US20080223587A1 - Ball injecting apparatus for wellbore operations - Google Patents
Ball injecting apparatus for wellbore operations Download PDFInfo
- Publication number
- US20080223587A1 US20080223587A1 US12/049,140 US4914008A US2008223587A1 US 20080223587 A1 US20080223587 A1 US 20080223587A1 US 4914008 A US4914008 A US 4914008A US 2008223587 A1 US2008223587 A1 US 2008223587A1
- Authority
- US
- United States
- Prior art keywords
- ball
- magazine
- wellbore
- subsequent
- transverse port
- 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
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
- E21B33/00—Sealing or packing boreholes or wells
- E21B33/02—Surface sealing or packing
- E21B33/03—Well heads; Setting-up thereof
- E21B33/068—Well heads; Setting-up thereof having provision for introducing objects or fluids into, or removing objects from, wells
Definitions
- This invention relates generally to apparatus and method for injecting balls into a wellbore, such as drop balls, frac balls, packer balls and other balls for interacting with downhole tools or for blocking perforations in casing in the wellbore. More particularly, the apparatus and method uses an actuator and ball magazine for controllably releasing balls into a fluid stream which is pumped into the wellbore.
- a series of packers in a packer arrangement is inserted into the wellbore, each of the packers located at intervals for isolating one zone from an adjacent zone. It is known to introduce a drop ball through the wellbore to selectively engage one of the packers in order to block fluid flow therethrough permitting creation of an isolated zone uphole from the packer for subsequent treatment or stimulation. Once the isolated zone has been stimulated, a subsequent drop ball is dropped to block off a subsequent packer, uphole of the previously blocked packer, for isolation and stimulation thereabove. The process is continued until all the desired zones have been stimulated.
- the balls range in diameter from a smallest ball, suitable to block the most downhole packer, to the largest diameter, suitable for blocking the most uphole packer.
- the wellbore is fit with a wellhead including valves and a block, such as a frachead, which provides fluid connections for introducing stimulation fluids including sand, gels and acid treatments into the wellbore.
- a wellhead including valves and a block, such as a frachead, which provides fluid connections for introducing stimulation fluids including sand, gels and acid treatments into the wellbore.
- operators manually introduce drop balls to the wellbore through an auxiliary line, coupled through a valve, to the wellhead.
- the auxiliary line is fit with a valved tee or T-configuration connecting the wellhead to a fluid pumping source and to a ball introduction valve.
- the operator closes off the valve at the wellhead to the auxiliary line, introduces one drop ball and blocks the valved T-configuration.
- the pumping source is pressurized to the auxiliary line and the wellhead valve is opened to introduce the ball. This procedure is repeated manually, one at a time, for each ball.
- This operation requires personnel
- FIG. 1A is a schematic view of a well undergoing stimulation operation using an embodiment of the invention connected to a top of a wellhead and a fanciful representation of downhole tools and zones along the wellbore;
- FIG. 1B is a schematic view of a well undergoing stimulation operation using an embodiment of the invention connected to the wellbore through a fluid line and having a separate fluid pump connected thereto;
- FIG. 1C is a schematic view of a well undergoing stimulation operation using an embodiment of the invention wherein the apparatus is fluidly connected to the stimulation fluid flow line through a bypass;
- FIG. 2 is a side view of a wellhead illustrating typical fracturing fluid side entrances and insertion of a drop ball through the top of a wellhead;
- FIG. 3A is a top, cross-sectional view of a ball magazine and actuator according to an embodiment of the invention, with the wellhead removed for clarity;
- FIG. 3B is an end view of the ball magazine of FIG. 3A along section B-B illustrating a magazine alignment keyway formed therein;
- FIGS. 4A-4D are top cross-sectional views of the ball magazine of FIG. 3 , illustrating the loaded ball magazine and the sequential deployment of three drop balls, a first small ball, a second medium ball and a third large ball, respectively;
- FIGS. 5A-5C are sequential longitudinal plan sectional views of an embodiment of the invention illustrating a system for indicating position of the magazine within the housing, more particularly
- FIG. 5A illustrates a first position wherein no chambers within the magazine are aligned with the wellbore and an indicator rod engages a first indicator pin
- FIG. 5B illustrates a second position wherein a first chamber and ball are aligned with the wellbore and the indicator rod engages a second indicator pin, the first pin having been removed to permit movement of the magazine;
- FIG. 5C illustrates a subsequent position wherein a last chamber and ball are aligned with the wellbore and the indicator rod engages a final indicator pin
- FIG. 6 is a side longitudinal sectional view according to FIG. 5A .
- a ball injecting apparatus can serially inject a first drop ball and subsequent drop balls into a wellbore, such as for actuating downhole tools.
- the apparatus comprises: a magazine housing having an axial bore formed therethrough and a transverse port, the transverse port being adapted for fluidly connecting to the wellbore; a magazine axially movable in the axial bore, the magazine having two or more transverse chambers spaced axially therealong, each chamber being adapted for receiving an individual drop ball therein; and an actuator for axially positioning the magazine within the axial bore between a loaded position where none of the two or more chambers are axially aligned with the transverse port, and an injection position where one selected chamber of the two or more chambers is moved into alignment with the transverse port wherein a drop ball for the selected chamber is injected from the selected chamber and through the transverse port to the wellbore.
- suitable actuator includes a hydraulic ram which can be operated remotely connected by a piston rod to the magazine. A rod can extend
- the apparatus enables a system and methodology for injecting drop balls into a flow passage including systems for operations on wellbores.
- the ball injecting apparatus is provided.
- the first of the two or more of the chambers is loaded with a first drop ball loaded therein and each subsequent chamber having a subsequent drop ball loaded therein.
- the apparatus is mounted so that the transverse port is fluidly connected to the flow passage.
- the actuator is actuated to move the magazine in the magazine housing to axially align the first chamber with the transverse port for injecting the first drop ball from the first chamber and through the transverse port to the flow passage.
- Embodiments of the invention are discussed herein in the context of the actuation of a series of packers within a wellbore for isolating subsequent zones within the formation for fracturing of the zones.
- a series of packers typically use a series of different sized balls for sequential blocking of adjacent packers.
- One of skill in the art however would appreciate that the invention is applicable to any operation requiring the dropping of one or more balls into the wellbore.
- a ball injecting apparatus 1 is fluidly connected to a wellbore 2 for positively introducing a specific ball into a fluid stream for injecting the ball into the wellbore.
- flow passage P is fluidly connected to a wellbore 2 such as through a wellhead 3 .
- the flow passage P can be fluidly connected along a non-tortuous path such as to through a top of the wellhead or an angled port.
- a ball injecting apparatus 1 is fit to the flow passage P and generally comprises a ball magazine 4 loaded with one or more balls 8 and actuator 5 for positioning the magazine 4 for aligning a ball 8 with the flow passage P and assuring injection of the ball.
- the wellhead 3 is connected to pump trucks 6 through a fluid line 7 for supplying a fracturing or stimulation fluid to the wellbore 2 .
- the wellhead 3 can be fit with a frac head or a wellhead isolation tool having a bore sufficiently large to permit the passage of the balls 8 therethrough.
- the pump trucks 6 are generally connected to a blender 9 and treatment fluid tanks 10 through which the components of the fracturing fluid, including sand or other proppant 11 , are blended for delivery through the fluid lines 7 to the wellhead 3 and to the wellbore 2 connected thereto.
- the wellhead 3 forms the flow passage P to the wellbore 2 .
- the ball injecting apparatus 1 is connected to the flow passage P by directly mounting to the wellhead 3 .
- Balls 8 can be injecting directly into the wellhead 3 by gravity or fluid which urges the balls 8 from the magazine 4 and into the flow passage P.
- a flow of fluids F is introduced through flow passage P or other ports in the wellhead to the wellbore 2 therebelow.
- the flow of fluid F can flow through the ball injecting apparatus 1 .
- the ball injecting apparatus 1 can be fluidly connected to the wellhead 3 intermediate a separate fluid supply line 14 and pump 15 for fluidly injecting balls 8 into the flow of fluids F being conducted in the wellbore 2 .
- frac fluid is introduced to the wellbore 3 through side ports 16 in a frac head 17 mounted below the fluid connection of the ball injecting apparatus 1 .
- the ball injecting apparatus 1 and separate fluid supply line 14 are connected to the wellhead 3 at a top port 18 of the wellhead 2 which is substantially in-line with the wellbore 2 .
- the ball injecting apparatus 1 and the flow passage P can be connected through known angled multi-ports (not detailed) of a frac head, typically angled in the range of 30 to 45 degrees.
- the ball injecting apparatus 1 may be fluidly connected to the wellhead 3 through a bypass 19 from a main treatment fluid supply line 20 .
- Valves are provided to route fluids through the bypass 19 to propel the balls 8 from the magazine 4 and along the flow passage P to the wellhead 3 .
- the ball 8 As shown in the wellhead configuration of FIG. 2 , where the ball 8 is introduced along a flow passage P which is generally in-line with wellbore 2 , the ball 8 does not need to change direction and is reliably introduced into the flow of fluids F through the wellhead 3 for delivery down the wellbore.
- the ball injecting apparatus 1 comprises a tubular magazine housing 30 having an axial bore 31 formed therein for receiving the magazine 4 .
- the housing 30 is fit with a transverse port 37 , generally transverse to the axial bore for forming a single point of egress for an injected ball 8 and becomes fluidly connected and contiguous with the flow passage P.
- the transverse port 37 is adapted for fluid connection with a bore 12 of the wellhead 3 ( FIG. 1A ) or intermediate a fluid line 14 , 20 (FIGS. 1 B, 1 C), referred to collectively herein as the flow passage P.
- the transverse port When connected intermediate a flow line 14 , 20 , the transverse port is a flow-though port having fluid connections on opposing sides of the magazine housing 30 .
- the magazine 4 comprises a piston-like linearly-extending body 4 b having two or more of chambers 32 for storing two or more drop balls 8 , one ball per chamber. Each chamber 32 can receive, store and discharge an individual drop ball 8 .
- Each chamber 32 is typically a transverse, substantially cylindrical passageway or bore through the body 4 b for forming entrance and exit openings 33 , 33 .
- the chamber 32 and transverse port 37 are fluidly contiguous with the flow passage P.
- the chambers 32 and the apparatus 1 itself can be sized to accept a range of diameters of balls up to the largest ball required for the particular operation.
- the bore 31 is sealed at opposing ends of the housing 34 , 35 so as to retain fluid pressure in the flow passage P.
- the magazine 4 can be removeably secured in the bore 31 of the magazine housing 30 using quick release unions 36 , 36 such as hammer union assemblies, that permit easy access to the magazine housing 30 to remove, load and replace a loaded magazine 4 .
- the magazine 4 may be secured within the magazine housing 30 using other releasable connections.
- the apparatus 1 is designed to American Petroleum Institute (API) standards for the particular design criteria including pressure and fluid characteristics.
- the magazine housing 30 is fluidly connected to the flow passage P for injecting the one or more balls 8 from the magazine 4 .
- the transverse port 37 forms a contiguous passage between the openings 33 of the ball chambers 32 and the flow passage P.
- the transverse port 37 is formed on opposing sides of the magazine housing 30 .
- the chamber 32 is fluidly connected to the flow passage P, for release of the ball 8 thereto.
- the magazine 4 is reciprocally actuated within the housing's bore 31 for manipulating the magazine 4 axially along the bore 31 so as to sequentially position, or align, each chamber 32 in-line with the transverse port 37 and flow passage P for deploying the drop balls 8 therein.
- the chambers 32 are axially spaced therealong. The chambers 32 can be evenly and axially spaced for ease of indexing the movement of the magazine 4 .
- the magazine 4 is actuated between an initial loaded position (FIGS. 3 A, 4 A), where none of the chambers 32 are aligned with the transverse port 37 , and an injection position ( FIGS. 4B-4D ), where one selected chamber 32 is moved into alignment with the transverse port 37 .
- an injection position FIGS. 4B-4D
- a drop ball 8 for the selected chamber 32 is injected through the transverse port 37 along the flow passage P to the wellbore 2 .
- the magazine 4 is actuated reciprocally axially within the bore 31 by the actuator 5 .
- the magazine 4 itself, and the actuation thereof, is insensitive to the size of the balls.
- Each chamber 32 can be sized for a particular-sized drop ball or similarly sized so as to receive and store one drop balls of a range of balls diameters without interference with the actuation and injection of drop balls therefrom. All chambers 32 can be sized to accommodate the largest diameter of the anticipated drop balls 8 .
- a suitable actuator 5 is a conventional double-acting hydraulic ram 40 having a piston 41 in a cylinder 42 .
- the piston 41 is operatively connected to the magazine 4 , such as through a piston rod 43 .
- a piston rod seal or seals 48 are positioned between the magazine housing 30 and the piston rod 43 wherein the transverse port 37 and wellbore 2 are contained and further are isolated from the actuator 5 .
- ports 44 are provided at opposing ends 45 , 46 of the cylinder 42 for connection to a control valve 47 (connection not illustrated) as understood by one of skill in the art, and which can be actuated remotely.
- FIGS. 4A to 4D Illustrative of the apparatus 1 in operation, as shown in FIGS. 4A to 4D , and in an embodiment of the invention, the magazine 4 is preloaded with three drop balls 8 of different, increasing diameter in three similar-sized, corresponding chambers 32 of the magazine 4 .
- Another embodiment capable of operation with up to five drop balls is illustrated in FIGS. 5A-6 .
- the loaded magazine 4 is inserted into the bore 31 of the magazine housing 30 and the connection 36 is secured.
- the balls 8 of increasing diameter can be differently and incrementally sized to actuate a series of downhole tools fit with corresponding ball seats.
- the preloaded magazine 4 is initially positioned into the magazine housing 30 with no chambers 32 aligned with the transverse port 37 or flow passage P so that no balls 8 are injected until actuated.
- the actuator 5 is actuated to advance the magazine 4 in the magazine housing 30 to position a first chamber 32 a , housing a first, small diameter drop ball 8 a , into alignment with the flow passage P for injecting the ball 8 a therein.
- the ball 8 a can fall under gravity (into the sheet of FIG. 4C ) or otherwise carried by a flow stream if intermediate the flow passage P.
- the first ball 8 a is typically sized to block a first downhole tool.
- the actuator 5 is further actuated to advance the magazine 4 to position a second chamber 32 b , housing a medium diameter drop ball 8 b , into alignment with the flow passage P.
- the first chamber 32 a is now empty, the first ball 8 a having been previously injected into the flow passage P.
- the second ball 8 b is typically sized to block a second downhole tool, uphole from the first downhole tool.
- the actuator 5 is further actuated to advance the magazine 4 to position a third chamber 32 c , housing a third and largest diameter drop ball 8 c , into alignment with the flow passage P.
- the first and second chambers 32 a , 32 b are now empty and, in this embodiment, the first chamber 32 a happens to move axially beyond the flow passage P.
- the third ball 8 c is typically sized to block a third downhole tool, uphole from the second downhole tool.
- the body 4 b passes through the flow passage P and a distal end 49 enters a passage 50 at the distal end 34 of the bore 31 which accepts the axial length of the magazine 4 .
- the distal end 49 of the magazine 4 rests inside the distal end 34 of the bore 31 and can be further supported thereby.
- additional chambers 32 for housing additional balls 8 can be implemented within an extended linear magazine 4 to operate a greater number of downhole tools.
- a length of the magazine housing 30 , the magazine 4 , the passage 50 and the stroke of the actuator 5 is adjusted accordingly.
- an indicator system 60 is provided for confirmation of alignment of a chamber 32 with the flow passage P and further for confirming which of the chambers 32 is aligned with the flow passage P so as to ensure a known drop ball 8 of known size is injected when required.
- the indicator 60 may comprise an electronic indicator 61 for indicating relative position of the magazine and transverse port 37 .
- Such an indicator 60 could include devices between the housing and magazine or on the actuator 5 .
- a magnet 62 and pickup 63 could be arranged on a hydraulic ram 40 or alternatively a graded rod 64 ( FIG. 3A ) connected to the hydraulic cylinder 42 .
- the indicator 60 precisely confirms the selected chamber 32 and drop ball 8 which is positioned for injection downstream.
- the indicator system 60 may comprise an indicator rod 65 extending from an end 66 of the magazine 4 and through the magazine housing 30 opposite the hydraulic ram 40 .
- An indicator rod seal or seals 51 are positioned between the magazine housing 30 and the indicator rod 65 wherein the transverse port 37 and wellbore 2 are contained.
- the indicator rod 65 extends through an indicator housing 67 and includes an indicator disc 68 mounted thereto at a distal end 69 .
- the indicator housing 67 is bored axially therealong with holes 70 at spaced intervals which correspond to the position of each of the chambers 32 in the magazine 4 when each chamber 32 is aligned with the flow passage P.
- Indicator stops or pins 71 can be inserted into the holes 70 against which the indicator disc 68 engages or stops, indicating that a chamber 32 is aligned with the transverse port 37 .
- First and subsequent indicator pins 71 can be sequentially or serially removed, enabling manual advancing the magazine 4 until the rod disk 68 engages each subsequent pin 71 .
- U-shaped pins are illustrated using pairs of holes 70 , for ease of handling, although straight pins, discs and slots or other removable stops could be used.
- the indicator pins 71 may be shear pins. A slight but measurable increase in pressure at the actuator 5 would indicate to an operator that the disc 68 had engaged an indicator pin 71 and that a drop ball 8 had been aligned and dropped into the flow passage P. For releasing a subsequent drop ball 8 , the magazine 4 would then be actuated under sufficient pressure to shear the indicator pin 71 and shift the magazine 4 axially until the indicator disc 68 engaged the next indicator pin 71 .
- sophisticated hydraulic rams 40 could have built-in mechanical or electrical measurement systems effective to indicate when the chambers 32 have been aligned with the flow passage P.
- rotational alignment means 80 are provided for ensuring that the magazine 4 , having two or more parallel and spaced chambers 32 formed therein, remains rotationally oriented during axial manipulation of the magazine 4 for aligning each of the chambers 32 in turn with the transverse port 37 .
- the magazine housing 30 and magazine can have a cross-sectional profile which resists rotation, such as a corresponding polygonal profile, pressure conditions of the wellbore 2 encourage selection of a generally cylindrical housing 30 and magazine 4 . Accordingly, means are provided for preventing rotation of the magazine 6 relative to the magazine housing 30 .
- alignment of the magazine 4 within the magazine housing 30 may be accomplished in a number of different ways including the use of splines, key and keyway combinations, locking nuts and the like.
- the magazine 4 is splined to the magazine housing 30 for retaining proper alignment of the chambers 32 throughout the axial manipulation of the magazine 4 .
- the spline may include a simple key 81 formed within the magazine housing 30 and keyway 82 formed in the magazine 4 .
- the indicator rod housing 67 is formed having a spline 83 extending therealong and the rod disc 68 has a keyway 84 formed therein for preventing rotation of the indicator rod 65 within the rod housing 67 and the magazine 4 connected thereto.
- the indicator rod 65 may be connected to the magazine 4 through a connector employing co-operating polygonal openings and rod end profiles for preventing rotation of the magazine 4 relative to the aligned indicator rod 65 and the magazine 4 attached thereto.
- a system and method for conducting operations on a wellbore 2 are provided.
- the wellbore 2 is fit with two of more downhole tools T 1 ,T 2 ,T 3 , such as packers spaced at intervals along the wellbore for isolation of a first zone and subsequent zones Z 1 ,Z 2 ,Z 3 .
- the system and methodology can implement an embodiment of the ball injecting apparatus 1 of the present invention.
- the ball injecting apparatus 1 is mounted with the transverse port 37 fluidly connected directly atop a stimulation multi-port wellhead 3 .
- a flow F of stimulation fluids 7 can be provided to the wellhead 3 and the apparatus 1 can inject drop balls 8 into the flow path P for delivery down the wellbore 2 .
- operations on the wellbore can include actuating a first packer T 1 for blocking flow therebelow so that stimulation operations can be conducted on a zone Z 1 uphole of that first packer.
- One or more subsequent packers T 2 ,T 3 , . . . Tn are provided uphole of the first packer T 1 .
- the magazine 4 of a hydraulic actuated ball injecting 1 is preloaded with three different sized drop balls 8 a , 8 b , 8 c of increasing diameter required for the stimulation operation.
- the drop balls 8 are loaded into the chambers 32 in the sequence in which they are to be injected. Once all the drop balls 8 are loaded, the magazine 4 is fully engaged within the housing bore 31 and the hammer union 36 or other appropriate connection is secured.
- the actuator 5 is actuated for moving the magazine and axially aligning a first or selected chamber 32 a with the transverse port 37 for injecting the first drop ball 8 a into the flow path P.
- the first drop ball moves downhole, in the wellbore, passing each of the subsequent packers Tn . . . T 3 ,T 2 until it engages the corresponding, first packer T 1 for actuating or blocking the wellbore at the first packer.
- the drop ball 8 a engages a ball seat for isolating the zone Z 1 , in the wellbore uphole of the first packer T 1 , from the wellbore therebelow.
- a new zone is isolated uphole of the first packer.
- the actuator 5 is actuated again for axially aligning a second and subsequent selected chamber 32 b with the transverse port 37 for injecting the subsequent drop ball 8 b into the flow path P.
- the subsequent drop ball 8 b traverses the wellbore 2 , passing each of the subsequent packers Tn . . . T 3 until the ball engages and actuates the corresponding, second and subsequent packer T 2 .
- the drop ball 8 b engages a corresponding ball seat of the subsequent packer T 2 for isolating zone Z 2 uphole of the subsequent packer.
- the actuator 5 can be actuated again for axially aligning yet another subsequent selected chamber 32 c with the transverse port 37 for injecting a third and subsequent drop ball 8 c for actuating the subsequent packer T 3 .
- the system and method is serially repeated for each packer and corresponding drop ball provided.
Abstract
Apparatus is provided injecting drop balls into a wellbore, such as for actuating downhole tools. A ball magazine adapted for storing drop balls, in two or more transverse ball chambers, is axially movable in a magazine housing mounted at a transverse port to a fluid passage in fluid communication with the wellbore. The magazine is serially actuable for aligning a first and subsequent chambers with the transverse port for injecting stored balls to the wellbore. An indicator, such as a rod extending from the magazine housing, can be used to indicate the relative location of the chamber and transverse port. The apparatus can be used in a system and methodology for actuating two or more downhole tools spaced at intervals along the wellbore.
Description
- This application is a regular application claiming priority of U.S. Provisional Patent application Ser. No. 60/895,350, filed on Mar. 16, 2007, the entirety of which is incorporated herein by reference.
- This invention relates generally to apparatus and method for injecting balls into a wellbore, such as drop balls, frac balls, packer balls and other balls for interacting with downhole tools or for blocking perforations in casing in the wellbore. More particularly, the apparatus and method uses an actuator and ball magazine for controllably releasing balls into a fluid stream which is pumped into the wellbore.
- It is known to conduct fracturing or other stimulation procedures in a wellbore by isolating zones in the wellbore using packers and the like and subjecting the isolated zone to treatment fluids at treatment pressures. In a typical fracturing procedure, for example, the casing of the well is perforated to admit oil and/or gas into the well and fracturing fluid is then pumped into the well and through the perforations into the formation. Such treatment opens and/or enlarges draining channels in the formation, enhancing the producing ability of the well.
- It is typically desired to stimulate multiple zones in a single stimulation treatment, typically using onsite stimulation fluid pumping equipment. A series of packers in a packer arrangement is inserted into the wellbore, each of the packers located at intervals for isolating one zone from an adjacent zone. It is known to introduce a drop ball through the wellbore to selectively engage one of the packers in order to block fluid flow therethrough permitting creation of an isolated zone uphole from the packer for subsequent treatment or stimulation. Once the isolated zone has been stimulated, a subsequent drop ball is dropped to block off a subsequent packer, uphole of the previously blocked packer, for isolation and stimulation thereabove. The process is continued until all the desired zones have been stimulated. Typically the balls range in diameter from a smallest ball, suitable to block the most downhole packer, to the largest diameter, suitable for blocking the most uphole packer.
- At surface, the wellbore is fit with a wellhead including valves and a block, such as a frachead, which provides fluid connections for introducing stimulation fluids including sand, gels and acid treatments into the wellbore. Conventionally, operators manually introduce drop balls to the wellbore through an auxiliary line, coupled through a valve, to the wellhead. The auxiliary line is fit with a valved tee or T-configuration connecting the wellhead to a fluid pumping source and to a ball introduction valve. The operator closes off the valve at the wellhead to the auxiliary line, introduces one drop ball and blocks the valved T-configuration. The pumping source is pressurized to the auxiliary line and the wellhead valve is opened to introduce the ball. This procedure is repeated manually, one at a time, for each ball. This operation requires personnel to work in close proximity to the treatment lines through which fluid and balls are pumped at high pressures and rates. The treatment fluid is energized which is highly dangerous.
- Aside from being a generally dangerous practice, other operational problems have occurred, such as valves malfunctioning and balls becoming stuck and not being pumped downhole. These problems have resulted in failed well treatment operations, requiring re-working which is very costly and inefficient. At times re-working of a well formation following an unsuccessful stimulation treatment may not be successful, which results in production loss.
- Other alternative methods and apparatus for the introduction of the drop balls have included an array of remote valves positioned onto a multi-port connection at the wellhead with a single ball positioned behind each valve. Each valve requires a separate manifold fluid pumper line and precise coordination both to ensure the ball is deployed and to ensure each ball is deployed at the right time in the sequence, throughout the stimulation operation. The multi-port arrangement, although workable, has proven to be very costly and inefficient. Further, this arrangement is dangerous to personnel due to the multiplicity of lines under high pressure connected to the top the wellhead during the stimulation operation. It is known to feed a plurality of perforation-sealing balls using an automated device as set forth in U.S. Pat. No. 4,132,243 to Kuus. Same-sized balls are used sealing perforations and are amenable feeding one by one from a stack of balls. The apparatus appears limited to same-sized balls and there is not positive identification whether a ball was successfully indexed from the stack for injection.
- There remains a need for a safe, efficient and remotely operated apparatus and mechanism for introducing drop balls to a wellbore.
-
FIG. 1A is a schematic view of a well undergoing stimulation operation using an embodiment of the invention connected to a top of a wellhead and a fanciful representation of downhole tools and zones along the wellbore; -
FIG. 1B is a schematic view of a well undergoing stimulation operation using an embodiment of the invention connected to the wellbore through a fluid line and having a separate fluid pump connected thereto; -
FIG. 1C is a schematic view of a well undergoing stimulation operation using an embodiment of the invention wherein the apparatus is fluidly connected to the stimulation fluid flow line through a bypass; -
FIG. 2 is a side view of a wellhead illustrating typical fracturing fluid side entrances and insertion of a drop ball through the top of a wellhead; -
FIG. 3A is a top, cross-sectional view of a ball magazine and actuator according to an embodiment of the invention, with the wellhead removed for clarity; -
FIG. 3B is an end view of the ball magazine ofFIG. 3A along section B-B illustrating a magazine alignment keyway formed therein; -
FIGS. 4A-4D are top cross-sectional views of the ball magazine ofFIG. 3 , illustrating the loaded ball magazine and the sequential deployment of three drop balls, a first small ball, a second medium ball and a third large ball, respectively; -
FIGS. 5A-5C are sequential longitudinal plan sectional views of an embodiment of the invention illustrating a system for indicating position of the magazine within the housing, more particularly -
FIG. 5A illustrates a first position wherein no chambers within the magazine are aligned with the wellbore and an indicator rod engages a first indicator pin; -
FIG. 5B illustrates a second position wherein a first chamber and ball are aligned with the wellbore and the indicator rod engages a second indicator pin, the first pin having been removed to permit movement of the magazine; and -
FIG. 5C illustrates a subsequent position wherein a last chamber and ball are aligned with the wellbore and the indicator rod engages a final indicator pin; and -
FIG. 6 is a side longitudinal sectional view according toFIG. 5A . - According to embodiments of the invention, a ball injecting apparatus can serially inject a first drop ball and subsequent drop balls into a wellbore, such as for actuating downhole tools. The apparatus comprises: a magazine housing having an axial bore formed therethrough and a transverse port, the transverse port being adapted for fluidly connecting to the wellbore; a magazine axially movable in the axial bore, the magazine having two or more transverse chambers spaced axially therealong, each chamber being adapted for receiving an individual drop ball therein; and an actuator for axially positioning the magazine within the axial bore between a loaded position where none of the two or more chambers are axially aligned with the transverse port, and an injection position where one selected chamber of the two or more chambers is moved into alignment with the transverse port wherein a drop ball for the selected chamber is injected from the selected chamber and through the transverse port to the wellbore. As suitable actuator includes a hydraulic ram which can be operated remotely connected by a piston rod to the magazine. A rod can extend from the magazine and through the magazine housing for indicating the relative position of the chambers and the transverse port. Sensors can complement the indicator.
- The apparatus enables a system and methodology for injecting drop balls into a flow passage including systems for operations on wellbores. The ball injecting apparatus is provided. The first of the two or more of the chambers is loaded with a first drop ball loaded therein and each subsequent chamber having a subsequent drop ball loaded therein. The apparatus is mounted so that the transverse port is fluidly connected to the flow passage. The actuator is actuated to move the magazine in the magazine housing to axially align the first chamber with the transverse port for injecting the first drop ball from the first chamber and through the transverse port to the flow passage. As needed, one serially repeats the actuating step for each subsequent chamber for serially injecting each of the subsequent drop balls from the subsequent chambers.
- Embodiments of the invention are discussed herein in the context of the actuation of a series of packers within a wellbore for isolating subsequent zones within the formation for fracturing of the zones. A series of packers typically use a series of different sized balls for sequential blocking of adjacent packers. One of skill in the art however would appreciate that the invention is applicable to any operation requiring the dropping of one or more balls into the wellbore.
- It has been known to drop a ball from surface through a tubular in a wellbore and into a seat of a downhole tool for blocking flow and permitting changes in pumped pressure to actuate downhole equipment such as movement of a sliding sleeve, opening and closing of a port, movement of a valves, fracturing of a frangible element, release of cementing wiper plugs, control of downhole packers, sealing perforations and the like. The diameter of the ball and the sequence of the release one or more drop balls into the wellbore is relevant to actuation of a series of packers for operations which can include as fracturing, acid stimulation and other stimulation procedures directed to zones of interest within the formation surrounding the wellbore.
- In embodiments of the invention, a ball injecting apparatus 1 is fluidly connected to a
wellbore 2 for positively introducing a specific ball into a fluid stream for injecting the ball into the wellbore. - In embodiments of the invention, as shown in
FIGS. 1A-1C and 3A, flow passage P is fluidly connected to awellbore 2 such as through awellhead 3. To minimize the risk of ball hang-up, the flow passage P can be fluidly connected along a non-tortuous path such as to through a top of the wellhead or an angled port. A ball injecting apparatus 1 is fit to the flow passage P and generally comprises aball magazine 4 loaded with one ormore balls 8 andactuator 5 for positioning themagazine 4 for aligning aball 8 with the flow passage P and assuring injection of the ball. - With reference to
FIGS. 1A-1C , and in the context of fracturing or treating sequential zones within a formation accessed by thewellbore 2, thewellhead 3 is connected to pumptrucks 6 through afluid line 7 for supplying a fracturing or stimulation fluid to thewellbore 2. Thewellhead 3 can be fit with a frac head or a wellhead isolation tool having a bore sufficiently large to permit the passage of theballs 8 therethrough. Thepump trucks 6 are generally connected to a blender 9 andtreatment fluid tanks 10 through which the components of the fracturing fluid, including sand or other proppant 11, are blended for delivery through thefluid lines 7 to thewellhead 3 and to thewellbore 2 connected thereto. Thewellhead 3 forms the flow passage P to thewellbore 2. - As shown in the embodiment of
FIG. 1A , the ball injecting apparatus 1 is connected to the flow passage P by directly mounting to thewellhead 3.Balls 8 can be injecting directly into thewellhead 3 by gravity or fluid which urges theballs 8 from themagazine 4 and into the flow passage P. In many instances, a flow of fluids F is introduced through flow passage P or other ports in the wellhead to thewellbore 2 therebelow. By injecting theball 8 directly into the flow passage P to join the flow fluid F one avoids accidental lodging of theball 8 in side ports or other cavities such as in some prior art T-configuration injection apparatus. - Alternatively, as shown in
FIG. 1B , the flow of fluid F can flow through the ball injecting apparatus 1. The ball injecting apparatus 1 can be fluidly connected to thewellhead 3 intermediate a separate fluid supply line 14 and pump 15 for fluidly injectingballs 8 into the flow of fluids F being conducted in thewellbore 2. In an embodiment of the invention, frac fluid is introduced to thewellbore 3 through side ports 16 in afrac head 17 mounted below the fluid connection of the ball injecting apparatus 1. The ball injecting apparatus 1 and separate fluid supply line 14 are connected to thewellhead 3 at atop port 18 of thewellhead 2 which is substantially in-line with thewellbore 2. The ball injecting apparatus 1 and the flow passage P can be connected through known angled multi-ports (not detailed) of a frac head, typically angled in the range of 30 to 45 degrees. - Further, as shown in the embodiment of
FIG. 1C , and particularly in the case of operations for injecting fluids containing no proppant, the ball injecting apparatus 1 may be fluidly connected to thewellhead 3 through a bypass 19 from a main treatmentfluid supply line 20. Valves are provided to route fluids through the bypass 19 to propel theballs 8 from themagazine 4 and along the flow passage P to thewellhead 3. - As shown in the wellhead configuration of
FIG. 2 , where theball 8 is introduced along a flow passage P which is generally in-line withwellbore 2, theball 8 does not need to change direction and is reliably introduced into the flow of fluids F through thewellhead 3 for delivery down the wellbore. - Generally, as shown in
FIGS. 3A and 3B , and in embodiments of the invention, the ball injecting apparatus 1 comprises atubular magazine housing 30 having anaxial bore 31 formed therein for receiving themagazine 4. Thehousing 30 is fit with atransverse port 37, generally transverse to the axial bore for forming a single point of egress for an injectedball 8 and becomes fluidly connected and contiguous with the flow passage P. Thetransverse port 37 is adapted for fluid connection with abore 12 of the wellhead 3 (FIG. 1A ) or intermediate a fluid line 14,20 (FIGS. 1B,1C), referred to collectively herein as the flow passage P. When connected intermediate aflow line 14,20, the transverse port is a flow-though port having fluid connections on opposing sides of themagazine housing 30. Themagazine 4 comprises a piston-like linearly-extending body 4 b having two or more ofchambers 32 for storing two ormore drop balls 8, one ball per chamber. Eachchamber 32 can receive, store and discharge anindividual drop ball 8. Eachchamber 32 is typically a transverse, substantially cylindrical passageway or bore through the body 4 b for forming entrance andexit openings chamber 32 is axially and rotationally aligned with thetransverse port 37, thechamber 32 andtransverse port 37 are fluidly contiguous with the flow passage P. Thechambers 32 and the apparatus 1 itself can be sized to accept a range of diameters of balls up to the largest ball required for the particular operation. - The
bore 31 is sealed at opposing ends of thehousing magazine 4 can be removeably secured in thebore 31 of themagazine housing 30 usingquick release unions magazine housing 30 to remove, load and replace a loadedmagazine 4. Alternatively themagazine 4 may be secured within themagazine housing 30 using other releasable connections. The apparatus 1 is designed to American Petroleum Institute (API) standards for the particular design criteria including pressure and fluid characteristics. Themagazine housing 30 is fluidly connected to the flow passage P for injecting the one ormore balls 8 from themagazine 4. - Best shown in
FIG. 6 , in embodiments of the invention, thetransverse port 37 forms a contiguous passage between theopenings 33 of theball chambers 32 and the flow passage P. In the case where the apparatus 1 is mounted intermediate a fluid flow line 14,20 (FIGS. 1B and 1C ) connected to the flow passage P, thetransverse port 37 is formed on opposing sides of themagazine housing 30. When one of the chambers' is axially aligned with thetransverse port 37, thechamber 32 is fluidly connected to the flow passage P, for release of theball 8 thereto. Where an axis CA of each of the two ofmore chambers 32 is parallel to the axis of eachother chamber 32, mere axial positioning of themagazine 4 will align each chamber in turn with thetransverse port 37. In the case where the apparatus 1 is connected directly to the wellhead 3 (FIG. 1A ), thedrop balls 8 can dropped out of thetransverse port 37 by gravity and directly into thewellhead 3. - The
magazine 4 is reciprocally actuated within the housing'sbore 31 for manipulating themagazine 4 axially along thebore 31 so as to sequentially position, or align, eachchamber 32 in-line with thetransverse port 37 and flow passage P for deploying thedrop balls 8 therein. Thechambers 32 are axially spaced therealong. Thechambers 32 can be evenly and axially spaced for ease of indexing the movement of themagazine 4. - The
magazine 4 is actuated between an initial loaded position (FIGS. 3A,4A), where none of thechambers 32 are aligned with thetransverse port 37, and an injection position (FIGS. 4B-4D ), where one selectedchamber 32 is moved into alignment with thetransverse port 37. When aligned, adrop ball 8 for the selectedchamber 32 is injected through thetransverse port 37 along the flow passage P to thewellbore 2. - The
magazine 4 is actuated reciprocally axially within thebore 31 by theactuator 5. Themagazine 4 itself, and the actuation thereof, is insensitive to the size of the balls. Eachchamber 32 can be sized for a particular-sized drop ball or similarly sized so as to receive and store one drop balls of a range of balls diameters without interference with the actuation and injection of drop balls therefrom. Allchambers 32 can be sized to accommodate the largest diameter of theanticipated drop balls 8. - A
suitable actuator 5 is a conventional double-acting hydraulic ram 40 having a piston 41 in acylinder 42. The piston 41 is operatively connected to themagazine 4, such as through a piston rod 43. A piston rod seal or seals 48 are positioned between themagazine housing 30 and the piston rod 43 wherein thetransverse port 37 andwellbore 2 are contained and further are isolated from theactuator 5. As shown inFIG. 3A ,ports 44 are provided at opposing ends 45,46 of thecylinder 42 for connection to a control valve 47 (connection not illustrated) as understood by one of skill in the art, and which can be actuated remotely. - Illustrative of the apparatus 1 in operation, as shown in
FIGS. 4A to 4D , and in an embodiment of the invention, themagazine 4 is preloaded with threedrop balls 8 of different, increasing diameter in three similar-sized, correspondingchambers 32 of themagazine 4. Another embodiment capable of operation with up to five drop balls is illustrated inFIGS. 5A-6 . - With reference to
FIGS. 4A-4D , the loadedmagazine 4 is inserted into thebore 31 of themagazine housing 30 and theconnection 36 is secured. Theballs 8 of increasing diameter can be differently and incrementally sized to actuate a series of downhole tools fit with corresponding ball seats. As shown inFIG. 4A , thepreloaded magazine 4 is initially positioned into themagazine housing 30 with nochambers 32 aligned with thetransverse port 37 or flow passage P so that noballs 8 are injected until actuated. - Subsequently, as shown in
FIG. 4B , theactuator 5 is actuated to advance themagazine 4 in themagazine housing 30 to position afirst chamber 32 a, housing a first, smalldiameter drop ball 8 a, into alignment with the flow passage P for injecting theball 8 a therein. Theball 8 a can fall under gravity (into the sheet ofFIG. 4C ) or otherwise carried by a flow stream if intermediate the flow passage P. Thefirst ball 8 a is typically sized to block a first downhole tool. - As shown in
FIG. 4C , theactuator 5 is further actuated to advance themagazine 4 to position asecond chamber 32 b, housing a medium diameter drop ball 8 b, into alignment with the flow passage P. Note thefirst chamber 32 a is now empty, thefirst ball 8 a having been previously injected into the flow passage P. The second ball 8 b is typically sized to block a second downhole tool, uphole from the first downhole tool. - As shown in
FIG. 4D , theactuator 5 is further actuated to advance themagazine 4 to position a third chamber 32 c, housing a third and largestdiameter drop ball 8 c, into alignment with the flow passage P. Note the first andsecond chambers first chamber 32 a happens to move axially beyond the flow passage P. Thethird ball 8 c is typically sized to block a third downhole tool, uphole from the second downhole tool. - As the
magazine 4 is serially actuated, the body 4 b passes through the flow passage P and adistal end 49 enters a passage 50 at thedistal end 34 of thebore 31 which accepts the axial length of themagazine 4. Thedistal end 49 of themagazine 4 rests inside thedistal end 34 of thebore 31 and can be further supported thereby. - As shown in
FIGS. 5A-6 ,additional chambers 32 for housingadditional balls 8 can be implemented within an extendedlinear magazine 4 to operate a greater number of downhole tools. A length of themagazine housing 30, themagazine 4, the passage 50 and the stroke of theactuator 5 is adjusted accordingly. - In embodiments of the invention of
FIGS. 3A-6 , anindicator system 60 is provided for confirmation of alignment of achamber 32 with the flow passage P and further for confirming which of thechambers 32 is aligned with the flow passage P so as to ensure a knowndrop ball 8 of known size is injected when required. - As shown in
FIG. 3A theindicator 60 may comprise anelectronic indicator 61 for indicating relative position of the magazine andtransverse port 37. Such anindicator 60 could include devices between the housing and magazine or on theactuator 5. For example, a magnet 62 andpickup 63 could be arranged on a hydraulic ram 40 or alternatively a graded rod 64 (FIG. 3A ) connected to thehydraulic cylinder 42. Theindicator 60 precisely confirms the selectedchamber 32 and dropball 8 which is positioned for injection downstream. - As shown in
FIGS. 5A-5C and 6, theindicator system 60 may comprise anindicator rod 65 extending from an end 66 of themagazine 4 and through themagazine housing 30 opposite the hydraulic ram 40. An indicator rod seal or seals 51 are positioned between themagazine housing 30 and theindicator rod 65 wherein thetransverse port 37 andwellbore 2 are contained. - In an embodiment, the
indicator rod 65 extends through anindicator housing 67 and includes anindicator disc 68 mounted thereto at a distal end 69. Theindicator housing 67 is bored axially therealong withholes 70 at spaced intervals which correspond to the position of each of thechambers 32 in themagazine 4 when eachchamber 32 is aligned with the flow passage P. - Indicator stops or pins 71 can be inserted into the
holes 70 against which theindicator disc 68 engages or stops, indicating that achamber 32 is aligned with thetransverse port 37. First and subsequent indicator pins 71 can be sequentially or serially removed, enabling manual advancing themagazine 4 until therod disk 68 engages each subsequent pin 71. U-shaped pins are illustrated using pairs ofholes 70, for ease of handling, although straight pins, discs and slots or other removable stops could be used. - Alternatively, the indicator pins 71 may be shear pins. A slight but measurable increase in pressure at the
actuator 5 would indicate to an operator that thedisc 68 had engaged an indicator pin 71 and that adrop ball 8 had been aligned and dropped into the flow passage P. For releasing asubsequent drop ball 8, themagazine 4 would then be actuated under sufficient pressure to shear the indicator pin 71 and shift themagazine 4 axially until theindicator disc 68 engaged the next indicator pin 71. - In the embodiment of
FIGS. 5A-5C , as opposed to that shown inFIG. 3A , the addition of theindicator rod system 60, through theindicator seal 51 at the opposite end 66 of themagazine housing 30 to the hydraulic ram 40, acts to balance the fluid force on the piston rod 43. Thus, lower forces are required to advance the piston 41 andmagazine 4, reducing stress on the moving components. Further, only asmall cylinder 42 is then required which acts to reduce the weight of the ball injecting apparatus 1. - Optionally, sophisticated hydraulic rams 40 could have built-in mechanical or electrical measurement systems effective to indicate when the
chambers 32 have been aligned with the flow passage P. - With reference to
FIGS. 3A , 3B, 4C and 5C, in embodiments of the invention, rotational alignment means 80 are provided for ensuring that themagazine 4, having two or more parallel and spacedchambers 32 formed therein, remains rotationally oriented during axial manipulation of themagazine 4 for aligning each of thechambers 32 in turn with thetransverse port 37. While themagazine housing 30 and magazine can have a cross-sectional profile which resists rotation, such as a corresponding polygonal profile, pressure conditions of thewellbore 2 encourage selection of a generallycylindrical housing 30 andmagazine 4. Accordingly, means are provided for preventing rotation of themagazine 6 relative to themagazine housing 30. One of skill in the art would appreciate that alignment of themagazine 4 within themagazine housing 30 may be accomplished in a number of different ways including the use of splines, key and keyway combinations, locking nuts and the like. - As shown in FIGS. 3A,3B and in an embodiment of the invention, the
magazine 4 is splined to themagazine housing 30 for retaining proper alignment of thechambers 32 throughout the axial manipulation of themagazine 4. As shown, the spline may include a simple key 81 formed within themagazine housing 30 andkeyway 82 formed in themagazine 4. - Alternately, in an embodiment as shown in
FIGS. 5A-5C , theindicator rod housing 67 is formed having a spline 83 extending therealong and therod disc 68 has a keyway 84 formed therein for preventing rotation of theindicator rod 65 within therod housing 67 and themagazine 4 connected thereto. Further, theindicator rod 65 may be connected to themagazine 4 through a connector employing co-operating polygonal openings and rod end profiles for preventing rotation of themagazine 4 relative to the alignedindicator rod 65 and themagazine 4 attached thereto. - With reference to FIGS. 1A and 4A-4D, a system and method for conducting operations on a
wellbore 2 are provided. Thewellbore 2 is fit with two of more downhole tools T1,T2,T3, such as packers spaced at intervals along the wellbore for isolation of a first zone and subsequent zones Z1,Z2,Z3. The system and methodology can implement an embodiment of the ball injecting apparatus 1 of the present invention. - With assistance of the embodiment illustrated in
FIG. 1A , the ball injecting apparatus 1 is mounted with thetransverse port 37 fluidly connected directly atop a stimulationmulti-port wellhead 3. A flow F ofstimulation fluids 7 can be provided to thewellhead 3 and the apparatus 1 can injectdrop balls 8 into the flow path P for delivery down thewellbore 2. As is known by those of skill in the art, operations on the wellbore can include actuating a first packer T1 for blocking flow therebelow so that stimulation operations can be conducted on a zone Z1 uphole of that first packer. One or more subsequent packers T2,T3, . . . Tn are provided uphole of the first packer T1. - As shown in
FIG. 4A , themagazine 4 of a hydraulic actuated ball injecting 1 is preloaded with three differentsized drop balls magazine 4 is incrementally inserted into themagazine housing 30 thedrop balls 8 are loaded into thechambers 32 in the sequence in which they are to be injected. Once all thedrop balls 8 are loaded, themagazine 4 is fully engaged within the housing bore 31 and thehammer union 36 or other appropriate connection is secured. - As shown in
FIG. 4B , theactuator 5 is actuated for moving the magazine and axially aligning a first or selectedchamber 32 a with thetransverse port 37 for injecting thefirst drop ball 8 a into the flow path P. The first drop ball moves downhole, in the wellbore, passing each of the subsequent packers Tn . . . T3,T2 until it engages the corresponding, first packer T1 for actuating or blocking the wellbore at the first packer. Thedrop ball 8 a engages a ball seat for isolating the zone Z1, in the wellbore uphole of the first packer T1, from the wellbore therebelow. - Once stimulation for the zone Z1 above the first packer T1 is complete, a new zone is isolated uphole of the first packer. As shown in
FIG. 4C , theactuator 5 is actuated again for axially aligning a second and subsequent selectedchamber 32 b with thetransverse port 37 for injecting the subsequent drop ball 8 b into the flow path P. The subsequent drop ball 8 b traverses thewellbore 2, passing each of the subsequent packers Tn . . . T3 until the ball engages and actuates the corresponding, second and subsequent packer T2. The drop ball 8 b engages a corresponding ball seat of the subsequent packer T2 for isolating zone Z2 uphole of the subsequent packer. - If there is a need and yet another subsequent packer, the
actuator 5 can be actuated again for axially aligning yet another subsequent selected chamber 32 c with thetransverse port 37 for injecting a third andsubsequent drop ball 8 c for actuating the subsequent packer T3. - The system and method is serially repeated for each packer and corresponding drop ball provided.
Claims (24)
1. A ball injecting apparatus for injecting drop balls into a wellbore comprising:
a magazine housing having an axial bore formed therethrough and a transverse port, the transverse port being adapted for fluidly connecting to the wellbore;
a magazine axially movable in the axial bore, the magazine having two or more transverse chambers spaced axially therealong, each chamber being adapted for receiving an individual drop ball therein; and
an actuator for axially positioning the magazine within the axial bore between a loaded position where none of the two or more chambers are axially aligned with the transverse port, and an injection position where one selected chamber of the two or more chambers is moved into alignment with the transverse port wherein a drop ball for the selected chamber is injected from the selected chamber and through the transverse port to the wellbore.
2. The ball injecting apparatus of claim 1 wherein each chamber is a transverse, substantially cylindrical bore through the magazine which is parallel and axially spaced from each other chamber.
3. The ball injecting apparatus of claim 2 wherein the magazine is rotationally constrained for maintaining rotational alignment of the selected chamber with the transverse port.
4. The ball injecting apparatus of claim 3 further comprising rotational alignment means for rotationally aligning the magazine and the magazine housing.
5. The ball injecting apparatus of claim 4 wherein the rotational alignment means is a co-operating key and keyway between the magazine housing and the magazine.
6. The ball injecting apparatus of claim 4 wherein the rotational alignment means is a co-operating key and keyway on the actuator.
7. The ball injecting apparatus of claim 1 further comprising:
an indicator rod extending from an end of the magazine opposite to the actuator, the indicator rod extending axially through the housing; and
an indicator seal between the housing and the indicator rod.
8. The ball injecting apparatus of claim 1 further comprising an indicator for signaling the position of the selected chamber.
9. The ball injecting apparatus of claim 8 wherein the indicator is an electronic sensor for sensing relative position of the magazine with respect to the housing.
10. The ball injecting apparatus of claim 8 wherein the indicator comprises:
an indicator rod extending from an end of the magazine opposite to the actuator, the indicator rod extending axially through the magazine housing;
an indicator seal between the housing and the indicator rod;
an indicator disc at a distal end of the indicator rod;
an indicator housing extending about the indicator rod and fixed relative to the magazine housing;
a plurality of holes bored through the housing each of which is axial spaced at intervals to correspond to the axial spacing of the two or more chambers in the magazine; and
removable stop pins for positioning in the plurality of holes along the indicator housing and acting between the indicator disc and the indicator housing for engaging the indicator disc thereagainst for signaling when one of the one or more chambers is aligned with the transverse port.
11. The ball injecting apparatus of claim 10 wherein the pins are shear pins acting between the indicator disc and the indicator housing, the actuator being actuatable to cause one of the shear pins to shear and permit movement of the magazine to a subsequent shear pin to axially align the selected chamber with the transverse port.
12. The ball injecting apparatus of claim 1 wherein the two or more chambers are similarly sized.
13. The ball injecting apparatus of claim 1 wherein each chamber is axially and equally spaced from each other chamber.
14. The ball injecting apparatus of claim 1 wherein the actuator comprises a double-acting hydraulic ram having a piston in a cylinder, the piston being operatively connected to the magazine.
15. The ball injecting apparatus of claim 14 wherein the piston is connected to magazine by a piston rod.
16. The ball injecting apparatus of claim 15 further comprising a piston rod seal between the magazine housing and the piston rod wherein the wellbore is isolated from the actuator.
17. A method for injecting drop balls into a flow passage comprising:
providing a ball injecting apparatus having
a magazine housing having an axial bore formed therethrough and a transverse port, the transverse port being adapted for fluidly connecting to the wellbore;
a magazine axially movable in the axial bore, the magazine having two or more transverse chambers spaced axially therealong, a first of the two or more of the chambers having a first drop ball loaded therein and each subsequent chamber having a subsequent drop ball loaded therein; and
an actuator for axially positioning the magazine within the axial bore between a loaded position where none of the two or more chambers are axially aligned with the transverse port, and an injection position where one selected chamber of the two or more chambers is moved into alignment with the transverse port;
mounting the ball injecting apparatus so that the transverse port is fluidly connected to the flow passage;
actuating the actuator to move the magazine in the magazine housing to axially align the first chamber with the transverse port for injecting the first drop ball from the first chamber and through the transverse port to the flow passage; and
serially repeating the actuating step for each subsequent chamber for serially injecting each of the subsequent drop balls from the subsequent chambers.
18. The method of claim 17 wherein the mounting step comprising mounting the ball injecting apparatus to a top of a wellbore for forming the flow passage extending downward from the transverse port to the wellbore, wherein the selected ball is injected to the flow passage by gravity.
19. The method of claim 17 wherein the mounting step comprises mounting the ball injecting apparatus intermediate a fluid flow line connected to the wellbore for forming the flow passage through transverse port of the ball injecting apparatus, wherein the selected ball is injected to the flow passage by fluid passing through the fluid flow line and the transverse port and to the wellbore.
20. A system for injecting one or more balls into a wellbore for actuating a series of downhole tools comprising:
a ball injecting apparatus having
a magazine housing having an axial bore formed therethrough and a transverse port, the transverse port being adapted for fluidly connecting to the wellbore;
a magazine axially movable in the axial bore, the magazine having two or more transverse chambers spaced axially therealong, a first of the two or more of the chambers having a first drop ball loaded therein and each subsequent chamber having a subsequent drop ball loaded therein; and
an actuator for axially positioning the magazine within the axial bore between a loaded position where none of the two or more chambers are axially aligned with the transverse port, and an injection position where one selected chamber of the two or more chambers is moved into alignment with the transverse port;
two or more downhole tools spaced at intervals along the wellbore, the two or more downhole tools comprising a first downhole tool actuable upon receipt of the first drop ball and each subsequent downhole tool actuable upon receipt of each subsequent drop ball;
wherein when the actuator is actuated to move the magazine in the magazine housing to axially align the first chamber with the transverse port, the first drop ball is injected from the first chamber and through the transverse port to the wellbore for actuating the first downhole tool; and
serially actuating the actuator for each subsequent chamber for serially injecting each of the subsequent drop balls from the subsequent chambers to serially actuate each of the subsequent downhole tools.
21. The system of claim 20 wherein
the two of more downhole tools are a first and subsequent packers for isolating a first zone and subsequent zones along the wellbore and the first packer is actuable upon receipt of the first drop ball for blocking the wellbore below the packer, and each subsequent packer is actuable upon receipt of the subsequent drop ball for blocking the wellbore below the subsequent packer;
the subsequent drop ball has a diameter greater than the first drop ball and each subsequent ball has a diameter greater than an immediately preceding subsequent drop ball wherein each of the drop balls does not actuate the subsequent packer.
22. The method of claim 21 further comprising:
a wellhead fluidly connected to the wellbore, wherein the ball injecting apparatus is mounted to a top of the wellhead for forming a flow passage extending downward from the transverse port to the wellbore, wherein the selected ball is injected to the flow passage by gravity.
23. The method of claim 21 further comprising:
a wellhead fluidly connected to the wellbore; and
a fluid flow line for flowing fluid to the wellhead, wherein the ball injecting apparatus is mounted intermediate the fluid flow line forming a flow passage through transverse port of the ball injecting apparatus and to the wellbore, wherein the selected ball is injected to the flow passage by fluid passing through the fluid flow line and the transverse port and to the wellbore.
24. The system of claim 23 wherein the wellhead further comprises a wellhead isolation tool having a bore of sufficient size to accept the first and subsequent drop balls.
Priority Applications (1)
Application Number | Priority Date | Filing Date | Title |
---|---|---|---|
US12/049,140 US20080223587A1 (en) | 2007-03-16 | 2008-03-14 | Ball injecting apparatus for wellbore operations |
Applications Claiming Priority (2)
Application Number | Priority Date | Filing Date | Title |
---|---|---|---|
US89535007P | 2007-03-16 | 2007-03-16 | |
US12/049,140 US20080223587A1 (en) | 2007-03-16 | 2008-03-14 | Ball injecting apparatus for wellbore operations |
Publications (1)
Publication Number | Publication Date |
---|---|
US20080223587A1 true US20080223587A1 (en) | 2008-09-18 |
Family
ID=39761492
Family Applications (1)
Application Number | Title | Priority Date | Filing Date |
---|---|---|---|
US12/049,140 Abandoned US20080223587A1 (en) | 2007-03-16 | 2008-03-14 | Ball injecting apparatus for wellbore operations |
Country Status (2)
Country | Link |
---|---|
US (1) | US20080223587A1 (en) |
CA (1) | CA2625766A1 (en) |
Cited By (85)
Publication number | Priority date | Publication date | Assignee | Title |
---|---|---|---|---|
US20080296012A1 (en) * | 2007-05-30 | 2008-12-04 | Smith International, Inc. | Cementing manifold with canister fed dart and ball release system |
US20100294511A1 (en) * | 2009-05-20 | 2010-11-25 | Colin David Winzer | Down-hole actuation device storage apparatus and method for launching |
CN101929330A (en) * | 2010-04-26 | 2010-12-29 | 中国石油集团川庆钻探工程有限公司长庆井下技术作业公司 | Remote control cock type steel ball delivery system |
US20110030947A1 (en) * | 2009-08-07 | 2011-02-10 | Halliburton Energy Boulevard | Stimulating subterranean zones |
US20110135530A1 (en) * | 2009-12-08 | 2011-06-09 | Zhiyue Xu | Method of making a nanomatrix powder metal compact |
US20110198096A1 (en) * | 2010-02-15 | 2011-08-18 | Tejas Research And Engineering, Lp | Unlimited Downhole Fracture Zone System |
US20110220367A1 (en) * | 2010-03-10 | 2011-09-15 | Halliburton Energy Services, Inc. | Operational control of multiple valves in a well |
WO2012018700A2 (en) * | 2010-08-03 | 2012-02-09 | Thru Tubing Solutions, Inc. | Abrasive perforator with fluid bypass |
US20120152525A1 (en) * | 2010-12-21 | 2012-06-21 | Stinger Wellhead Protection, Inc. | Low profile, high capacity ball injector |
US20120211219A1 (en) * | 2011-02-22 | 2012-08-23 | Stinger Wellhead Protection, Inc. | Horizontal frac ball injector |
US8327931B2 (en) | 2009-12-08 | 2012-12-11 | Baker Hughes Incorporated | Multi-component disappearing tripping ball and method for making the same |
US20130068484A1 (en) * | 2002-08-21 | 2013-03-21 | Packers Plus Energy Services Inc. | Method and apparatus for wellbore fluid treatment |
US8425651B2 (en) | 2010-07-30 | 2013-04-23 | Baker Hughes Incorporated | Nanomatrix metal composite |
US8424610B2 (en) | 2010-03-05 | 2013-04-23 | Baker Hughes Incorporated | Flow control arrangement and method |
US20130228326A1 (en) * | 2012-03-04 | 2013-09-05 | Sheldon GRIFFITH | Ball injecting apparatus for wellbore operations with external loading port |
US8573295B2 (en) | 2010-11-16 | 2013-11-05 | Baker Hughes Incorporated | Plug and method of unplugging a seat |
US8631876B2 (en) | 2011-04-28 | 2014-01-21 | Baker Hughes Incorporated | Method of making and using a functionally gradient composite tool |
US8636055B2 (en) | 2011-05-05 | 2014-01-28 | Oil States Energy Services, L.L.C. | Controlled aperture ball drop |
US8746343B2 (en) | 2001-11-19 | 2014-06-10 | Packers Plus Energy Services Inc. | Method and apparatus for wellbore fluid treatment |
US8776884B2 (en) | 2010-08-09 | 2014-07-15 | Baker Hughes Incorporated | Formation treatment system and method |
US8783365B2 (en) | 2011-07-28 | 2014-07-22 | Baker Hughes Incorporated | Selective hydraulic fracturing tool and method thereof |
CN103939079A (en) * | 2013-01-23 | 2014-07-23 | 中国石油化工股份有限公司 | Wellhead ball throwing device for fracture acidizing and operation method thereof |
CN103939073A (en) * | 2013-01-23 | 2014-07-23 | 中国石油化工股份有限公司 | Pitching device for oil field staged fracturing |
US20140352968A1 (en) * | 2013-06-03 | 2014-12-04 | Cameron International Corporation | Multi-well simultaneous fracturing system |
US9022107B2 (en) | 2009-12-08 | 2015-05-05 | Baker Hughes Incorporated | Dissolvable tool |
US9033055B2 (en) | 2011-08-17 | 2015-05-19 | Baker Hughes Incorporated | Selectively degradable passage restriction and method |
US9057242B2 (en) | 2011-08-05 | 2015-06-16 | Baker Hughes Incorporated | Method of controlling corrosion rate in downhole article, and downhole article having controlled corrosion rate |
CN104712300A (en) * | 2015-02-13 | 2015-06-17 | 陈介骄 | Fracturing construction pitching device and pitching method thereof |
US9068428B2 (en) | 2012-02-13 | 2015-06-30 | Baker Hughes Incorporated | Selectively corrodible downhole article and method of use |
US9080098B2 (en) | 2011-04-28 | 2015-07-14 | Baker Hughes Incorporated | Functionally gradient composite article |
US9090956B2 (en) | 2011-08-30 | 2015-07-28 | Baker Hughes Incorporated | Aluminum alloy powder metal compact |
US9090955B2 (en) | 2010-10-27 | 2015-07-28 | Baker Hughes Incorporated | Nanomatrix powder metal composite |
US9101978B2 (en) | 2002-12-08 | 2015-08-11 | Baker Hughes Incorporated | Nanomatrix powder metal compact |
CN104832150A (en) * | 2015-05-21 | 2015-08-12 | 西南石油大学 | Device and method of electromagnet control intelligent ball injection for horizontal well multistage fracturing |
US9109422B2 (en) | 2013-03-15 | 2015-08-18 | Performance Wellhead & Frac Components, Inc. | Ball injector system apparatus and method |
US9109429B2 (en) | 2002-12-08 | 2015-08-18 | Baker Hughes Incorporated | Engineered powder compact composite material |
US9109269B2 (en) | 2011-08-30 | 2015-08-18 | Baker Hughes Incorporated | Magnesium alloy powder metal compact |
US9127515B2 (en) | 2010-10-27 | 2015-09-08 | Baker Hughes Incorporated | Nanomatrix carbon composite |
US9133695B2 (en) | 2011-09-03 | 2015-09-15 | Baker Hughes Incorporated | Degradable shaped charge and perforating gun system |
US9139928B2 (en) | 2011-06-17 | 2015-09-22 | Baker Hughes Incorporated | Corrodible downhole article and method of removing the article from downhole environment |
US9187990B2 (en) | 2011-09-03 | 2015-11-17 | Baker Hughes Incorporated | Method of using a degradable shaped charge and perforating gun system |
US9228422B2 (en) | 2012-01-30 | 2016-01-05 | Thru Tubing Solutions, Inc. | Limited depth abrasive jet cutter |
US9227243B2 (en) | 2009-12-08 | 2016-01-05 | Baker Hughes Incorporated | Method of making a powder metal compact |
US9243475B2 (en) | 2009-12-08 | 2016-01-26 | Baker Hughes Incorporated | Extruded powder metal compact |
US9267347B2 (en) | 2009-12-08 | 2016-02-23 | Baker Huges Incorporated | Dissolvable tool |
US9284812B2 (en) | 2011-11-21 | 2016-03-15 | Baker Hughes Incorporated | System for increasing swelling efficiency |
US9347119B2 (en) | 2011-09-03 | 2016-05-24 | Baker Hughes Incorporated | Degradable high shock impedance material |
US9528356B2 (en) | 2014-03-05 | 2016-12-27 | Halliburton Energy Services Inc. | Flow control mechanism for downhole tool |
WO2017027962A1 (en) * | 2015-08-20 | 2017-02-23 | Fmc Technologies Canada Ltd. | Ball insertion device for use in oil and gas wells |
US9605508B2 (en) | 2012-05-08 | 2017-03-28 | Baker Hughes Incorporated | Disintegrable and conformable metallic seal, and method of making the same |
US9643250B2 (en) | 2011-07-29 | 2017-05-09 | Baker Hughes Incorporated | Method of controlling the corrosion rate of alloy particles, alloy particle with controlled corrosion rate, and articles comprising the particle |
US9643144B2 (en) | 2011-09-02 | 2017-05-09 | Baker Hughes Incorporated | Method to generate and disperse nanostructures in a composite material |
CN106703735A (en) * | 2016-11-28 | 2017-05-24 | 中国石油天然气股份有限公司 | Well mouth ball pitching device |
US9682425B2 (en) | 2009-12-08 | 2017-06-20 | Baker Hughes Incorporated | Coated metallic powder and method of making the same |
US9707739B2 (en) | 2011-07-22 | 2017-07-18 | Baker Hughes Incorporated | Intermetallic metallic composite, method of manufacture thereof and articles comprising the same |
US9739111B2 (en) | 2011-05-05 | 2017-08-22 | Oil States Energy Services, L.L.C. | Controlled aperture ball drop |
US9777558B1 (en) | 2005-03-12 | 2017-10-03 | Thru Tubing Solutions, Inc. | Methods and devices for one trip plugging and perforating of oil and gas wells |
US9816339B2 (en) | 2013-09-03 | 2017-11-14 | Baker Hughes, A Ge Company, Llc | Plug reception assembly and method of reducing restriction in a borehole |
US9833838B2 (en) | 2011-07-29 | 2017-12-05 | Baker Hughes, A Ge Company, Llc | Method of controlling the corrosion rate of alloy particles, alloy particle with controlled corrosion rate, and articles comprising the particle |
US9856547B2 (en) | 2011-08-30 | 2018-01-02 | Bakers Hughes, A Ge Company, Llc | Nanostructured powder metal compact |
US9910026B2 (en) | 2015-01-21 | 2018-03-06 | Baker Hughes, A Ge Company, Llc | High temperature tracers for downhole detection of produced water |
US9926766B2 (en) | 2012-01-25 | 2018-03-27 | Baker Hughes, A Ge Company, Llc | Seat for a tubular treating system |
US10016810B2 (en) | 2015-12-14 | 2018-07-10 | Baker Hughes, A Ge Company, Llc | Methods of manufacturing degradable tools using a galvanic carrier and tools manufactured thereof |
US10030474B2 (en) | 2008-04-29 | 2018-07-24 | Packers Plus Energy Services Inc. | Downhole sub with hydraulically actuable sleeve valve |
US10119355B2 (en) | 2014-01-06 | 2018-11-06 | Halliburton Energy Services, Inc. | Releasing a well drop |
US10161218B2 (en) | 2015-03-03 | 2018-12-25 | Stream-Flo Industries Ltd. | Ball injector for frac tree |
US10221637B2 (en) | 2015-08-11 | 2019-03-05 | Baker Hughes, A Ge Company, Llc | Methods of manufacturing dissolvable tools via liquid-solid state molding |
US10240419B2 (en) | 2009-12-08 | 2019-03-26 | Baker Hughes, A Ge Company, Llc | Downhole flow inhibition tool and method of unplugging a seat |
US20190218880A1 (en) * | 2018-01-15 | 2019-07-18 | Nicholas J. Cannon | Object launching apparatus and related methods |
US10378302B2 (en) * | 2017-11-03 | 2019-08-13 | Global Core Technologies Corp. | Drop ball sizing apparatus and method |
US10378303B2 (en) | 2015-03-05 | 2019-08-13 | Baker Hughes, A Ge Company, Llc | Downhole tool and method of forming the same |
US10435978B2 (en) | 2013-06-07 | 2019-10-08 | Ge Oil And Gas Canada Inc. | Atmospheric ball injecting apparatus, system and method for wellbore operations |
US20190368301A1 (en) * | 2018-05-31 | 2019-12-05 | Dynaenergetics Gmbh & Co. Kg | Drone conveyance system and method |
US10677024B2 (en) | 2017-03-01 | 2020-06-09 | Thru Tubing Solutions, Inc. | Abrasive perforator with fluid bypass |
US20210115754A1 (en) * | 2019-10-22 | 2021-04-22 | Shane Triche | Ball injecting apparatus and method for wellbore operations |
US11167343B2 (en) | 2014-02-21 | 2021-11-09 | Terves, Llc | Galvanically-active in situ formed particles for controlled rate dissolving tools |
US11242724B2 (en) | 2017-12-14 | 2022-02-08 | Downing Wellhead Equipment, Llc | Launching objects into a wellbore |
US11365164B2 (en) | 2014-02-21 | 2022-06-21 | Terves, Llc | Fluid activated disintegrating metal system |
US20220228456A1 (en) * | 2019-06-20 | 2022-07-21 | Thru Tubing Solutions, Inc. | Discrete plugging device launcher |
US11408279B2 (en) | 2018-08-21 | 2022-08-09 | DynaEnergetics Europe GmbH | System and method for navigating a wellbore and determining location in a wellbore |
US11434713B2 (en) * | 2018-05-31 | 2022-09-06 | DynaEnergetics Europe GmbH | Wellhead launcher system and method |
US11434725B2 (en) | 2019-06-18 | 2022-09-06 | DynaEnergetics Europe GmbH | Automated drone delivery system |
US11649526B2 (en) | 2017-07-27 | 2023-05-16 | Terves, Llc | Degradable metal matrix composite |
US11879301B2 (en) | 2020-10-14 | 2024-01-23 | Advanced Upstream Ltd. | Pneumatic transport system and method for wellbore operations |
US11920426B2 (en) * | 2020-10-14 | 2024-03-05 | John Tyler Thomason | Payload deployment tools |
Families Citing this family (1)
Publication number | Priority date | Publication date | Assignee | Title |
---|---|---|---|---|
CN105443073B (en) * | 2015-12-18 | 2019-01-18 | 中国石油天然气股份有限公司 | Adjust stifled ball delivery device |
Citations (17)
Publication number | Priority date | Publication date | Assignee | Title |
---|---|---|---|---|
US3063080A (en) * | 1961-01-11 | 1962-11-13 | Panhandle Eastern Pipe Line Co | Combination gate valve and ball launcher and catcher for use in pressure flow lines |
US4070161A (en) * | 1976-06-17 | 1978-01-24 | General Electric Company | Double seal gate valve structure |
US4132243A (en) * | 1977-06-15 | 1979-01-02 | Bj-Hughes Inc. | Apparatus for feeding perforation sealer balls and the like into well treating fluid |
US4759469A (en) * | 1986-11-03 | 1988-07-26 | Special Projects Mfg., Inc. | Apparatus and method for injecting balls into a well |
US5277248A (en) * | 1992-05-19 | 1994-01-11 | B And E Manufacturing & Supply Co. | Ball valve type injector and catcher apparatus with adjustable flow control for catching and retrieving paraffin cutting balls |
US6182752B1 (en) * | 1998-07-14 | 2001-02-06 | Baker Hughes Incorporated | Multi-port cementing head |
US6186236B1 (en) * | 1999-09-21 | 2001-02-13 | Halliburton Energy Services, Inc. | Multi-zone screenless well fracturing method and apparatus |
US6286540B1 (en) * | 1998-04-14 | 2001-09-11 | Nataniel Carli Bonicontro | Pig or sphere thrower |
US6302199B1 (en) * | 1999-04-30 | 2001-10-16 | Frank's International, Inc. | Mechanism for dropping a plurality of balls into tubulars used in drilling, completion and workover of oil, gas and geothermal wells |
US6390189B1 (en) * | 1998-01-20 | 2002-05-21 | Sandvik Tamrock Oy | Feed apparatus for feeding capsular cartridges into drilled hole |
US6408837B1 (en) * | 1999-09-13 | 2002-06-25 | Johnson Research & Development Co. | Toy gun with magazine |
US6588501B1 (en) * | 2002-09-27 | 2003-07-08 | Varco I/P, Inc. | Method and apparatus to reduce hydrostatic pressure in sub sea risers using buoyant spheres |
US6799638B2 (en) * | 2002-03-01 | 2004-10-05 | Halliburton Energy Services, Inc. | Method, apparatus and system for selective release of cementing plugs |
US6899172B2 (en) * | 2003-06-03 | 2005-05-31 | Mcleod Roderick D. | Abrasion resistant frac head |
US6907936B2 (en) * | 2001-11-19 | 2005-06-21 | Packers Plus Energy Services Inc. | Method and apparatus for wellbore fluid treatment |
US20050184083A1 (en) * | 2004-02-24 | 2005-08-25 | Diaz Juan M. | Remote actuator for ball injector |
US7431091B2 (en) * | 2002-08-21 | 2008-10-07 | Packers Plus Energy Services Inc. | Method and apparatus for wellbore fluid treatment |
-
2008
- 2008-03-14 US US12/049,140 patent/US20080223587A1/en not_active Abandoned
- 2008-03-14 CA CA002625766A patent/CA2625766A1/en not_active Abandoned
Patent Citations (17)
Publication number | Priority date | Publication date | Assignee | Title |
---|---|---|---|---|
US3063080A (en) * | 1961-01-11 | 1962-11-13 | Panhandle Eastern Pipe Line Co | Combination gate valve and ball launcher and catcher for use in pressure flow lines |
US4070161A (en) * | 1976-06-17 | 1978-01-24 | General Electric Company | Double seal gate valve structure |
US4132243A (en) * | 1977-06-15 | 1979-01-02 | Bj-Hughes Inc. | Apparatus for feeding perforation sealer balls and the like into well treating fluid |
US4759469A (en) * | 1986-11-03 | 1988-07-26 | Special Projects Mfg., Inc. | Apparatus and method for injecting balls into a well |
US5277248A (en) * | 1992-05-19 | 1994-01-11 | B And E Manufacturing & Supply Co. | Ball valve type injector and catcher apparatus with adjustable flow control for catching and retrieving paraffin cutting balls |
US6390189B1 (en) * | 1998-01-20 | 2002-05-21 | Sandvik Tamrock Oy | Feed apparatus for feeding capsular cartridges into drilled hole |
US6286540B1 (en) * | 1998-04-14 | 2001-09-11 | Nataniel Carli Bonicontro | Pig or sphere thrower |
US6182752B1 (en) * | 1998-07-14 | 2001-02-06 | Baker Hughes Incorporated | Multi-port cementing head |
US6302199B1 (en) * | 1999-04-30 | 2001-10-16 | Frank's International, Inc. | Mechanism for dropping a plurality of balls into tubulars used in drilling, completion and workover of oil, gas and geothermal wells |
US6408837B1 (en) * | 1999-09-13 | 2002-06-25 | Johnson Research & Development Co. | Toy gun with magazine |
US6186236B1 (en) * | 1999-09-21 | 2001-02-13 | Halliburton Energy Services, Inc. | Multi-zone screenless well fracturing method and apparatus |
US6907936B2 (en) * | 2001-11-19 | 2005-06-21 | Packers Plus Energy Services Inc. | Method and apparatus for wellbore fluid treatment |
US6799638B2 (en) * | 2002-03-01 | 2004-10-05 | Halliburton Energy Services, Inc. | Method, apparatus and system for selective release of cementing plugs |
US7431091B2 (en) * | 2002-08-21 | 2008-10-07 | Packers Plus Energy Services Inc. | Method and apparatus for wellbore fluid treatment |
US6588501B1 (en) * | 2002-09-27 | 2003-07-08 | Varco I/P, Inc. | Method and apparatus to reduce hydrostatic pressure in sub sea risers using buoyant spheres |
US6899172B2 (en) * | 2003-06-03 | 2005-05-31 | Mcleod Roderick D. | Abrasion resistant frac head |
US20050184083A1 (en) * | 2004-02-24 | 2005-08-25 | Diaz Juan M. | Remote actuator for ball injector |
Cited By (130)
Publication number | Priority date | Publication date | Assignee | Title |
---|---|---|---|---|
US9963962B2 (en) | 2001-11-19 | 2018-05-08 | Packers Plus Energy Services Inc. | Method and apparatus for wellbore fluid treatment |
US8746343B2 (en) | 2001-11-19 | 2014-06-10 | Packers Plus Energy Services Inc. | Method and apparatus for wellbore fluid treatment |
US9366123B2 (en) | 2001-11-19 | 2016-06-14 | Packers Plus Energy Services Inc. | Method and apparatus for wellbore fluid treatment |
US9303501B2 (en) | 2001-11-19 | 2016-04-05 | Packers Plus Energy Services Inc. | Method and apparatus for wellbore fluid treatment |
US10087734B2 (en) | 2001-11-19 | 2018-10-02 | Packers Plus Energy Services Inc. | Method and apparatus for wellbore fluid treatment |
US10822936B2 (en) | 2001-11-19 | 2020-11-03 | Packers Plus Energy Services Inc. | Method and apparatus for wellbore fluid treatment |
US9074451B2 (en) | 2002-08-21 | 2015-07-07 | Packers Plus Energy Services Inc. | Method and apparatus for wellbore fluid treatment |
US10053957B2 (en) | 2002-08-21 | 2018-08-21 | Packers Plus Energy Services Inc. | Method and apparatus for wellbore fluid treatment |
US10487624B2 (en) | 2002-08-21 | 2019-11-26 | Packers Plus Energy Services Inc. | Method and apparatus for wellbore fluid treatment |
US8657009B2 (en) * | 2002-08-21 | 2014-02-25 | Packers Plus Energy Services Inc. | Method and apparatus for wellbore fluid treatment |
US20130068484A1 (en) * | 2002-08-21 | 2013-03-21 | Packers Plus Energy Services Inc. | Method and apparatus for wellbore fluid treatment |
US9109429B2 (en) | 2002-12-08 | 2015-08-18 | Baker Hughes Incorporated | Engineered powder compact composite material |
US9101978B2 (en) | 2002-12-08 | 2015-08-11 | Baker Hughes Incorporated | Nanomatrix powder metal compact |
US9777558B1 (en) | 2005-03-12 | 2017-10-03 | Thru Tubing Solutions, Inc. | Methods and devices for one trip plugging and perforating of oil and gas wells |
US20080296012A1 (en) * | 2007-05-30 | 2008-12-04 | Smith International, Inc. | Cementing manifold with canister fed dart and ball release system |
US8091628B2 (en) * | 2007-05-30 | 2012-01-10 | Smith International, Inc. | Apparatus and method for providing fluid and projectiles to downhole tubulars |
US10030474B2 (en) | 2008-04-29 | 2018-07-24 | Packers Plus Energy Services Inc. | Downhole sub with hydraulically actuable sleeve valve |
US10704362B2 (en) | 2008-04-29 | 2020-07-07 | Packers Plus Energy Services Inc. | Downhole sub with hydraulically actuable sleeve valve |
US8256514B2 (en) | 2009-05-20 | 2012-09-04 | Stream-Flo Industries Ltd. | Down-hole actuation device storage apparatus and method for launching |
US8561684B2 (en) | 2009-05-20 | 2013-10-22 | Stream-Flo Industries Ltd. | Down-hole actuation device storage apparatus and method for launching |
US20100294511A1 (en) * | 2009-05-20 | 2010-11-25 | Colin David Winzer | Down-hole actuation device storage apparatus and method for launching |
US20110030947A1 (en) * | 2009-08-07 | 2011-02-10 | Halliburton Energy Boulevard | Stimulating subterranean zones |
US9085974B2 (en) * | 2009-08-07 | 2015-07-21 | Halliburton Energy Services, Inc. | Stimulating subterranean zones |
US8327931B2 (en) | 2009-12-08 | 2012-12-11 | Baker Hughes Incorporated | Multi-component disappearing tripping ball and method for making the same |
US8714268B2 (en) | 2009-12-08 | 2014-05-06 | Baker Hughes Incorporated | Method of making and using multi-component disappearing tripping ball |
US10240419B2 (en) | 2009-12-08 | 2019-03-26 | Baker Hughes, A Ge Company, Llc | Downhole flow inhibition tool and method of unplugging a seat |
US9267347B2 (en) | 2009-12-08 | 2016-02-23 | Baker Huges Incorporated | Dissolvable tool |
US9243475B2 (en) | 2009-12-08 | 2016-01-26 | Baker Hughes Incorporated | Extruded powder metal compact |
US9227243B2 (en) | 2009-12-08 | 2016-01-05 | Baker Hughes Incorporated | Method of making a powder metal compact |
US20110135530A1 (en) * | 2009-12-08 | 2011-06-09 | Zhiyue Xu | Method of making a nanomatrix powder metal compact |
US9079246B2 (en) | 2009-12-08 | 2015-07-14 | Baker Hughes Incorporated | Method of making a nanomatrix powder metal compact |
US9682425B2 (en) | 2009-12-08 | 2017-06-20 | Baker Hughes Incorporated | Coated metallic powder and method of making the same |
US10669797B2 (en) | 2009-12-08 | 2020-06-02 | Baker Hughes, A Ge Company, Llc | Tool configured to dissolve in a selected subsurface environment |
US9022107B2 (en) | 2009-12-08 | 2015-05-05 | Baker Hughes Incorporated | Dissolvable tool |
US20110198096A1 (en) * | 2010-02-15 | 2011-08-18 | Tejas Research And Engineering, Lp | Unlimited Downhole Fracture Zone System |
US8424610B2 (en) | 2010-03-05 | 2013-04-23 | Baker Hughes Incorporated | Flow control arrangement and method |
US20110220367A1 (en) * | 2010-03-10 | 2011-09-15 | Halliburton Energy Services, Inc. | Operational control of multiple valves in a well |
CN101929330A (en) * | 2010-04-26 | 2010-12-29 | 中国石油集团川庆钻探工程有限公司长庆井下技术作业公司 | Remote control cock type steel ball delivery system |
US8425651B2 (en) | 2010-07-30 | 2013-04-23 | Baker Hughes Incorporated | Nanomatrix metal composite |
WO2012018700A2 (en) * | 2010-08-03 | 2012-02-09 | Thru Tubing Solutions, Inc. | Abrasive perforator with fluid bypass |
WO2012018700A3 (en) * | 2010-08-03 | 2012-04-19 | Thru Tubing Solutions, Inc. | Abrasive perforator with fluid bypass |
US8448700B2 (en) | 2010-08-03 | 2013-05-28 | Thru Tubing Solutions, Inc. | Abrasive perforator with fluid bypass |
US8776884B2 (en) | 2010-08-09 | 2014-07-15 | Baker Hughes Incorporated | Formation treatment system and method |
US9127515B2 (en) | 2010-10-27 | 2015-09-08 | Baker Hughes Incorporated | Nanomatrix carbon composite |
US9090955B2 (en) | 2010-10-27 | 2015-07-28 | Baker Hughes Incorporated | Nanomatrix powder metal composite |
US8573295B2 (en) | 2010-11-16 | 2013-11-05 | Baker Hughes Incorporated | Plug and method of unplugging a seat |
US9222329B2 (en) | 2010-12-21 | 2015-12-29 | Oil States Energy Services, L.L.C. | Low profile, high capacity ball injector |
US20120152525A1 (en) * | 2010-12-21 | 2012-06-21 | Stinger Wellhead Protection, Inc. | Low profile, high capacity ball injector |
US8869882B2 (en) * | 2010-12-21 | 2014-10-28 | Oil States Energy Services, L.L.C. | Low profile, high capacity ball injector |
US20120211219A1 (en) * | 2011-02-22 | 2012-08-23 | Stinger Wellhead Protection, Inc. | Horizontal frac ball injector |
US9228417B2 (en) | 2011-02-22 | 2016-01-05 | Oil States Energy Services, L.L.C. | Horizontal frac ball injector |
US8869883B2 (en) * | 2011-02-22 | 2014-10-28 | Oil States Energy Services, L.L.C. | Horizontal frac ball injector |
US10335858B2 (en) | 2011-04-28 | 2019-07-02 | Baker Hughes, A Ge Company, Llc | Method of making and using a functionally gradient composite tool |
US8631876B2 (en) | 2011-04-28 | 2014-01-21 | Baker Hughes Incorporated | Method of making and using a functionally gradient composite tool |
US9631138B2 (en) | 2011-04-28 | 2017-04-25 | Baker Hughes Incorporated | Functionally gradient composite article |
US9080098B2 (en) | 2011-04-28 | 2015-07-14 | Baker Hughes Incorporated | Functionally gradient composite article |
US8839851B2 (en) | 2011-05-05 | 2014-09-23 | Oil States Energy Services, L.L.C. | Controlled apperture ball drop |
US9739111B2 (en) | 2011-05-05 | 2017-08-22 | Oil States Energy Services, L.L.C. | Controlled aperture ball drop |
US8636055B2 (en) | 2011-05-05 | 2014-01-28 | Oil States Energy Services, L.L.C. | Controlled aperture ball drop |
US9869151B2 (en) | 2011-05-05 | 2018-01-16 | Oil States Energy Services, L.L.C. | Controlled aperture ball drop |
US9139928B2 (en) | 2011-06-17 | 2015-09-22 | Baker Hughes Incorporated | Corrodible downhole article and method of removing the article from downhole environment |
US9926763B2 (en) | 2011-06-17 | 2018-03-27 | Baker Hughes, A Ge Company, Llc | Corrodible downhole article and method of removing the article from downhole environment |
US9707739B2 (en) | 2011-07-22 | 2017-07-18 | Baker Hughes Incorporated | Intermetallic metallic composite, method of manufacture thereof and articles comprising the same |
US10697266B2 (en) | 2011-07-22 | 2020-06-30 | Baker Hughes, A Ge Company, Llc | Intermetallic metallic composite, method of manufacture thereof and articles comprising the same |
US8783365B2 (en) | 2011-07-28 | 2014-07-22 | Baker Hughes Incorporated | Selective hydraulic fracturing tool and method thereof |
US9833838B2 (en) | 2011-07-29 | 2017-12-05 | Baker Hughes, A Ge Company, Llc | Method of controlling the corrosion rate of alloy particles, alloy particle with controlled corrosion rate, and articles comprising the particle |
US10092953B2 (en) | 2011-07-29 | 2018-10-09 | Baker Hughes, A Ge Company, Llc | Method of controlling the corrosion rate of alloy particles, alloy particle with controlled corrosion rate, and articles comprising the particle |
US9643250B2 (en) | 2011-07-29 | 2017-05-09 | Baker Hughes Incorporated | Method of controlling the corrosion rate of alloy particles, alloy particle with controlled corrosion rate, and articles comprising the particle |
US9057242B2 (en) | 2011-08-05 | 2015-06-16 | Baker Hughes Incorporated | Method of controlling corrosion rate in downhole article, and downhole article having controlled corrosion rate |
US9033055B2 (en) | 2011-08-17 | 2015-05-19 | Baker Hughes Incorporated | Selectively degradable passage restriction and method |
US10301909B2 (en) | 2011-08-17 | 2019-05-28 | Baker Hughes, A Ge Company, Llc | Selectively degradable passage restriction |
US9109269B2 (en) | 2011-08-30 | 2015-08-18 | Baker Hughes Incorporated | Magnesium alloy powder metal compact |
US9925589B2 (en) | 2011-08-30 | 2018-03-27 | Baker Hughes, A Ge Company, Llc | Aluminum alloy powder metal compact |
US10737321B2 (en) | 2011-08-30 | 2020-08-11 | Baker Hughes, A Ge Company, Llc | Magnesium alloy powder metal compact |
US9802250B2 (en) | 2011-08-30 | 2017-10-31 | Baker Hughes | Magnesium alloy powder metal compact |
US9090956B2 (en) | 2011-08-30 | 2015-07-28 | Baker Hughes Incorporated | Aluminum alloy powder metal compact |
US11090719B2 (en) | 2011-08-30 | 2021-08-17 | Baker Hughes, A Ge Company, Llc | Aluminum alloy powder metal compact |
US9856547B2 (en) | 2011-08-30 | 2018-01-02 | Bakers Hughes, A Ge Company, Llc | Nanostructured powder metal compact |
US9643144B2 (en) | 2011-09-02 | 2017-05-09 | Baker Hughes Incorporated | Method to generate and disperse nanostructures in a composite material |
US9133695B2 (en) | 2011-09-03 | 2015-09-15 | Baker Hughes Incorporated | Degradable shaped charge and perforating gun system |
US9347119B2 (en) | 2011-09-03 | 2016-05-24 | Baker Hughes Incorporated | Degradable high shock impedance material |
US9187990B2 (en) | 2011-09-03 | 2015-11-17 | Baker Hughes Incorporated | Method of using a degradable shaped charge and perforating gun system |
US9284812B2 (en) | 2011-11-21 | 2016-03-15 | Baker Hughes Incorporated | System for increasing swelling efficiency |
US9926766B2 (en) | 2012-01-25 | 2018-03-27 | Baker Hughes, A Ge Company, Llc | Seat for a tubular treating system |
US9228422B2 (en) | 2012-01-30 | 2016-01-05 | Thru Tubing Solutions, Inc. | Limited depth abrasive jet cutter |
US9068428B2 (en) | 2012-02-13 | 2015-06-30 | Baker Hughes Incorporated | Selectively corrodible downhole article and method of use |
US20130228326A1 (en) * | 2012-03-04 | 2013-09-05 | Sheldon GRIFFITH | Ball injecting apparatus for wellbore operations with external loading port |
US9605508B2 (en) | 2012-05-08 | 2017-03-28 | Baker Hughes Incorporated | Disintegrable and conformable metallic seal, and method of making the same |
US10612659B2 (en) | 2012-05-08 | 2020-04-07 | Baker Hughes Oilfield Operations, Llc | Disintegrable and conformable metallic seal, and method of making the same |
CN103939073A (en) * | 2013-01-23 | 2014-07-23 | 中国石油化工股份有限公司 | Pitching device for oil field staged fracturing |
CN103939079A (en) * | 2013-01-23 | 2014-07-23 | 中国石油化工股份有限公司 | Wellhead ball throwing device for fracture acidizing and operation method thereof |
US9109422B2 (en) | 2013-03-15 | 2015-08-18 | Performance Wellhead & Frac Components, Inc. | Ball injector system apparatus and method |
US20140352968A1 (en) * | 2013-06-03 | 2014-12-04 | Cameron International Corporation | Multi-well simultaneous fracturing system |
US10435978B2 (en) | 2013-06-07 | 2019-10-08 | Ge Oil And Gas Canada Inc. | Atmospheric ball injecting apparatus, system and method for wellbore operations |
US9816339B2 (en) | 2013-09-03 | 2017-11-14 | Baker Hughes, A Ge Company, Llc | Plug reception assembly and method of reducing restriction in a borehole |
GB2535924B (en) * | 2014-01-06 | 2020-08-26 | Halliburton Energy Services Inc | Releasing a well drop |
US10119355B2 (en) | 2014-01-06 | 2018-11-06 | Halliburton Energy Services, Inc. | Releasing a well drop |
US11613952B2 (en) | 2014-02-21 | 2023-03-28 | Terves, Llc | Fluid activated disintegrating metal system |
US11365164B2 (en) | 2014-02-21 | 2022-06-21 | Terves, Llc | Fluid activated disintegrating metal system |
US11167343B2 (en) | 2014-02-21 | 2021-11-09 | Terves, Llc | Galvanically-active in situ formed particles for controlled rate dissolving tools |
US9528356B2 (en) | 2014-03-05 | 2016-12-27 | Halliburton Energy Services Inc. | Flow control mechanism for downhole tool |
US9910026B2 (en) | 2015-01-21 | 2018-03-06 | Baker Hughes, A Ge Company, Llc | High temperature tracers for downhole detection of produced water |
CN104712300A (en) * | 2015-02-13 | 2015-06-17 | 陈介骄 | Fracturing construction pitching device and pitching method thereof |
US10161218B2 (en) | 2015-03-03 | 2018-12-25 | Stream-Flo Industries Ltd. | Ball injector for frac tree |
US10731436B2 (en) | 2015-03-03 | 2020-08-04 | Stream-Flo Industries Ltd. | Ball injector for frac tree |
US10378303B2 (en) | 2015-03-05 | 2019-08-13 | Baker Hughes, A Ge Company, Llc | Downhole tool and method of forming the same |
CN104832150A (en) * | 2015-05-21 | 2015-08-12 | 西南石油大学 | Device and method of electromagnet control intelligent ball injection for horizontal well multistage fracturing |
US10221637B2 (en) | 2015-08-11 | 2019-03-05 | Baker Hughes, A Ge Company, Llc | Methods of manufacturing dissolvable tools via liquid-solid state molding |
WO2017027962A1 (en) * | 2015-08-20 | 2017-02-23 | Fmc Technologies Canada Ltd. | Ball insertion device for use in oil and gas wells |
US10016810B2 (en) | 2015-12-14 | 2018-07-10 | Baker Hughes, A Ge Company, Llc | Methods of manufacturing degradable tools using a galvanic carrier and tools manufactured thereof |
CN106703735A (en) * | 2016-11-28 | 2017-05-24 | 中国石油天然气股份有限公司 | Well mouth ball pitching device |
US10677024B2 (en) | 2017-03-01 | 2020-06-09 | Thru Tubing Solutions, Inc. | Abrasive perforator with fluid bypass |
US11898223B2 (en) | 2017-07-27 | 2024-02-13 | Terves, Llc | Degradable metal matrix composite |
US11649526B2 (en) | 2017-07-27 | 2023-05-16 | Terves, Llc | Degradable metal matrix composite |
US10378302B2 (en) * | 2017-11-03 | 2019-08-13 | Global Core Technologies Corp. | Drop ball sizing apparatus and method |
US11242724B2 (en) | 2017-12-14 | 2022-02-08 | Downing Wellhead Equipment, Llc | Launching objects into a wellbore |
US20190218880A1 (en) * | 2018-01-15 | 2019-07-18 | Nicholas J. Cannon | Object launching apparatus and related methods |
US10584552B2 (en) * | 2018-01-15 | 2020-03-10 | Downing Wellhead Equipment, Llc | Object launching apparatus and related methods |
US11486219B2 (en) * | 2018-05-31 | 2022-11-01 | DynaEnergetics Europe GmbH | Delivery system |
US11434713B2 (en) * | 2018-05-31 | 2022-09-06 | DynaEnergetics Europe GmbH | Wellhead launcher system and method |
US10605037B2 (en) * | 2018-05-31 | 2020-03-31 | DynaEnergetics Europe GmbH | Drone conveyance system and method |
US20190368301A1 (en) * | 2018-05-31 | 2019-12-05 | Dynaenergetics Gmbh & Co. Kg | Drone conveyance system and method |
US10844684B2 (en) * | 2018-05-31 | 2020-11-24 | DynaEnergetics Europe GmbH | Delivery system |
US11408279B2 (en) | 2018-08-21 | 2022-08-09 | DynaEnergetics Europe GmbH | System and method for navigating a wellbore and determining location in a wellbore |
US11434725B2 (en) | 2019-06-18 | 2022-09-06 | DynaEnergetics Europe GmbH | Automated drone delivery system |
US20220228456A1 (en) * | 2019-06-20 | 2022-07-21 | Thru Tubing Solutions, Inc. | Discrete plugging device launcher |
US20210115754A1 (en) * | 2019-10-22 | 2021-04-22 | Shane Triche | Ball injecting apparatus and method for wellbore operations |
US11808107B2 (en) * | 2019-10-22 | 2023-11-07 | Shane Triche | Ball injecting apparatus and method for wellbore operations |
US11879301B2 (en) | 2020-10-14 | 2024-01-23 | Advanced Upstream Ltd. | Pneumatic transport system and method for wellbore operations |
US11920426B2 (en) * | 2020-10-14 | 2024-03-05 | John Tyler Thomason | Payload deployment tools |
Also Published As
Publication number | Publication date |
---|---|
CA2625766A1 (en) | 2008-09-16 |
Similar Documents
Publication | Publication Date | Title |
---|---|---|
US20080223587A1 (en) | Ball injecting apparatus for wellbore operations | |
US10731436B2 (en) | Ball injector for frac tree | |
US8136585B2 (en) | Radial ball injecting apparatus for wellbore operations | |
RU2733998C2 (en) | Multistage stimulation device, systems and methods | |
US8567501B2 (en) | System and method for stimulating multiple production zones in a wellbore with a tubing deployed ball seat | |
US9765594B2 (en) | Apparatus and method for stimulating subterranean formations | |
US7377321B2 (en) | Testing, treating, or producing a multi-zone well | |
EP2115269B1 (en) | Improved system and method for stimulating multiple production zones in a wellbore | |
US20130014936A1 (en) | Ball injecting apparatus for wellbore operations with external loading port | |
AU2016253692B2 (en) | Downhole sleeve system and method | |
US20110209873A1 (en) | Method and apparatus for single-trip wellbore treatment | |
CA2975941C (en) | Atmospheric ball injecting apparatus and system | |
US20080277110A1 (en) | Hydraulic open hole packer | |
US20100108323A1 (en) | Reliable Sleeve Activation for Multi-Zone Frac Operations Using Continuous Rod and Shifting Tools | |
US20180313182A1 (en) | Wellbore sleeve injector and method of use | |
CN107208473A (en) | Multistage pressure frac system with number system | |
US20130228326A1 (en) | Ball injecting apparatus for wellbore operations with external loading port | |
US20140102717A1 (en) | Method for launching replacement balls | |
US9644441B2 (en) | Hydraulic impact apparatus and methods | |
US20160115770A1 (en) | Treatment string and method of use thereof | |
GB2448632A (en) | Multi-State object activated valve with additional isolating member | |
US9551199B2 (en) | Hydraulic impact apparatus and methods | |
CA2801677A1 (en) | Ball injecting apparatus for wellbore operations with external loading port |
Legal Events
Date | Code | Title | Description |
---|---|---|---|
STCB | Information on status: application discontinuation |
Free format text: ABANDONED -- FAILURE TO RESPOND TO AN OFFICE ACTION |