Abstract: A one-trip system for milling a window using a whipstock is disclosed. The whipstock can be set on a packer or anchor which can be an electric line-type packer which, without modifications, can be set with the hydraulic mechanism disclosed so as to avoid the need for running a wireline rig. The assembly of the packer or anchor and whipstock is run into the wellbore in a single trip, with a mill or mills capable of milling a window. At the conclusion of the milling, the mill or mills are retrieved. Thereafter, a retrieving tool is attached to the whipstock and facilitates a release of the setting tool from the packer so that the setting tool and the whipstock are retrieved together.

Abstract: A method for completing multi-lateral wells and maintaining selective re-entry into laterals is presented. In accordance with the present invention, a first lateral well is drilled from a primary well bore and a string of external casing packers and a packer bore receptacle are run therein. Once the orientation of the packer bore receptacle is determined, an orientation anchor of a retrievable whipstock assembly is mounted thereto. Thereafter, a second lateral well may be drilled. Once the second lateral well is drilled, the whipstock assembly may be retrieved and replaced with a scoophead diverter assembly which also includes an orientation anchor for mating with the packer bore receptacle. At this time, a string of external casing packers may be run into the second lateral well through the scoophead diverter assembly. Finally, a selective reentry tool is run into the scoophead assembly. The selective re-entry tool includes a diversion flapper for selecting either the first or second lateral well bore.

Abstract: The present invention relates to two improved methods for multilateral completion and cementing (e.g. sealing) the juncture between primary and lateral wellbores. These two completion methods of the present invention address the issue of cementation of the lateral wellbores for the purpose of zonal isolation. It is desirable to have the ability to re-enter each lateral wellbore as well as maintain the option to perform any function that could be done in a single wellbore. For this reason, cemented lateral wellbores are desirable so that normal isolation, stimulation or any other operation can be achieved. The methods allow sealing and reworking of either wellbores with single laterals or multiple laterals and provide safe durable junctions therebetween.

Abstract: A method is presented involving the use of measurement-while-drilling (MWD) devices and tools for well completion (including multi-lateral well completion). While MWD techniques have been known for many years and in that time, have gained wide acceptance, the use of MWD has been limited only to borehole drilling, particularly directional drilling. However, it has now been discovered that MWD may be advantageously used in wellbore completions and particularly multi-lateral completions. Examples of successful applications of MWD in completions are provided with regard to lateral wellbores which may be installed at depths of 10,000 ft. or more, and which range from vertical to horizontal. Such examples include the running of a scoophead/diverter assembly and a parallel seal assembly where it is desirable to align the tools at approximately the position at which they will engage with mating equipment.

Abstract: A method for completing multi-lateral wells and maintaining selective re-entry into laterals is presented. In accordance with the present invention, a first lateral well is drilled from a primary well bore and a string of external casing packers and a packer bore receptacle are run therein. Once the orientation of the packer bore receptacle is determined, an orientation anchor of a retrievable whipstock assembly is mounted thereto. Thereafter, a second lateral well may be drilled. Once the second lateral well is drilled, the whipstock assembly may be retrieved and replaced with a scoophead diverter assembly which also includes an orientation anchor for mating with the packer bore receptacle. At this time, a string of external casing packers may be run into the second lateral well through the scoophead diverter assembly. Finally, a selective reentry tool is run into the scoophead assembly. The selective re-entry tool includes a diversion flapper for selecting either the first or second lateral well bore.

Abstract: A scoophead/diverter assembly functions to orient and anchor multiple tubing strings at the Y-juncture in an oil or gas well with multiple lateral wellbores. An important advantage of this arrangement is to provide communication to multiple reservoirs or tap different locations within the same reservoir, and enable re-entry to these wellbores for remediation and stimulation. The large bore of the scoophead enables a secondary wellbore's production tubing (liner) to pass through until the top of the liner is in the scoophead. In order to effect a seal inside the scoophead, a novel offset parallel seal assembly with centralizer is utilized. This parallel seal assembly carries compressive loads on the primary wellbore side, and has a shear out mechanism on the secondary wellbore side. This seal assembly also may constitute the connection between the scoophead and a selective re-entry tool (SRT).

Abstract: A novel scoophead/diverter assembly is presented which is installed at the juncture between a primary wellbore and a lateral branch and which allows the production tubing of each to be oriented and anchored. This scoophead/diverter assembly further provides dual seal bores for tying back to the surface with either a dual packer completion or a single tubing string completion utilizing a selective re-entry tool. The scoophead/diverter assembly comprises a scoophead, a diverter sub, two struts as connecting members between the scoophead and diverter sub and a joint of tubing communicating from the scoophead, thru the diverter sub, and to the primary wellbore. The scoophead has a large and small bore. The large bore is a receptacle for a tie back sleeve run on top of the lateral wellbore string, and the small bore is a seal bore to tie the primary wellbore back to surface. Below the scoophead, a joint of tubing is threaded to the small bore.

Abstract: In a wellbore having at least one lateral or branch wellbore extending therefrom, a selective re-entry tool is presented for running on a completion string to enable an operator to select the branch desired so as to enter such desired branch with a coil tubing workstring (or the like) and perform an appropriate operation (e.g., stimulation, fracture, cleanout, shifting, etc.). In a preferred embodiment, the selective re-entry tool includes an outer stationary sub and an inner longitudinally shiftable mandrel or sleeve. Preferably, this sleeve is connected to a rectangular box which is spaced from an exit sub having a pair of exit openings. A flapper is pivotally connected at the intersection between the exit opening to the box by a pair of rails or pivot pins. Laterally extending ears on opposed sides of the flapper are received in a respective pair of elongated ramped guide slots formed on opposed lateral surfaces of the box.

Abstract: In accordance with the present invention, a plurality of methods and devices are provided for solving important and serious problems posed by lateral (and especially multilateral) completion in a wellbore including methods and devices for sealing the junction between a vertical and lateral well. Methods are disclosed wherein deformable devices are utilized to selectively seal the juncture between the vertical and lateral wells. Such deformable devices may comprise (1) an inflatable mold which utilizes a hardenable liquid (e.g., epoxy or cementious slurry) to form the seal; (2) expandable memory metal devices; and (3) swaging devices for plastically deforming a sealing material.

Abstract: The apparatus of the present invention is a retrievable packer which provides for release between a mandrel and a packing element support structure by virtue of a rotational movement The apparatus is configured so that the packer can be set by letting up on a tubing string or, in some applications where sufficient weight is unavailable, by pulling up on the tubing string. The slips feature a locking mechanism to secure the packing element against the wellbore W. A release mechanism is provided to defeat the lock mechanism and to act upon the slips to draw them inwardly so the apparatus can be removed from the wellbore W.

Abstract: A dual seal packer is shown having a central mandrel which carries upper and lower seal assemblies which straddle an outer cage assembly. Rocker type slips are carried in the cage assembly and are set by a single expander ring. Special support surfaces on the slips cooperate with mating support surfaces on the cage assembly to provide support for the slips under tensive and compressive loading. The slips and upper and lower seal assemblies are set in a single step operation by rotating the mandrel to the right while holding tension on the well string from the surface.

Abstract: A well packer as shown having a shear release mechanism located internally within a packer body which allows the shear release value to be easily varied. A lock body and internal piston ring are initially static. An engagement surface on the lock body cooperates with the setting sleeve to lock setting force into the packing elements. A straight upward pull on the packer mandrel, allows the piston and lock body to become dynamic to relax the packing elements and allow the well packer to be retrieved to the well surface.