Provided is an inner string, an outer string, and a well system. The outer string, in one aspect, includes an outer tubular configured to extend at least partially around an inner tubular, the outer tubular including a seal surface. The outer string, according to one aspect, further includes two radial orientation slots located along an inside surface of the outer tubular, the two radial orientation slots offset from one another by a distance (d.sub.1), the two radial orientation slots configured to align with an orientation port in the inner tubular that it is configured to engage with to provide two pressure readings indicative of a relative location of the inner tubular to the outer tubular.

Provided is an inner string and a well system. The inner string, in one aspect, includes an inner tubular including a sidewall having a thickness (t.sub.3), the inner tubular having an orientation port extending entirely through the sidewall to provide fluid access from an interior of the inner tubular to an exterior of the inner tubular. The inner string, according to one aspect, further includes a weighted swivel located around the inner tubular, the weighted swivel including an orientation slot, the orientation slot configured to align with the orientation port to provide a pressure reading indicative of a relative location of the inner tubular to the weighted swivel.

A downhole tool for determining laterals in a borehole wall or a borehole casing, comprising a tool housing extending along a longitudinal axis and having a circumference perpendicular to the longitudinal axis and a plurality of sonic transceivers. Each sonic transceiver transmitting sonic signals from the housing and receiving sonic signals reflected from the borehole wall or borehole casing in a predefined angular segment. The sonic transceivers are arranged along the circumference of the tool housing having a mutual distance and are capable of transmitting sonic signals radially away from the tool housing in an entire central angle of 360 degrees towards the borehole wall or borehole casing. During a pulse time, one sonic transceiver transmits a sonic signal in the predefined angular segment of that sonic transmitter, and one sonic transceiver, during a subsequent echo time, receives a reflected sonic signal from the borehole wall or borehole casing.

Provided is a frac window system, a well system, and a method. The frac window system, in at least one aspect, includes an elongated tubular having a first end and a second end with an opening defined in a wall of the elongated tubular between the first end and the second end, the wall having an inner surface and an outer surface, wherein the opening in the wall is configured to align with a window of a first wellbore casing, and a spacer window sleeve positioned within the elongated tubular, the spacer window sleeve including a tubular having a first tubular end and a second tubular end with a second opening defined in a second wall of the tubular between the first tubular end and the second tubular end, the second wall having a second inner surface and a second outer surface, wherein the second opening in the second wall is configured to at least partially align with the opening in the wall of the elongated tubular.

A method and a lateral entry guide tool for deploying a work string in a wellbore defining a window and a lateral wellbore extending from the window are described. The work string and the tool are run through the wellbore to a distance above the window. A locator subassembly is activated to detect the window. The tool is run through the wellbore in a downhole direction from the distance above the window past the window. After the locator subassembly indicates that the tool is past the window, a window entry depth is determined based a depth at which the window was detected. The work string is pulled back to position the tool at the window entry depth. A positioning subassembly is activated. The work string is run through the window while adjusting and calibrating the positioning subassembly as the work string pass through the window into the lateral wellbore.

A bottom hole assembly (BHA) operable to be conveyed within a wellbore extending into a subterranean formation from a wellsite surface via coiled tubing. The BHA may operable to receive a fluid pumped from the wellsite surface via the coiled tubing. The BHA may include a fluid control tool comprising a first fluid passage extending longitudinally through the fluid control tool and a plurality of first fluid outlets extending radially between the first fluid passage and the wellbore. The fluid control tool may be selectively operable to close the first fluid passage and open the plurality of first fluid outlets to pass the fluid into the wellbore via the plurality of first fluid outlets, and close the plurality of first fluid outlets and open the first fluid passage to pass the fluid through first fluid passage. The BHA may further include a tractor operable to move the BHA along the wellbore coupled downhole from the fluid control tool. The tractor may have a second fluid passage fluidly connected with the first fluid passage. The BHA may also include a fluid outlet sub coupled downhole from the tractor having a plurality of second fluid outlets fluidly connected with the first fluid passage and extending radially outward to fluidly connect the second fluid passage and the wellbore, and a bent sub coupled downhole from the fluid outlet sub and operable for steering the BHA.

A junction for use in a multilateral completion system is presented. The junction comprises a metal sealant applicable to a lateral component of the multilateral completion system. The metal sealant is expanding in response to hydrolysis and after activation forms a seal and an anchor with a well casing or tubing of the multilateral completion system. The metal sealant is expanding in response to one of an alkaline earth metal hydrolysis and a transition metal hydrolysis. More specifically, the metal sealant is expanding in response to one of magnesium hydrolysis, aluminum hydrolysis, calcium hydrolysis, and calcium oxide hydrolysis.

A wellbore isolation system is disclosed. The wellbore isolation system includes a junction positioned at an intersection of a first wellbore and a second wellbore, and a deflector disposed in the junction such that a path into the first leg of the junction is obstructed and engaged with the first leg of the junction to form a fluid and pressure tight seal. The junction includes a first leg extending downhole into the first wellbore, and a second leg extending downhole into the second wellbore. The deflector includes a channel extending axially through the deflector, and a degradable plug disposed in the channel and engaged with the channel to prevent fluid flow through the channel.

A unitary junction for deployment in a wellbore, wherein the unitary junction permits electrical power and communications signals to be established in both a lateral wellbore and a main wellbore utilizing. The unitary junction assembly generally includes a conduit having a first upper aperture, a first lower aperture and a second lower aperture where the first lower aperture is defined at the distal end of a primary leg extending from a conduit junction and the second lower aperture is defined at the distal end of a deformable lateral leg extending from the conduit junction. A lower wireless energy transfer mechanism is positioned along at least one of the legs between the distal end of the leg and the junction. The lower wireless energy transfer mechanism is in wired communication an upper energy transfer mechanism permitting electrical communication to be established across the intersection of wellbore branches utilizing the unitary junction.

Systems and methods include a method providing automated production optimization for smart well completions using real-time nodal analysis including comingled production calibration. Real-time well rates and flowing bottom-hole pressure data are collected at various choke settings for multiple flow conditions for each lateral of a multilateral well during regular field optimization procedures. Surface and downhole pressures and production metrics for each of the laterals are recorded for one lateral at a time during production of the well. Flowing parameters of individual laterals are estimated using the multilateral well production model. An optimum pressure drop across each downhole valve is determined using the multilateral well production model. Each lateral of the multilateral well is calibrated during the commingled production at various choke valves settings. The calibrating is done using the multilateral well production model, based at least in part on the optimum pressure drop across each downhole valve.