLING; MINING
- E21B—EARTH DRILLING, e.g. DEEP DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
- E21B33/00—Sealing or packing boreholes or wells
- E21B33/10—Sealing or packing boreholes or wells in the borehole
- E21B33/13—Methods or devices for cementing, for plugging holes, crevices, or the like
- E21B33/14—Methods or devices for cementing, for plugging holes, crevices, or the like for cementing casings into boreholes
- E21B33/16—Methods or devices for cementing, for plugging holes, crevices, or the like for cementing casings into boreholes using plugs for isolating cement charge; Plugs therefor
- E21B33/165—Cementing plugs specially adapted for being released down-hole
Definitions
- CRT Casing Running Tool
- an oilfield tool includes a Casing Running Tool (CRT) adapted to run casing into a borehole.
- 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.
- a sealant e.g., a cement slurry, a resin, among others
- a method for oilfield borehole preparation 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.
- an oilfield system for running and cementing casing 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.
- FIG. 1 is a schematic of an oilfield tool and borehole with an outermost layer of casing cemented in place, according to an embodiment of the disclosure
- FIGS. 2A-2C are schematics representing exemplary stages of a cementing process using the same oilfield tool for running in casing and cementing, in accordance with an embodiment of the disclosure
- FIGS. 3A-3D are exemplary flowcharts of operational actions for using an oilfield tool for running in casing and cementing the casing in place, in accordance with an embodiment of the disclosure
- FIGS. 4A-4B are schematics of an exemplary dynamic device in reduced diameter and expanded diameter form, in accordance with another embodiment of the disclosure.
- FIG. 5 is a schematic of an oilfield tool in accordance with another embodiment of the disclosure.
- FIG. 1 an exemplary schematic cross-section of an oil well operation is shown with an outer borehole 120 and an inner borehole 125 located in the surface 110 of an oil field.
- the oil field can either be located on land or undersea. Teachings of the current disclosure should not be limited to one of these two applications and/or locations.
- 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.
- both the outer casing 130 and the inner casing 135 are cemented or sealed in place.
- 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 .
- 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.
- an embodiment of the current disclosure uses a single oilfield tool 100 comprising various components.
- a casing running tool (CRT) 160 a dynamic device launching tool 170 , and a swivel 180 are provided to allow the running of the casing and the cementing of the casing without having to derig one tool and rig up another.
- 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 .
- 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.
- these ranges are exemplary and embodiments of this disclosure may differ as appropriate.
- the oilfield tool 100 comprises a dynamic device launching tool 170 .
- 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 .
- 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 .
- 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 FIGS. 4A and 4B ).
- the dynamic device 172 , 174 can expand from a reduced diameter form configured to pass through an initial passageway (e.g., such as the interior passageway of the CRT 162 ) to an expanded diameter form that may substantially seal and/or wipe a circumferential passageway (e.g., such as the interior surface of the inner casing 135 ) that may be approximately three (3) times as larger or larger than the initial passageway.
- the expansion of the dynamic devices 172 , 174 may be due to the removal of the volumetric constraints of the initial passageway, or may be due to mechanical, electrical, or flow assisted operation from reduced to full expansion.
- FIGS. 2A-2C these exemplary illustrations show some of the detail surrounding the cementing operation of the oilfield tool 100 , specifically, cementing casing 230 into borehole 220 .
- casing 230 has been run to a desired depth in borehole 220 located in the surface 210 of an oilfield by oilfield tool 100 .
- first dynamic device 172 was released by first dynamic device release 173 of the dynamic device launching tool 170 .
- 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 .
- the first borehole fluid 252 is displaced via the annulus 240 and removed.
- FIG. 2A shows a point in time in which the first dynamic device 172 is travelling downhole inside the casing 230 .
- 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.
- the first dynamic device 172 has reached a downhole stopping point near the end of casing 230 .
- the second dynamic device 174 has been released so as to follow the quantity of sealant 245 necessary to fill the annulus 240 and to cement the casing 230 in place.
- a second borehole fluid 254 is pumped in via the swivel 180 and fluid inlet 185 and provided by a borehole fluid supply 250 .
- the second borehole fluid 254 may be used to pressure test the casing 230 .
- the second borehole fluid 254 may further be used to increase the pressure inside of the casing 230 , ultimately rupturing a rupture device 178 located in the first dynamic device 172 .
- 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 FIG. 2C .
- 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.
- FIG. 3A this figure illustrates a method of using the oilfield tool 100 .
- the method is shown using exemplary flowchart 300 , according to an embodiment of the current disclosure.
- the flowchart 300 may comprise actions such as configuring an oilfield tool 310 , running casing with the oilfield tool 320 and cementing the casing with the oilfield tool 330 .
- 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 FIG. 3B .
- running casing with the oilfield tool may include additional actions such as making up casing 322 and manipulating casing 324 .
- manipulating casing 324 may include actions such as circulating casing 325 , reciprocating casing 326 , or rotating casing 327 .
- 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.
- 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.
- 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).
- 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.
- sealant may be pumped directly through the top drive and a side entry T-piece used in place of the swivel.
- 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.
- 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.
- float valves in the bottom of the casing can be tested by allowing fluid to pass backwards through them.
- 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.
- FIGS. 4A and 4B illustrate a schematic of an exemplary dynamic device 400 in reduced diameter form ( FIG. 4A ) and expanded diameter form ( FIG. 4B ).
- the dynamic device 400 comprises three or more sets of an inner arm 420 and an outer arm 430 .
- the inner arms 420 may be pivotally coupled with a first block 405 and the outer arms 430 may be pivotally coupled with a second block 415 .
- the first block 405 and the second block 415 may be resiliently and slidably coupled towards one another via a resilient device 410 (shown in this non-limiting example as a spring in an expanded state).
- a distal end of the inner arms 420 may be slidably and pivotally coupled to the body of the outer arms 430 .
- 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 .
- the sealing/wiping/separating component 440 may be a resilient material, fabric, folded structure, or expandable material.
- 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.
- the resilient device 410 in an expanded state, providing a contracting force on the first block 405 and the second block 410 .
- the dynamic device 400 may be retained in this reduced diameter form due to the limitations of space provided by the inner passageways of the dynamic device launching tool for example. Other systems or methods of maintaining the dynamic device 400 in a reduced diameter form may be used as appropriate.
- the outer arms 430 and consequently, portions of the sealing/wiping component 440 may be in contact with the inner surfaces of the inner passageways or storage locations of the dynamic device launching tool.
- 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.
- the resilient device 410 motivates the outer arms 430 and sealing/wiping/separating component 440 radially outward.
- the outer arms 430 and the sealing/wiping/separating component 440 are then able to engage the inner surface of the casing substantially circumferentially.
- the ratio between the outermost dimension 450 of the contracted dynamic device 400 in reduced diameter form shown in FIG. 4A and the outermost dimension 455 of the expanded dynamic device 400 in expanded diameter form shown in FIG. 4B can be a factor of about three or larger.
- an in-line launching component such as a modified cement head 570 takes the place of the dynamic device launching tool 170 .
- the modified cement head 570 is coupled to a swivel 580 and CRT 160 .
- the modified cement head 570 comprises a first dynamic device 572 and a second dynamic device 574 .
- the modified cement head 570 further comprises a sealant inlet 576 and a borehole fluid inlet 578 .
- the modified cement head 570 may be coupled to a side entry T-piece (not shown) in place of the swivel 580 .
- a sealant supply engaged to the sealant inlet 576 introduces sealant into the oilfield tool 500 .
- 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 .
- borehole fluid is provided via the borehole fluid inlet 578 .
- the second dynamic device 574 is released and provides a separation or barrier between the sealant and the introduced borehole fluid.
- separation of fluids may be the only function of the second dynamic device 574 .
- 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.
- 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.
Abstract
Description
- 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:
-
FIG. 1 is a schematic of an oilfield tool and borehole with an outermost layer of casing cemented in place, according to an embodiment of the disclosure; -
FIGS. 2A-2C are schematics representing exemplary stages of a cementing process using the same oilfield tool for running in casing and cementing, in accordance with an embodiment of the disclosure; -
FIGS. 3A-3D are exemplary flowcharts of operational actions for using an oilfield tool for running in casing and cementing the casing in place, in accordance with an embodiment of the disclosure; -
FIGS. 4A-4B are schematics of an exemplary dynamic device in reduced diameter and expanded diameter form, in accordance with another embodiment of the disclosure; and -
FIG. 5 is a schematic of an oilfield tool in accordance with another embodiment of the disclosure. - 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
FIG. 1 , an exemplary schematic cross-section of an oil well operation is shown with anouter borehole 120 and aninner borehole 125 located in thesurface 110 of an oil field. The oil field can either be located on land or undersea. Teachings of the current disclosure should not be limited to one of these two applications and/or locations. - To prevent the collapse of the
boreholes outer casing 130 and aninner casing 135 have been run into the boreholes. Although twocasings outer casing 130 has been cemented into theouter borehole 120. - Cementing results in the
outer sealant 140 filling theouter annulus 150 located between the exterior wall of theouter casing 130 and the interior wall of theouter borehole 120. Cementing theouter casing 130 helps in securing theouter casing 130 in place and in sealing the formation surrounding theouter casing 130, and sealing theouter annulus 150, among other reasons. - Generally, both the
outer casing 130 and theinner casing 135 are cemented or sealed in place. However, theinner casing 135 has not been depicted as cemented in order to show in more detail how theouter sealant 140, formed during the cementing of theouter casing 130, is drilled through during the formation of theinner borehole 125. After running theinner casing 135 into theinner borehole 125, the resulting space surrounding the exterior of theinner casing 135 and the interior of theouter casing 130 and the exterior wall of theinner borehole 125 is theinner 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
FIG. 1 , an embodiment of the current disclosure uses asingle oilfield tool 100 comprising various components. In one case, a casing running tool (CRT) 160, a dynamicdevice launching tool 170, and aswivel 180 are provided to allow the running of the casing and the cementing of the casing without having to derig one tool and rig up another. - A
swivel 180 is shown in this exemplary embodiment for applications in which rotating of the string is required. In other embodiments, aswivel 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 theswivel 180. - The
CRT 160 is adapted and configured to run casing. TheCRT 160 has a CRTinterior passageway 162 that is of a smaller interior diameter than the interior diameter of theinner casing 135. In some cases, the ratio of the diameter of theinner casing 135 to the diameter of the CRTinterior passageway 162 of theCRT 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 dynamicdevice launching tool 170. In this exemplary embodiment, the dynamicdevice launching tool 170 comprises a firstdynamic device 172, a firstdynamic device release 173, a seconddynamic device 174, and a seconddynamic device release 175. More dynamic devices or less dynamic devices may be used or held by the dynamicdevice launching tool 170 depending upon the application. In some cases, adynamic device device launching tool 170 while theoilfield tool 100 is rigged up. - The
dynamic devices dynamic devices casing 135. In other applications, thedynamic devices dynamic devices - The
swivel 180 may contain an operational interface 187 (e.g., electrical, mechanical, or hydraulic, among others) for operating the dynamicdevice launching tool 170. In some applications, the dynamicdevice launching tool 170 may also be controlled wirelessly (not shown). - The dynamic
device launching tool 170 comprises a dynamic deviceinterior passage 176 communicatively coupled to the CRTinterior passageway 162. Adynamic device dynamic device release inner casing 135 via the dynamic deviceinterior passageway 176 and the CRTinterior passageway 162. - Once within the
inner casing 135, thedynamic device FIGS. 4A and 4B ). Thedynamic device dynamic devices - Operation of the
oilfield tool 100 will be discussed in more detail as follows. - Turning generally to
FIGS. 2A-2C , these exemplary illustrations show some of the detail surrounding the cementing operation of theoilfield tool 100, specifically, cementingcasing 230 intoborehole 220. InFIG. 2A , casing 230 has been run to a desired depth inborehole 220 located in the surface 210 of an oilfield byoilfield tool 100. Without changing theoilfield tool 100, firstdynamic device 172 was released by firstdynamic device release 173 of the dynamicdevice launching tool 170. - A sealant (e.g., cement slurry, resin, among others) 245 provided by
sealant supply 240 via thefluid inlet 185 ofswivel 180 follows the firstdynamic device 172 into thecasing 230. Thesealant 240 and firstdynamic device 172 traverse intocasing 230 via the dynamic deviceinterior passageway 176 and the CRTinterior passageway 162. The firstdynamic device 172 circumferentially expands from a reduced diameter to an expanded diameter in order to substantially separate thesealant 245 from afirst borehole fluid 252. As thesealant 245 is pumped into thecasing 230, thefirst borehole fluid 252 is displaced via theannulus 240 and removed.FIG. 2A shows a point in time in which the firstdynamic device 172 is travelling downhole inside thecasing 230. - At this general time, the second
dynamic device 174 is still retained by the seconddynamic device release 175. The seconddynamic device 174 may be provided when theoilfield tool 100 is made up or added to the dynamicdevice launching tool 170 at some point when required by the cementing operation. - Turning generally now to
FIG. 2B , at the instant shown in the figure, the firstdynamic device 172 has reached a downhole stopping point near the end ofcasing 230. The seconddynamic device 174 has been released so as to follow the quantity ofsealant 245 necessary to fill theannulus 240 and to cement thecasing 230 in place. Asecond borehole fluid 254 is pumped in via theswivel 180 andfluid inlet 185 and provided by aborehole fluid supply 250. Thesecond borehole fluid 254 may be used to pressure test thecasing 230. In addition, thesecond borehole fluid 254 may further be used to increase the pressure inside of thecasing 230, ultimately rupturing arupture device 178 located in the firstdynamic device 172. - The
rupture device 178 may be a rupture disk or the use of rupture-able material. After exceeding a certain pressure, therupture device 178 ruptures, allowing thesealant 245 to flow into theannulus 240 surrounding thecasing 230. Thesecond borehole fluid 254 is pumped into thecasing 230 until thesealant 245 is fully distributed within theannulus 240. In some cases, thesecond borehole fluid 254 will be introduced into thecasing 230 until the seconddynamic device 174 is adjacent to the firstdynamic device 172, as shown inFIG. 2C . - After the
sealant 245 hardens, the first and seconddynamic devices - Referring generally to
FIG. 3A , this figure illustrates a method of using theoilfield tool 100. The method is shown usingexemplary flowchart 300, according to an embodiment of the current disclosure. Theflowchart 300 may comprise actions such as configuring anoilfield tool 310, running casing with theoilfield tool 320 and cementing the casing with theoilfield tool 330. - In some embodiments, the action described as configuring an
oilfield tool 310 can be further detailed as comprising providing aCRT 312, providing a dynamicdevice launching tool 314 and providing aswivel 316, as shown inFIG. 3B . As shown inFIG. 3C , running casing with the oilfield tool may include additional actions such as making upcasing 322 and manipulatingcasing 324. And still further as shown inFIG. 3D , manipulatingcasing 324 may include actions such as circulatingcasing 325, reciprocatingcasing 326, orrotating casing 327. - 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:
-
- a. CRT
- b. dynamic device launching tool comprising first and second dynamic devices
- c. swivel—when rotating the string is required, or a side entry T-piece (not shown) when no rotation of the string is required
- 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
FIGS. 4A and 4B , these figures illustrate a schematic of an exemplarydynamic device 400 in reduced diameter form (FIG. 4A ) and expanded diameter form (FIG. 4B ). InFIG. 4A , thedynamic device 400 comprises three or more sets of aninner arm 420 and anouter arm 430. Theinner arms 420 may be pivotally coupled with afirst block 405 and theouter arms 430 may be pivotally coupled with asecond block 415. Thefirst block 405 and thesecond block 415 may be resiliently and slidably coupled towards one another via a resilient device 410 (shown in this non-limiting example as a spring in an expanded state). - A distal end of the
inner arms 420 may be slidably and pivotally coupled to the body of theouter 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 theouter arm 430. Other mechanisms may be used as appropriate. - The
outer arms 430 may interact with a sealing/wiping/separating component 440 attached around theouter 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
FIG. 4A theresilient device 410 is in an expanded state, providing a contracting force on thefirst block 405 and thesecond block 410. Thedynamic device 400 may be retained in this reduced diameter form due to the limitations of space provided by the inner passageways of the dynamic device launching tool for example. Other systems or methods of maintaining thedynamic device 400 in a reduced diameter form may be used as appropriate. Theouter arms 430 and consequently, portions of the sealing/wiping component 440 may be in contact with the inner surfaces of the inner passageways or storage locations of the dynamic device launching tool. - When the
dynamic device 400 is released, thedynamic device 400 transitions to an expanded diameter form to engage the larger inner circumferential area of the casing. Theouter 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
FIG. 4B , theresilient device 410 motivates theouter arms 430 and sealing/wiping/separating component 440 radially outward. Theouter arms 430 and the sealing/wiping/separating component 440 are then able to engage the inner surface of the casing substantially circumferentially. In some cases, the ratio between theoutermost dimension 450 of the contracteddynamic device 400 in reduced diameter form shown inFIG. 4A and theoutermost dimension 455 of the expandeddynamic device 400 in expanded diameter form shown inFIG. 4B can be a factor of about three or larger. - Referring generally to
FIG. 5 , another embodiment of theoilfield tool 500 is illustrated. In this exemplary embodiment, an in-line launching component such as a modified cement head 570 takes the place of the dynamicdevice launching tool 170. The modified cement head 570 is coupled to aswivel 580 andCRT 160. The modified cement head 570 comprises a firstdynamic device 572 and a second dynamic device 574. The modified cement head 570 further comprises asealant inlet 576 and a boreholefluid inlet 578. In other embodiments in which there is no required significant rotation of the string, the modified cement head 570 may be coupled to a side entry T-piece (not shown) in place of theswivel 580. - After the casing has been run in, a sealant supply engaged to the
sealant inlet 576 introduces sealant into theoilfield tool 500. As the sealant flows through thesealant inlet 576, the firstdynamic device 572 is released ahead of the sealant and travels into the casing below theoilfield tool 500. The firstdynamic 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 firstdynamic 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 theoilfield 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 firstdynamic 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.
Claims (20)
Applications Claiming Priority (2)
Application Number | Priority Date | Filing Date | Title |
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EP17167725 | 2017-04-24 | ||
EP17167725.5 | 2017-04-24 |
Publications (1)
Publication Number | Publication Date |
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US20180371881A1 true US20180371881A1 (en) | 2018-12-27 |
Family
ID=58632248
Family Applications (1)
Application Number | Title | Priority Date | Filing Date |
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US15/960,658 Abandoned US20180371881A1 (en) | 2017-04-24 | 2018-04-24 | Tool, method and system for well services |
Country Status (1)
Country | Link |
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US (1) | US20180371881A1 (en) |
-
2018
- 2018-04-24 US US15/960,658 patent/US20180371881A1/en not_active Abandoned
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