Abstract: A bowl that has a beach at a beach angle to a horizontal axis and a lip at a lip angle relative to the horizontal axis. The bowl is configured to contain a substance in a concave inner portion between the beach, lip and between two sides connecting the lip and beach. The beach angle and lip angle allow for maximized scoping of the substance in the concave inner portion, but providing a low contact entry and a lip that forces the substance onto the dipping instrument.

Abstract: Goggles for use in water that are configured to guide a person along predetermined courses. The goggles can have a pair of indicators that can be in communication with a microprocessor. The microprocessor can actuate the indicators selectively to guide a person wearing the goggles along a predetermined course.

Abstract: Goggles for use in water that are configured to guide a person along predetermined courses. The goggles can have a pair of indicators that can be in communication with a microprocessor. The microprocessor can actuate the indicators selectively to guide a person wearing the goggles along a predetermined course.

Abstract: Goggles for use in water comprising a frame, a first lens operatively secured in a frame, a second lens operatively secured in the frame, a first indicator adjacent the first lens, a second indicator adjacent the second lens, and a housing connected with both ends of the frame wherein the housing is in communication with the indicators.

Abstract: A downhole tool and method for performing to provide a flow path from an inner bore thereof to a wellbore annulus, wherein the flow path is provided upon the application of pressure.

Abstract: A clamping apparatus allowing a downhole line to be fed between downhole tubular members. The clamping apparatus can include a first and second half, each including: support arms with inner surfaces, connecting walls, and grips. The first and second halves can be selectively connectable. The clamping apparatus can include handles, hinges, and latches. A system for feeding a downhole line between an outer tubular member and an inner tubular member can include an outer tubular member disposed about an inner tubular member, wherein the clamping apparatus is disposed about the inner tubular member.

Abstract: A downhole shifting mechanism having an inner tubular member, an outer tubular member, a piston, a first set of teeth, a sliding block, a body lock ring, a first flow path, and a second flow path is described herein. A downhole assembly can include the downhole shifting mechanism with a downhole tool connected to a second end of the downhole shifting mechanism. Also described is a method for shifting a downhole tool disposed within a wellbore.

Abstract: One or more embodiments of a selectively openable and closable downhole tool. The wherein, the downhole tool can include an outer tubular member having an annulus port formed therethrough. The downhole tool can also include an inner tubular member. The inner tubular member can include an inner port. The inner port and annulus port can be selectively aligned to form a flow path therethrough by moving the inner tubular member relative to the outer tubular member. The downhole tool can also include a logic drum configured to selectively move the inner tubular member. The downhole tool can also include a piston assembly configured to move the logic drum.

Abstract: A method for feeding a downhole line between two tubulars is provided. The method can include connecting a clamping apparatus about a first tubular member. The method can include supporting a second tubular member with a support surface of the clamping apparatus, feeding a downhole line through a pass through channel formed between the clamping apparatus and a tubular member, and communicating the downhole line with a tool. The clamping apparatus can include two halves, each with support arms, connecting walls, and grips.

Abstract: A multiple-positioning mechanical shifting system including for used in hydrocarbon wells. The system includes a shifting tool capable of selectively positioning a mechanical sliding sleeve valve in multiple operational positions that varying the flow rate and/or volume of tubing string fluid flowing to the well annulus. The system also includes a multiple position mechanical choke valve. A method of operating the mechanical choke valve using the shifting tool is described.

Abstract: A bypass device for bypassing a hydraulic piston in a wellbore with an outer tubular body. The outer tubular body can have a fluid control manifold. The fluid control manifold can have two control paths, two high pressure fluid paths, and two valves connecting with two high pressure fluid connecting paths. An inner tubular body can be disposed within the outer tubular body, and a piston chamber can be disposed between the inner tubular body and the outer tubular body. The piston chamber can include two piston chamber sections separated by a hydraulic piston.

Abstract: A downhole filter with a filter housing having a top filter and a bottom filter disposed therein. The filter housing can be in fluid communication with each filter. Each filter can be in fluid communication with a burst disk housing having a burst disk module and a burst disk. Each burst disk housing can be in fluid communication with the filter housing. Fluid can flow through the filter housing and through the filter. When a filter is clogged, the fluid can burst a burst disk, thereby bypassing the filter. The downhole filter can include a middle sub in fluid communication with the top filter and a second portion of the filter housing. The middle sub can threadably engage a bottom burst disk housing.

Abstract: A multiple-positioning mechanical shifting system including for used in hydrocarbon wells. The system includes a shifting tool capable of selectively positioning a mechanical sliding sleeve valve in multiple operational positions that varying the flow rate and/or volume of tubing string fluid flowing to the well annulus. The system also includes a multiple position mechanical choke valve. A method of operating the mechanical choke valve using the shifting tool is described.

Abstract: A method for connecting control lines to well bore equipment for controlling a well on a batch basis. A batch basis as used herein can mean that the well is controlled periodically. A first half of the pin connector can be formed by securing an extending hydraulic wet connector to a lower tubular portion. The lower tubular portion can have a lower tubular body, a first pin, and a lower hydraulic flow path.

Abstract: A double pin connector with hydraulic connect and seal assembly having a top portion. The top portion has an upper tubular portion. The upper tubular portion engages an intermediate tubular portion. The intermediate tubular portion has an upper flow path in fluid communication with the first hydraulic connector and a plurality of seals comprising at least one second hydraulic flow path seal.

Abstract: A double pin connector with hydraulic connect and seal assembly having a top portion. The top portion has an upper tubular portion. The upper tubular portion engages an intermediate tubular portion. The intermediate tubular portion has an upper flow path in fluid communication with the first hydraulic connector and a plurality of seals comprising at least one second hydraulic flow path seal.

Abstract: A method for injecting fluid into a well or producing fluid from a well comprising providing one or more single fluid line sliding sleeve downhole tool assemblies into a well in a closed position, applying a first pressure from a fluid source simultaneously to open at least one of the single fluid line sliding sleeve downhole tool assemblies, and allowing fluid to move into tubing or into a reservoir. The method contemplates the use of multiple single fluid line sliding sleeve downhole tool assemblies, wherein the first pressure causes only one of the tool assemblies, or one operably connected plurality of tool assemblies, to be in an open position at any time.

Abstract: A completion system for a well including an upper production tubing disposed within a wellbore. An upper packer engaging the upper production tubing a top pin connector with seal assembly engaging the upper packer. A first intermediate production tubing disposed between the top pin connector with seal assembly and a top hydraulically operated tool.

Abstract: A system for controlling zones of fluid flow in and out of a wellbore. The wellbore has a top of a well and a bottom of a well. The system has a control line connected to a power source, and a control system; wherein the control line is disposed within the wellbore. The system also has a single fluid line sliding sleeve downhole tool assembly connected to the control line disposed within the wellbore.

Abstract: A single fluid line sliding sleeve downhole tool assembly having a top sub engaging a top connector which connects to a body that engages a middle connector which is secured to a port housing, wherein the port housing engages a lower connector and the lower connector engages a bottom sub.