WO1999007975A1 - Method and apparatus for drilling and completing wells - Google Patents
Method and apparatus for drilling and completing wells Download PDFInfo
- Publication number
- WO1999007975A1 WO1999007975A1 PCT/US1997/014042 US9714042W WO9907975A1 WO 1999007975 A1 WO1999007975 A1 WO 1999007975A1 US 9714042 W US9714042 W US 9714042W WO 9907975 A1 WO9907975 A1 WO 9907975A1
- Authority
- WO
- WIPO (PCT)
- Prior art keywords
- string
- well bore
- completion assembly
- drilling
- assembly
- Prior art date
Links
- 238000005553 drilling Methods 0.000 title claims abstract description 91
- 238000000034 method Methods 0.000 title claims abstract description 22
- 239000012530 fluid Substances 0.000 claims abstract description 43
- 238000004519 manufacturing process Methods 0.000 claims description 67
- 238000004891 communication Methods 0.000 claims description 6
- 230000004044 response Effects 0.000 claims description 2
- 230000000903 blocking effect Effects 0.000 claims 1
- 230000014759 maintenance of location Effects 0.000 claims 1
- 230000015572 biosynthetic process Effects 0.000 abstract description 9
- 238000012856 packing Methods 0.000 abstract description 7
- 150000001875 compounds Chemical class 0.000 description 14
- 239000002253 acid Substances 0.000 description 12
- 239000002002 slurry Substances 0.000 description 12
- 230000008901 benefit Effects 0.000 description 9
- 229930195733 hydrocarbon Natural products 0.000 description 8
- 150000002430 hydrocarbons Chemical class 0.000 description 8
- 238000011156 evaluation Methods 0.000 description 7
- 239000004576 sand Substances 0.000 description 6
- 239000004215 Carbon black (E152) Substances 0.000 description 5
- 238000003384 imaging method Methods 0.000 description 4
- 238000007789 sealing Methods 0.000 description 4
- 238000011144 upstream manufacturing Methods 0.000 description 4
- 230000000712 assembly Effects 0.000 description 3
- 238000000429 assembly Methods 0.000 description 3
- 238000009434 installation Methods 0.000 description 3
- 210000002445 nipple Anatomy 0.000 description 3
- 125000006850 spacer group Chemical group 0.000 description 3
- XLYOFNOQVPJJNP-UHFFFAOYSA-N water Substances O XLYOFNOQVPJJNP-UHFFFAOYSA-N 0.000 description 3
- 230000005540 biological transmission Effects 0.000 description 2
- 230000005251 gamma ray Effects 0.000 description 2
- 238000002347 injection Methods 0.000 description 2
- 239000007924 injection Substances 0.000 description 2
- 238000012544 monitoring process Methods 0.000 description 2
- 230000008569 process Effects 0.000 description 2
- 238000005086 pumping Methods 0.000 description 2
- 101150006257 rig-4 gene Proteins 0.000 description 2
- 239000003643 water by type Substances 0.000 description 2
- 230000003213 activating effect Effects 0.000 description 1
- 230000008859 change Effects 0.000 description 1
- 239000004020 conductor Substances 0.000 description 1
- 238000010276 construction Methods 0.000 description 1
- 239000000356 contaminant Substances 0.000 description 1
- 238000005520 cutting process Methods 0.000 description 1
- 238000011161 development Methods 0.000 description 1
- 230000000694 effects Effects 0.000 description 1
- 239000000463 material Substances 0.000 description 1
- 238000005259 measurement Methods 0.000 description 1
- 238000012986 modification Methods 0.000 description 1
- 230000004048 modification Effects 0.000 description 1
- 238000011084 recovery Methods 0.000 description 1
- 238000005070 sampling Methods 0.000 description 1
- 239000007787 solid Substances 0.000 description 1
- 239000000243 solution Substances 0.000 description 1
- 230000003068 static effect Effects 0.000 description 1
- 238000012360 testing method Methods 0.000 description 1
Classifications
-
- E—FIXED CONSTRUCTIONS
- E21—EARTH DRILLING; MINING
- E21B—EARTH DRILLING, e.g. DEEP DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
- E21B43/00—Methods or apparatus for obtaining oil, gas, water, soluble or meltable materials or a slurry of minerals from wells
- E21B43/02—Subsoil filtering
- E21B43/10—Setting of casings, screens, liners or the like in wells
-
- 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
- E21B49/00—Testing the nature of borehole walls; Formation testing; Methods or apparatus for obtaining samples of soil or well fluids, specially adapted to earth drilling or wells
- E21B49/08—Obtaining fluid samples or testing fluids, in boreholes or wells
-
- 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
- E21B7/00—Special methods or apparatus for drilling
- E21B7/04—Directional drilling
- E21B7/06—Deflecting the direction of boreholes
- E21B7/068—Deflecting the direction of boreholes drilled by a down-hole drilling motor
Definitions
- the present invention relates to drilling and completing of wells.
- the invention relates to drilling and completing of hydrocarbon wells.
- new methods of well bore construction allow for the drilling of a primary access well bore.
- the primary access well bore will have one or more branch well bores extending therefrom that will intersect certain target reservoirs.
- the invention herein described may be utilized with the drilling and completion of these branch well bores.
- the invention herein disclosed is also applicable to other types of field development.
- the apparatus may contain a work string and a completion assembly attached to the work string.
- the apparatus further contains a drilling motor assembly adapted to the work string for creating a bore hole; and, an orientation sensor adapted to the drilling motor assembly for sensing the physical location of the bit.
- the orientation sensor is placed near the bit.
- the apparatus may further comprise a formation evaluation sensor adapted to the work string for sensing the physical parameters of a subterranean reservoir and a telemetry device adapted to receive and output signals from both the orientation sensor and the formation evaluation sensor.
- a communication device may also be included for communicating an output signal from the orientation sensor and communicating the output signal to the telemetry device.
- the telemetry device then transmits the output signals to the surface.
- the drilling motor assembly comprises a motor, an adjustable kick-off sub, and a drill bit.
- This embodiment may also have a production sensor adapted to the completion assembly for sensing the production parameters of the subterranean reservoir.
- the method would include lowering the bottom hole assembly and circulating the drilling fluid through the bottom hole assembly so that the drilling motor assembly effects rotation of the bit. While drilling is proceeding, the orientation sensor will sense the physical location of the bit. The output signal is communicated to the telemetry device which ultimately transmits the orientation output signals to the surface. After analyzing the output signals, the operator may steer the bottom hole assembly for optimum placement of the completion assembly across the target zone. The method may further include pumping an acid in order to dissolve an acid soluble compound that may be contained on the completion assembly. Thereafter, the well may be placed on production. Permanent production sensors may be placed on the completion assembly and production parameters may be monitored during the life of the well.
- an apparatus for drilling and completing a well will comprise a work string attached to a completion assembly.
- a drilling motor is adapted to the work string for creating a bore hole, with the drilling motor being positioned upstream of the completion assembly.
- a bit operatively associated with the drilling motor assembly; an inner drive shaft connecting the motor with a bearing housing; and an orientation sensor adapted to the bit for sensing the physical location of said bit.
- This apparatus may also include a communication device adapted to the orientation sensor for communicating an output signal from the orientation sensor to a telemetry device, with the telemetry device being operatively associated with the work string. Also included may be a formation evaluation sensor adapted to the work string for sensing the physical parameters of a subterranean reservoir, with the formation evaluation sensor being operatively associated with the telemetry device.
- a production sensor may be adapted to the completion assembly for sensing the production characteristics of the subterranean reservoir.
- the drilling motor and inner drive shaft are selectively retrievable from the bottom hole assembly. Thus, after the drilling and completing of the well, the drilling motor and drive shaft may be retrieved from the well.
- the method for this embodiment would include lowering the bottom hole assembly into a well bore and circulating the drilling fluid so that the drilling motor assembly drills a bore hole.
- the orientation sensor would sense the physical location of the bit.
- the output signal is ultimately transmitted uphole and the bit is steered so that the completion assembly is placed across the target reservoir.
- the apparatus includes a work string, a completion assembly attached to the work string, and a drilling motor concentrically positioned within the inner diameter of the completion assembly. Also, the apparatus would include: a bit operatively associated with the drilling motor assembly; a sealing member concentrically positioned within the completion assembly and connected to the motor; and, an orientation sensor adapted to the bit for sensing the physical location of the bit.
- the apparatus may further include a communication device adapted to the orientation sensor for communicating an output signal from the orientation sensor to a telemetry device, with the telemetry device being operatively associated with the work string.
- the apparatus further comprises a formation evaluation sensor adapted to the work string for sensing the physical parameters of a subterranean reservoir, with the formation evaluation sensor being operatively associated with the telemetry device.
- This embodiment also includes a production sensor adapted to the completion assembly for sensing the production characteristics of the subterranean reservoir.
- the drilling motor and inner drive shaft is selectively retrievable by a secondary string.
- the method utilizing this embodiment includes lowering the bottom hole assembly into a well bore and circulating a fluid through the drilling motor assembly so that a bore hole is formed. Next, the physical location of the bit is determined as previously described.
- the method further comprises steering the bottom hole assembly so that a target reservoir is encountered. Thereafter, a secondary string containing a retrieving tool is lowered into the well bore and the drilling motor assembly can be retrieved.
- the method further includes positioning a production string into the well, and thereafter, the reservoir may be produced through the completion assembly.
- a production sensor may be placed on the completion assembly so that production parameters may be monitored during the life of the well. If a hydrophone sensor is placed on the production string, the method may further include monitoring a response to an acoustic event. The acoustic event may be generated from a hydrophone transmitter in the production string, or from another acoustic source elsewhere in the well bore, another well bore within the reservoir, or even from the surface.
- An advantage of the present invention includes the saving of rig time by having a well drilled and completed in one step. Another advantage includes steering the bottom hole assembly for optimum placement within a target reservoir. Another advantage includes increasing the productivity of the reservoir. Another advantage is that since the well is completed faster, there is less exposure to drilling fluid which damages the reservoir. Still yet another advantage includes using the invention with multilateral and directional well bores. Another advantage includes use of this system from a main access well bore in order to drill and complete a branch well.
- a feature of the present invention includes use of an orientation sensor that is placed near the bit. Another feature is use of a communication device that communicates the output of the orientation sensor to a telemetry apparatus for ultimate transmission to the surface.
- Another feature is the completion assembly is placed upstream of the orientation sensor so that the completion assembly is optimally placed within the target reservoir. Still yet another feature includes the use of permanent sensors on the completion assembly that will monitor the target reservoir and its production of fluid and gas. These sensors may communicate with a host module located, for instance, in a main access well bore. Another feature includes use of a motor that may be placed upstream of the completion assembly. Another feature includes use of a motor that has extending therefrom a drive shaft concentrically placed within the completion assembly for connection to a thrust bearing near the bit. This allows for the motor to be above the completion assembly and thus retrievable. Also, the completion assembly is closer to the bit, and thus, the driller does not have to drill as much additional hole to properly position the completion assembly within the reservoir.
- Another feature includes use of a slim hole motor that is concentrically placed within the completion assembly that is also selectively retrievable. Still yet another feature includes the ability to gravel pack after drilling and positioning of the completion assembly. Still yet another feature includes placement of a soluble compound about the completion assembly.
- This device may also contain completing means for completing the well, which in one embodiment would be preventing means for preventing the production of a reservoir sand into the inner diameter of the work string, also referred to as screen means.
- the steps would then include positioning the screen adjacent the target reservoir; and, placing a gravel slurry in the annulus adjacent to the target reservoir.
- the preventing means may include a soluble compound, and which would require after having the preventing means in position, displacing an acid solution means for dissolving the soluble compound; and thereafter, placing the well on production.
- Another advantage includes the ability to complete sub-sea wells without changing out the rams of the Blow Out Preventor stack since the work string may remain in place after drilling through the target reservoir. Still yet another advantage includes having a drilling bottom hole assembly attached to a production string such that the production string is drilled into the target reservoir, and the well can be placed on production without the necessity of pulling out of the hole and replacing the work string.
- Figure 1 is a partial section view of one embodiment of the present invention.
- Figure 2 is a section view of a first embodiment of a bottom hole assembly for use in the present invention.
- Figure 3 is a section view of a bottom hole assembly as shown in Fig. 2, further containing a production sensor package.
- Figure 4 is a section view of a second embodiment of a bottom hole assembly for use in the present invention.
- Figure 5 is a section view of a third embodiment of a bottom hole assembly for use in the present invention.
- Figure 6 is a section view of a fourth embodiment of a bottom hole assembly for use in the present invention.
- Figure 7A is a schematic representation of use of the present invention in a branch well bore that extends from a main access well.
- Figure 7B is an enlargement of a portion of Fig. 7 A.
- Figure 8 A is a schematic representation of use of the present invention in a first and a second branch.
- Figure 8B is an enlargement of a portion of Fig. 8 A.
- Figure 9 is a section view of a first embodiment of the present invention used for placing a gravel slurry adjacent the target reservoir.
- Figure 10 is a section view of a second embodiment of the present invention used for placing a gravel slurry adjacent the target reservoir.
- Fig. 1 depicts a semi-submersible drilling vessel 2 that has mounted thereon a drilling rig 4.
- the drilling rig 4 is typically equipped with a surface Blow-Out Preventor (BOP) stack 6 as is well known in the art.
- BOP surface Blow-Out Preventor
- a sub-sea Blow-Out Preventor stack 8 is positioned on the ocean floor 10, with a riser 12 linking the sub-sea BOP stack 8 to the surface BOP stack 6.
- Extending into the earth from the sub-sea BOP stack 8 are the well casings, specifically the conductor casing 14, the surface casing 16, and the intermediate casing 18.
- a work string 20 according to the present invention is suspended within the riser 12 and the casings 14, 16, 18.
- the work string 20 has attached thereto a bottom hole assembly 26.
- the particular work string 20 shown in Fig. 1 is a drill string, and the bottom hole assembly 26 includes a drill motor assembly 28, as well as a completion assembly 30.
- a cased hole 50 has extending therefrom an uncased bore hole 52.
- the bore hole 52 has been drilled by the drill motor assembly 28, which in this embodiment includes the bit 54, a bearing assembly 56, a centralizing sub 58, and the rotor/stator assembly 60.
- An applicable rotor/stator assembly 60 that may be used is available from the applicant, Baker Hughes Incorporated (BHI), under the product name Navi-DrillTM
- the centralizing sub 58 may contain static blades or hydraulically or mechanically extendable blades which would aid in the steering of the bottom hole assembly 26
- a lower sensor module 62 is included in the bottom hole assembly 26.
- the lower sensor module 62 can contain directional sensors such as a magnetometer, an accelerometer, an inclination instrument, and a tool face instrument, all being well known in the art and available from BHI under the product name Navi-TRAKTM.
- the lower sensor module 62 may also contain formation evaluation sensors such as resistivity and gamma ray instruments, both being well known in the art and available from BHI under the product name Navi-MPRTM (Multiple Propagation Resistivity)
- the operator may also choose to place an axial strain sensor or a torsional strain sensor on the work string 20, to measure the weight and torque that are being applied to the bit 54
- the sensors contained within the lower sensor module 62 generate output signals
- These output signals may be transmitted to a host module 64 that will receive the output signals, convert the signals to an appropriate data signal, and ultimately transmit the data signal to the surface
- a host module 64 that will receive the output signals, convert the signals to an appropriate data signal, and ultimately transmit the data signal to the surface
- This system utilizes an electromagnetic short-hop system that transmits from the sensor module to the Measurement While Drilling (MWD) host module
- the telemetry system can be mud-pulse, acoustic, electromagnetic, or other systems.
- the MWD host module 64 can contain certain other sensors such as a gamma ray instrument, a resistivity instrument, and a density instrument, all of which are available from BHI under the product name Navi-TRAKTM
- the MWD host module 64 may also contain directional sensors such as the previously described magnetometer, accelerometer, and inclination instruments These types of sensors provide lithology correlation information and directional data while drilling
- the bottom hole assembly 26 may also include an adjustable kick off tool 66 that is upstream of the rotor/stator assembly 60, but downstream of the completion assembly 30
- the adjustable kick off tool 66 is commercially available from BHI under the product name AKOTM
- a connector sub 68 that can be used to disconnect the drill motor assembly 28 from the work string 20 in the case of trouble, such as the drill motor assembly 28 becoming stuck
- the connector sub 68 commercially available from BHI under the trade name Mechanical & Hydraulic Release Sub, has a collet member 80, for attachment and release purposes In the embodiment shown in Fig.
- the connector sub 68 is threadedly attached to the MWD host module 64 and the completion assembly 30
- the completion assembly 30 is a wire screen 72 around a perforated pipe 74, which is often referred to by those of ordinary skill in the art as a gravel pack screen
- This type of completion assembly is commercially available from BHI under the product name BAKERWELDTM. It should be understood, however, that other types of screens are available such as the slotted liner, and prepacked screens
- An acid soluble compound is placed in apertures of the completion assembly 30
- the soluble compound keeps solids, such as drill cuttings and drilling fluid contaminants, from plugging the completion assembly 30
- the soluble compound can be a wax material, although other soluble compounds can be used
- the soluble compound must be robust enough to withstand pressure differentials over 1000 psi, to temporarily seal the completion assembly 30 against the pressure drop in the drilling fluid as it drives the rotor/stator assembly 60 and the pressure drop caused by nozzles in the bit 54
- the completion assembly 30 is connected to a spacer pipe 76, which in turn is connected to another connector sub 78, similar to the connector sub 68
- the connector sub 78 also has a collet 80 Below the upper connector sub 78, the work string 20 has attached thereto a hang and release packer 82 that enables the lower portion of the work string 20 to be hung on the intermediate casing 18
- the hang and release packer 82 is commercially available from BHI under the product name Retrievable Hydraulic Set Packer The hang and release packer 82 can be installed on the spacer pipe 76
- the production sensor assembly 84 is able to monitor the gas-oil ratio, the water-oil ratio, and the gas-water ratio, as well as the pressure and temperature of the reservoir These are all important factors in evaluating the reservoir performance for ultimate recovery
- the production sensor assembly 84 will be capable of monitoring the fluid stream from the reservoir throughout the life of the well Analysis of data received from the production sensor assembly 84 will enable the operator to monitor the production profile and reservoir characteristics through time.
- the operator may also choose to install a series of hydrophone sensors in the production sensor assembly 84, that can detect acoustic signals in the reservoir, originating from a well bore or from the surface.
- the hydrophone sensors can also sense micro-seismic events in the reservoir, such as small slip plane or fault movement.
- the phones could be used as part of cross well acoustic imaging, near well acoustic imaging, reservoir imaging, and as receivers for imaging via a surface seismic source.
- the production sensor assembly 84 may communicate with a host controller (not shown), as is well known in the art.
- the host controller may be located at some point in the intermediate casing 18. In the case of a branch well extending from a main access well bore, the host controller may be located in the main access bore, and other production sensor assemblies in other branch wells can also communicate with the host controller.
- the production sensor assembly 84 may communicate with the host controller via a short-hop telemetry system, or the connection may be hard-wired.
- Fig. 4 shows a second embodiment of the bottom hole assembly 26, similar to the embodiment of Fig. 3, except that the adjustable kick-off sub 66 has been moved to a location below the rotor/stator assembly 60.
- a flexible u-joint may be included in the adjustable kick-off sub 66.
- the cased hole 50 is drilled and cased, as is well known in the art.
- the work string 20 and bottom hole assembly 26 of the present invention are used for this purpose, resulting in the bottom hole assembly 26 being positioned within the cased hole 50.
- the work string 20 may be a drill pipe, coiled tubing, or small diameter pipe.
- a larger drilling rig may have been used to drill and case the hole. If so, the bottom hole assembly 26 may be run in and set via the hang and release packer 82. Then, the larger drilling rig may be immobilized and a smaller, less expensive rig may be used to further drill and complete the well, in accordance with the present invention.
- the operator first makes sure that the hang and release packer 82 is not set. Then, a drilling fluid is pumped down the inner bore 86 of the work string 20. The drilling fluid flows through the drill motor assembly 28, resulting in rotation of the bit 54. The return path of the drilling fluid is up the annulus 88 to the surface. In the embodiment of Figs. 2 and 3, only the bit 54 rotates; however, in the embodiment of Fig. 4, both the lower sensor module 62 and the bit 54 may rotate.
- the lower sensor module 62 constantly monitors the orientation of the bit 54 by taking accelerometer, magnetometer, inclination and tool face readings and generating output signals representative thereof.
- the magnetometer/accelerometer measures the earth's magnetic and gravitational fields to derive a directional survey.
- the output signal of the lower sensor module 62 is then transmitted via the short-hop telemetry transmitter to the MWD host module 64.
- the host module 64 processes the sensor signals and then transmits data uphole.
- the host module 64 can contain a mud-pulse valve; however, other types of telemetry devices can be used, such as acoustic, electromagnetic or others.
- the host module 64 also contains sensors which are sampling certain reservoir characteristics, and the outputs of these sensors are transmitted uphole via the telemetry system. This data is also used in order to steer the bottom hole assembly 26 for optimum placement of the completion assembly 30 relative to the target reservoir 24, for instance, across the target reservoir 24.
- the steering takes place by intermittently rotating or turning the work string 20, activating ribs on the centralizing sub 58, or adjusting the adjustable kick off sub 66.
- the soluble compound can then be removed from the completion assembly 30 by pumping an acid down the work string 20.
- the well may then be placed in production. Alternatively, the operator may desire to gravel pack the well, and thereafter, begin production.
- the operator can release the work string 20 from the bottom hole assembly 26 with the connector sub 78 and pull out of the well. Then, a production string may be lowered into the well and stabbed into the bottom hole assembly 26. A gravel pack may be performed, either with the original work string 20, or alternatively, after the production string has been connected
- a retrievable rotor/stator assembly 60 is positioned above the completion assembly 30
- the work string 20 has attached thereto the hang and release packer 82 along with the connector sub 78
- the rotor/stator assembly 60 is attached to a motor drive shaft 90 that passes concentrically through the center of the completion assembly 30 to the adjustable kick off sub 66
- the drive shaft 90 is removably mated to a flex joint located within the adjustable kick off sub 66, such as by means of a simple longitudinal spline connection
- the completion assembly 30 is closer to the bit
- the rotor/stator assembly 60 and the drive shaft 90 are retrievable from the completion assembly 30
- the operator circulates drilling fluid down the internal bore 86 of the work string 20 and through the rotor/stator assembly 60 Rotation is imparted to the bit 54 via the flex joint and the drive shaft 90, rotating within the completion assembly 30
- the lower sensor module 62 generates output signals which are received by the host module for ultimate telemetry to the surface, all as previously described
- the output signals from the sensors contained within the host module will also be transmitted to the surface
- the operator may steer the bottom hole assembly 26 into proper placement relative to the target reservoir 24
- an acid soluble compound may be pumped down to dissolve it Gravel packing the well may also take place at this point, or after a production string is in place Then, the operator can retrieve the work string 20 along with the rotor/stator assembly 60, the flex joint, and the drive shaft 90 Thereafter, the production string is run into the well and stabbed into the bottom hole assembly 26 The well is then capable of producing the reservoir fluids Alternatively, the well may be used for injection purposes, as desired
- a small diameter rotor/stator assembly 60 is positioned within the completion assembly 30
- a sealing string 92 is attached to the rotor/stator assembly 60 and then sealed into the connector sub 78
- the drive shaft 90 extends from the rotor/stator assembly 60 to the flex joint contained within the adjustable kick off sub 66
- Small diameter motors such as the one depicted are commercially available from BFfl under the product name Navi-DrillTM.
- the remainder of the bottom hole assembly 26 is comparable to the embodiment of Fig. 5, and the hang and release packer 82 is used.
- a lower sensor module 62 is included below the AKO 66, to generate output signals that will be received by the host module for ultimate transmission to the surface by the host module's telemetry system.
- the operator circulates drilling fluid down the internal bore 86 of the work string 20 and through the rotor/stator assembly 60. Rotation is imparted to the bit 54 via the flex joint and the drive shaft 90.
- the sealing string 92 assures that the drilling fluid does not exit the bottom hole assembly 26 through the completion assembly 30.
- a seal must be provided at the lower end of the rotor/stator assembly 60, to prevent drilling fluid backflow up around the rotor/stator assembly 60.
- the lower sensor module 62 As drilling proceeds, the lower sensor module 62 generates output signals which are received by the host module for ultimate telemetry to the surface, all as previously described. The output signals from the sensors contained within the host module are also transmitted to the surface. After analysis of the data, the operator may steer the bottom hole assembly 26 into proper placement relative to the target reservoir 24.
- an acid may be pumped down, in order to dissolve it. Gravel packing the well may also take place at this point, or alternatively, after the production string is in place. Then, the operator can retrieve the work string 20 along with the rotor/stator assembly 60, the flex joints, the drive shaft 90, and the sealing string 92. Thereafter, the production string is run into the well and stabbed into the bottom hole assembly 26. The well is then capable of producing the reservoir fluids. Alternatively, the well may be used for injection purposes.
- Figs. 7A and 7B depict use of the present invention with a main access well bore
- the main access well bore 100 has therein a plurality of windows 102, 104, 106, 108 that will allow for the drilling of branch wells.
- the windows 102, 104, 106 and 108 are placed so that the branch wells are optimally placed for completion relative to a plurality of reservoirs 110, 112, 114, 116.
- a branch well bore 118 has been drilled to the reservoir 112 with a bottom hole drilling assembly 120 similar to the bottom hole assembly 26 shown in Fig. 6.
- the hang and release packer 82 has been set, the connector sub 78 has been released, and the drill string has been pulled out of the well, leaving the bottom hole assembly 120 in place.
- a second work string such as drill pipe, production tubing, coiled tubing, or snubbing pipe, and stabs into the bottom hole assembly 120.
- the drilling fluid is then pumped down through the work string and motor to rotate the bit 54.
- the entire bottom hole assembly 120 is then steered to the desired position relative to the reservoir 112.
- the branch 118 has been drilled through the target reservoir 112, and a second branch well bore 122 has been drilled to the reservoir 110 with the bottom hole assembly 124 which is similar to the bottom hole assembly of Fig. 6.
- the procedure includes drilling the first branch well bore 118 with the bottom hole assembly 120 so that the completion assembly 30 is adjacent the target site. Then, the work string is disconnected from the bottom hole assembly 120, and retrieved from the main access well 100. The work string is run back into the well 100 with the bottom hole assembly 124 attached thereto. Through the window 102, the well bore 122 is created by drilling with the bottom hole assembly 124 as previously described.
- the bottom hole assembly 124 is steered into intersection with the reservoir 110, and the work string is then pulled out of the well. Thereafter, production strings may be run into the well 100 and connected to the bottom hole assemblies 120, 124, or other branch wells may be drilled to the other reservoirs 114, 116.
- the reservoir fluids may be produced via individual production strings or a series of interconnected conduits, while using the production sensor assemblies 84, if desired.
- the present invention also provides for the placement of a gravel pack slurry in the annulus 210 adjacent a target reservoir 242.
- the work string 20 for this embodiment includes the previously described bottom hole assembly 26, with the rotor/stator assembly 220, a bit 218, and a completion assembly 228.
- bottom hole assembly 26 include a gravel pack extension and crossover tool 260 commercially available from Baker Hughes Incorporated under the trade name Model "S-2" Cross-OverTM, and the "S-l” Gravel Pack ExtensionTM.
- the gravel pack extension and crossover tool 260 contains a sliding sleeve 262 that is slidable from a closed position to an open position.
- the sliding sleeve 262 is actuated by dropping a ball (not shown) from the surface, with the ball coming to rest on the sliding sleeve 262.
- a ball not shown
- the operator By pressuring up on the internal bore 86 of the work string, the operator causes the ball to force the sliding sleeve 262 to an open position.
- the work string 20 includes a packer 266 that will sealingly engage the intermediate casing 18, so that an upper annulus 208 and a lower annulus 210 are formed.
- the packer 266 will have operatively connected thereto a setting tool 267, with the associated wash pipe extending therefrom, with the entire assembly being well known in the art and commercially available from Baker Hughes Incorporated under the trade name "SC" Setting ToolTM. Alternatively, the "BDP" Setting ToolTM may be used.
- wash pipe serves as a conduit for the drilling fluid during the drilling phase.
- the path of the fluid during drilling is through the inner diameter of the work string 20, through the packer 266, into the wash pipe and through the rotor/stator assembly 220.
- the wash pipe it is not necessary to place the acid soluble compound about the completion assembly 228.
- the packer 266 is released from the wash pipe and setting tool 267 by rotating the work string 20 so that the setting tool 267 and wash pipe disengage from the packer 266. Thereafter, the setting tool 267 may be picked up, which in turn lifts the wash pipe which had been previously stung into the top of the rotor/stator assembly 220. The entire wash pipe assembly is lifted up so that the end of the wash pipe is adjacent the completion assembly 228. In this position, the well can be gravel packed. As previously mentioned, the sliding sleeve 262 had been opened, thus, once the wash pipe is in the proper position, the gravel packing process may begin and the sand slurry is pumped down the inner bore 86 of the work string 20.
- the sand slurry exits into the annulus 210 at ports 264 and 265 into the lower annulus 210.
- the fluid of the sand slurry will be returned through the porous sand screen on the completion assembly 228 and into the bottom of the wash pipe, and then up through the inner bore of the wash pipe.
- the fluid is ultimately crossed-over to the upper annulus 208.
- FIG. 10 an alternate embodiment of the present invention is depicted, that can be used when gravel packing is desirable.
- the bottom hole assembly 26, including the completion assembly 228, the rotor/stator assembly 220, and the bit 218, is essentially the same as those depicted in Figs. 2 and 3.
- Fig. 10 depicts a production type of packer 274 that is connected to the work string.
- the production packer 274 is commercially available from Baker Hughes Incorporated under the name Retrievable Hydraulic Set Packer. Extending downward from the production packer 274 is the connector 276 for landing the packer 274.
- the procedure for drilling, completing and gravel packing the hydrocarbon reservoir 242 with this embodiment begins with drilling through the target reservoir 242 as previously described with the bottom hole assembly depicted in Figs. 2 and 3.
- the lower annulus 210 can be gravel packed by circulating a gravel pack slurry down the upper annulus 208 and getting the fluid returns through the completion assembly 228.
- the packer 274 is not placed on the original bottom hole assembly 26, because the outer diameter of the packer 274 is too large, and it would prevent the gravel slurry from being effectively pumped down hole, since the slurry would bridge about the packer 274.
- the work string is detached from the remainder of the bottom hole assembly 26, utilizing the connector sub 78 that is positioned above the completion assembly 228, as previously described in Fig. 3.
- the connector sub 78 and work string have been pulled from the wellbore, the outer diameter nipple profile 277 remains in the well bore with the rest of the bottom hole assembly 26.
- a production tubing string is run back into the wellbore, with the production tubing string having the previously mentioned packer 274 and the connector 276 extending therefrom.
- the connector 276 will be stung into and attach with the outer diameter nipple profile 277.
- the packer 274 is set against the casing string by hydraulic means such as pressuring up on the annulus. After the packer is set and an upper annulus 208 and lower annulus 210 are formed, the well may then be placed in production.
Abstract
Description
Claims
Priority Applications (5)
Application Number | Priority Date | Filing Date | Title |
---|---|---|---|
CA002268256A CA2268256A1 (en) | 1997-08-08 | 1997-08-08 | Method and apparatus for drilling and completing wells |
GB9907958A GB2333789A (en) | 1997-08-08 | 1997-08-08 | Method and apparatus for drilling and completing wells |
PCT/US1997/014042 WO1999007975A1 (en) | 1997-08-08 | 1997-08-08 | Method and apparatus for drilling and completing wells |
AU40585/97A AU4058597A (en) | 1997-08-08 | 1997-08-08 | Method and apparatus for drilling and completing wells |
NO991668A NO991668L (en) | 1997-08-08 | 1999-04-08 | Method and apparatus for drilling and completing wells |
Applications Claiming Priority (1)
Application Number | Priority Date | Filing Date | Title |
---|---|---|---|
PCT/US1997/014042 WO1999007975A1 (en) | 1997-08-08 | 1997-08-08 | Method and apparatus for drilling and completing wells |
Publications (1)
Publication Number | Publication Date |
---|---|
WO1999007975A1 true WO1999007975A1 (en) | 1999-02-18 |
Family
ID=22261420
Family Applications (1)
Application Number | Title | Priority Date | Filing Date |
---|---|---|---|
PCT/US1997/014042 WO1999007975A1 (en) | 1997-08-08 | 1997-08-08 | Method and apparatus for drilling and completing wells |
Country Status (4)
Country | Link |
---|---|
AU (1) | AU4058597A (en) |
CA (1) | CA2268256A1 (en) |
GB (1) | GB2333789A (en) |
WO (1) | WO1999007975A1 (en) |
Families Citing this family (1)
Publication number | Priority date | Publication date | Assignee | Title |
---|---|---|---|---|
GB9903256D0 (en) | 1999-02-12 | 1999-04-07 | Halco Drilling International L | Directional drilling apparatus |
Citations (11)
Publication number | Priority date | Publication date | Assignee | Title |
---|---|---|---|---|
US4942926A (en) * | 1988-01-29 | 1990-07-24 | Institut Francais Du Petrole | Device and method for carrying out operations and/or manipulations in a well |
WO1992008875A2 (en) * | 1990-11-20 | 1992-05-29 | Framo Developments (Uk) Limited | Well completion system |
US5148875A (en) * | 1990-06-21 | 1992-09-22 | Baker Hughes Incorporated | Method and apparatus for horizontal drilling |
US5197553A (en) * | 1991-08-14 | 1993-03-30 | Atlantic Richfield Company | Drilling with casing and retrievable drill bit |
US5255741A (en) * | 1991-12-11 | 1993-10-26 | Mobil Oil Corporation | Process and apparatus for completing a well in an unconsolidated formation |
US5320178A (en) * | 1992-12-08 | 1994-06-14 | Atlantic Richfield Company | Sand control screen and installation method for wells |
US5472057A (en) * | 1994-04-11 | 1995-12-05 | Atlantic Richfield Company | Drilling with casing and retrievable bit-motor assembly |
EP0713951A2 (en) * | 1994-11-22 | 1996-05-29 | Baker Hughes Incorporated | Method of drilling and completing wells |
US5531273A (en) * | 1994-03-22 | 1996-07-02 | Bestline Liner Systems | Well completion tool and process |
WO1996030625A1 (en) | 1995-03-27 | 1996-10-03 | Baker Hughes Incorporated | Hydrocarbon production using multilateral well bores |
DE19535906A1 (en) * | 1995-09-27 | 1997-04-03 | Becfield Drilling Services Gmb | Process for the production of a cased extraction well |
Family Cites Families (1)
Publication number | Priority date | Publication date | Assignee | Title |
---|---|---|---|---|
DE1953590C3 (en) * | 1969-10-24 | 1983-02-10 | Leo P.H. Dipl.Rer.Pol. 7000 Stuttgart Keller | Process for influencing the planographic printing process and planographic printing machine for this purpose |
-
1997
- 1997-08-08 AU AU40585/97A patent/AU4058597A/en not_active Abandoned
- 1997-08-08 CA CA002268256A patent/CA2268256A1/en not_active Abandoned
- 1997-08-08 GB GB9907958A patent/GB2333789A/en active Pending
- 1997-08-08 WO PCT/US1997/014042 patent/WO1999007975A1/en active Application Filing
Patent Citations (11)
Publication number | Priority date | Publication date | Assignee | Title |
---|---|---|---|---|
US4942926A (en) * | 1988-01-29 | 1990-07-24 | Institut Francais Du Petrole | Device and method for carrying out operations and/or manipulations in a well |
US5148875A (en) * | 1990-06-21 | 1992-09-22 | Baker Hughes Incorporated | Method and apparatus for horizontal drilling |
WO1992008875A2 (en) * | 1990-11-20 | 1992-05-29 | Framo Developments (Uk) Limited | Well completion system |
US5197553A (en) * | 1991-08-14 | 1993-03-30 | Atlantic Richfield Company | Drilling with casing and retrievable drill bit |
US5255741A (en) * | 1991-12-11 | 1993-10-26 | Mobil Oil Corporation | Process and apparatus for completing a well in an unconsolidated formation |
US5320178A (en) * | 1992-12-08 | 1994-06-14 | Atlantic Richfield Company | Sand control screen and installation method for wells |
US5531273A (en) * | 1994-03-22 | 1996-07-02 | Bestline Liner Systems | Well completion tool and process |
US5472057A (en) * | 1994-04-11 | 1995-12-05 | Atlantic Richfield Company | Drilling with casing and retrievable bit-motor assembly |
EP0713951A2 (en) * | 1994-11-22 | 1996-05-29 | Baker Hughes Incorporated | Method of drilling and completing wells |
WO1996030625A1 (en) | 1995-03-27 | 1996-10-03 | Baker Hughes Incorporated | Hydrocarbon production using multilateral well bores |
DE19535906A1 (en) * | 1995-09-27 | 1997-04-03 | Becfield Drilling Services Gmb | Process for the production of a cased extraction well |
Also Published As
Publication number | Publication date |
---|---|
GB2333789A (en) | 1999-08-04 |
GB9907958D0 (en) | 1999-06-02 |
CA2268256A1 (en) | 1999-02-18 |
AU4058597A (en) | 1999-03-01 |
Similar Documents
Publication | Publication Date | Title |
---|---|---|
US5667023A (en) | Method and apparatus for drilling and completing wells | |
EP0713953B1 (en) | Method of drilling and completing wells | |
AU2003210744B2 (en) | Well system | |
US5842528A (en) | Method of drilling and completing wells | |
CA2448419C (en) | Instrumentation for a downhole deployment valve | |
AU743707B2 (en) | Well system | |
US6397946B1 (en) | Closed-loop system to compete oil and gas wells closed-loop system to complete oil and gas wells c | |
US6868906B1 (en) | Closed-loop conveyance systems for well servicing | |
AU2002324484B2 (en) | Method and apparatus to monitor, control and log subsea oil and gas wells | |
US5680901A (en) | Radial tie back assembly for directional drilling | |
CN102007264B (en) | Method and apparatus for programmable pressure drilling and programmable gradient drilling, and completion | |
CN101929335A (en) | The concentrated sampling of formation fluid | |
CA2626923A1 (en) | Wellbore system | |
US6138756A (en) | Milling guide having orientation and depth determination capabilities | |
EP2815056B1 (en) | Swelling debris barrier and methods | |
US11047211B2 (en) | Reverse circulation debris removal tool for setting isolation seal assembly | |
GB2359574A (en) | Access and flow control between a main and lateral bore | |
EP2964873B1 (en) | Wireline assisted coiled tubing portion and method for operation of such a coiled tubing portion | |
WO1999007975A1 (en) | Method and apparatus for drilling and completing wells | |
Juiniti et al. | Campos Basin: Lessons learned and critical issues to be overcome in drilling and completion operations | |
Larimore et al. | Field cases of cost-efficient slickline well interventions | |
Yamamoto et al. | Offshore Deep-Water Drilling | |
Wodka et al. | Underbalanced coiled tubing drilled horizontal well in the North Sea | |
US20100163309A1 (en) | Sub-Surface Deployment Valve | |
Dyson | Well Engineering |
Legal Events
Date | Code | Title | Description |
---|---|---|---|
AK | Designated states |
Kind code of ref document: A1 Designated state(s): AU CA GB NO |
|
AL | Designated countries for regional patents |
Kind code of ref document: A1 Designated state(s): AT BE CH DE DK ES FI FR GB GR IE IT LU MC NL PT SE |
|
ENP | Entry into the national phase |
Ref document number: 2268256 Country of ref document: CA Ref country code: CA Ref document number: 2268256 Kind code of ref document: A Format of ref document f/p: F Ref country code: GB Ref document number: 9907958 Kind code of ref document: A Format of ref document f/p: F |
|
121 | Ep: the epo has been informed by wipo that ep was designated in this application | ||
122 | Ep: pct application non-entry in european phase |