Abstract: The present invention provides resilient cement compositions and methods which are particularly useful in the construction and repair of oil and gas wells. The cement compositions have improved mechanical properties including elasticity and ductility and are basically comprised of cementitious material, an aqueous rubber latex and a latex stabilizer.

Abstract: Methods of forming highly insulated pipeline bundles made up of one or more flow lines positioned within a continuous larger diameter outer sleeve are provided. The methods basically comprise the steps of filling the space between the outside of the flow lines and the inside of the outer sleeve with a foamed cement composition comprised of hydraulic cement, water, a gas and a foaming agent, allowing the hydration reaction between the hydraulic cement and the water in the cement composition to take place, and then heating the hydrated cement composition to evaporate and remove excess water in the cement composition and thereby increase the insulating properties of the cement composition.

Abstract: A well completion spacer fluid is provided which is particularly suitable for separating a cement slurry from drilling fluid in primary cementing operations. The well completion spacer fluid is also useful for separating other potentially incompatible fluids in the wellbore, such as, separating drilling fluid from a completion brine. The spacer fluid basically comprises water, a hydrous magnesium silicate clay, silica and organic polymer(s).

Abstract: An improved coiled tubing pulling tool and methods of using the pulling tool for pulling a well tool from a well bore, relocating a well tool in the well bore and performing other similar operations.

Abstract: A fluid loss device has a housing, a seal assembly, a running tool, and a plug. The housing of the fluid loss device is placed in a production string before a well bore is completed. The plug is attached to the running tool, and the running tool is attached to a wash pipe.The fluid loss device is activated by lifting the wash pipe and the running tool, thereby engaging the plug with the seal assembly, engaging the seal assembly with the housing, and severing the plug from the running tool. Activation of the fluid loss device inhibits fluid communication through the fluid loss device and reduces damage to the well structure behind the fluid loss device while completion operations are performed in other areas of the well bore.The fluid loss device is deactivated by forcing the plug through the fluid loss device with mechanical force or pressure, or by chemically eroding the diameter of the plug until the plug passes through the fluid loss device.

Abstract: To test coiled tubing, at least one test is performed on a coiled tubing that has been used, such as in an oil or gas well. Performing such test includes obtaining a specific output data event (e.g., a nondestructive evaluation test readout) for the used coiled tubing. The specific output data event is compared with a predetermined sequence of output data events (e.g., a collection of data defining a "lifeline" for the coiled tubing) for determining where the sequence and the specific output data event correspond. A coiled tubing status indication is generated in response to where the specific output data event corresponds with the sequence as a measure of a point in the useful life of the used coiled tubing.

Abstract: The apparatus and method for injecting coiled tubing downhole includes a connector member disposed on the end of the coiled tubing and supporting a downhole tool. A packer member is releasably connected to the connector member. The packer member includes a pack-off element and slips for releasably engaging the outer pipe string through which the coiled tubing is being injected. Seals are provided on the packer member for engaging the outer circumferential surface of the coiled tubing. A fluid passageway extends through the connector member for communicating the packer member with the coiled tubing. Fluid pressure is applied through the flow bore of the coiled tubing. The fluid pressure is applied through the fluid passageway to actuate an actuator member in the packer member to set the pack-off element and slips. Thus, upon actuating the packer member, the annulus formed by the coiled tubing and outer pipe string is closed.

Abstract: The present invention provides an improved subsurface release cementing plug apparatus for use in a string of pipe during the cementing of the pipe in a well bore. The apparatus includes a hollow cementing plug seat member adapted to be connected in the string of pipe near the bottom thereof and a cementing plug assembly releasably connectable to a circulation tool or casing running tool in the top of the string of pipe. The cementing plug assembly includes a top cementing plug having an external annular seating surface formed thereon for sealingly engaging a top internal annular seating surface of the cementing plug seat member, and a bottom cementing plug releasably connected to the top cementing plug having an external annular seating surface formed thereon for engaging a bottom internal annular seating surface of the cementing plug seat member.

Abstract: The present invention provides an improved cementing inflation packer tool and methods of using the tool. The tool includes of a tubular housing having a packer inflating port disposed therein and a packer inflating port opening sleeve slidably disposed within the housing. The opening sleeve is movable between a closed position and an open position by a first cementing plug. An external packer sleeve having a pressurized fluid inflatable packer element attached thereto and a cementing port therein is sealingly disposed over the outer surface of the housing and the packer inflating port. The external packer sleeve provides a passageway from the packer inflating port to the inflatable packer element and check valve means are disposed in the passageway. A fluid rupturable member having a predetermined rupture pressure is sealingly attached over the cementing port.

Abstract: The present invention provides methods of grouting a subsurface conduit whereby the hardened grout resists stress failures. The methods basically comprise the steps of forming a hardenable grout composition having elastomeric properties upon hardening, placing the hardenable grout composition adjacent to the outside of a subsurface conduit whereby upon hardening the grout composition forms an elastomeric solid support for the conduit and allowing the hardenable grout composition to harden into an elastomeric solid mass.

Abstract: An improved well cementing plug assembly adapted to be connected to a string of drill pipe or a circulation tool for use in a pipe during the cementing of the pipe in a well bore is provided. The top and bottom plugs are selectively releasable by activating balls dropped into the plug assembly. Different sizes of plugs can be used utilizing the same inner tubes and other assembly parts, and the top plug slides on its inner tube when a pressure differential is exerted on it thereby insuring a seal between the top and bottom plugs when the plugs are landed on a float shoe or the like.

Abstract: In a retrievable packer adapted for service under high temperature and high pressure operating conditions, the packer is purpose-designed as a cut-to-release packer. That is, this retrievable packer has no built-in release mechanism. An internal cinch slip is used to retain the packer in its set position and thereby prevent the accidental release of the packer. The only way it can be released is by severing the mandrel. The cut point is opportunely designed so that the mandrel is severed in a precise location such that not only is the packer released, but all the packer and tail pipe are then retrievable as a unit. The primary advantage of a cut-to-release packer is that it can withstand extreme tubing loads occurring during production and stimulation.

Abstract: An apparatus for downhole injection and mixing of fluids into a cement slurry. The apparatus includes embodiments which either carry a fluid to the proper injection point in a wellbore or maintain it at the proper injection point until activated. In a first embodiment, the apparatus is characterized as a cementing plug having a fluid holding chamber therein. When the plug is pumped downwardly in the wellbore, the fluid in the chamber is flowed out of the chamber and mixed with the cement slurry by a venturi effect. In a second embodiment, the apparatus is characterized by a casing portion having a fluid holding chamber therein. A solenoid valve controls communication of the chamber with the well annulus, and fluid flow through the well annulus causes the fluid in the chamber to be flowed outwardly by a venturi effect. The second embodiment includes a casing shoe disposed below the fluid holding chamber.

Abstract: An inflation packer method and apparatus comprising at inflatable packer bladder and an inflation fluid. The packer apparatus further comprises a packer mandrel having a central flow passage therethrough and an outer packer body which includes the inflatable packer bladder. A chemical expanding additive is employed to expand the inflation fluid used to inflate the packer bladder. An annular inflation fluid passageway is defined between the mandrel and the body. Inflation fluid passes from the central flow passage into the annular inflation fluid passageway to inflate the inflatable packer bladder. The mandrel has grooves defined on an outer surface thereof. The chemical expanding additive is placed in grooves defined on the outer surface of the mandrel so that the expanding additive is dispersed into the fluid passing into the annular passageway.

Abstract: A foamable drilling fluid for use in well operations such as deep water offshore drilling where risers are not employed in returning the fluid to the surface mud pit. A preferred foamable drilling fluid comprises a prehydrated clay such as bentonite, sea water, a surfactant selected from the group consisting of .alpha.-olefinsulfonates, alkylpolyglycosides, alcohol sulfates, salts of ethoxylated alcohol sulfates, and a stabilizing surfactant consisting of cocoamine betaine. The stabilized foam drilling fluid resists foam breakdown upon drilling cessation, prevents fluid loss to reduce filter cake buildup and increases the carrying capacity of cuttings and other solids. In addition, a foamable drilling fluid is provided including an hydraulic material selected from the group consisting of Portland cement, siliceous material like fumed silica, blast furnace slag and pozzolans such as fly ash.

Abstract: The present invention relates to tools and methods for stabilizing incompetent or otherwise unstable subterranean zones or formations penetrated by a well bore during drilling. The methods basically comprise drilling the well bore through an unstable subterranean zone or formation when it is encountered, pumping a fluid through a well stabilization tool while moving the tool through the portion of the well bore in the unstable zone or formation whereby fluid jets formed by the well stabilization tool enlarge the diameter of the well bore by fluid jet erosion, pumping a hardenable cementitious material through the well stabilization tool while moving the tool through the enlarged portion of the well bore whereby the enlarged portion is filled with the hardenable cementitious material, allowing the cementitious material to harden and then drilling the well bore through the hardened cementitious material.

Abstract: The present invention provides cementitious well drilling fluids and methods of drilling subterranean well bores. The drilling fluids are basically comprised of water, a water viscosity increasing material and a cementitious material which when deposited on the walls of the well bore as a part of the filter cake thereon consolidates the filter cake into a stable mass that readily bonds to a cementitious material slurry subsequently placed in the well bore. The methods of drilling a subterranean well bore are basically comprised of the steps of preparing a drilling fluid of the invention and drilling a subterranean well bore using the drilling fluid.

Abstract: An intrinsically safe data network, such as one defining a system for acquiring and transferring data from inside a hazardous zone at an oil or gas well to outside the hazardous zone, includes a fixed number of at least one data signal conductor and a fixed number of at least one intrinsic safety barrier forming part of the overall network that allows for the use of more transducers than there are intrinsic safety barrier(s).

Abstract: The apparatus and method for injecting coiled tubing downhole includes a connector member disposed on the end of the coiled tubing and supporting a downhole tool. The connector member includes a dual check valve in the fluid passageway which allows fluid passage to actuate the packer member and closes the fluid passage after the connector member is disconnected from the packer member. The connector member may also include a valve member which allows circulation down the flow bore of the coiled tubing. The packer member includes a valve for the passage of well fluids between the packer member and coiled tubing.

Abstract: An improved downhole tool apparatus and method for limiting the extrusion of packer element seals of packers and bridge plugs which utilize segmented packer retaining shoes when such tools are of larger diameters, or when used at elevated differential pressures or elevated temperatures. Preferably the segmented packer shoes incorporate a plurality of gap-bridging disks to limit if not eliminate unwanted extrusion of the packer elements upon setting of the tool. By making the packer element shoes and disks of non-metallic material, the subject invention increases the ability to drill or mill downhole tools out of a well bore in less time than it would take with using conventional or non-conventional drilling or milling techniques or equipment while providing enhanced high temperature and high pressure performance, especially in larger nominal outside diameter downhole tools.