Abstract: A well treating composition of a composite containing a scale inhibitor adsorbed onto a water-insoluble adsorbent is useful in the control, formation and treatment of inorganic scales in a subterranean formation or wellbore. In addition, the well treating composition is useful in controlling the rate of release of scale inhibitor in the wellbore. The water-insoluble adsorbent may be activated carbon, silica particulate, precipitated silica, zeolite, diatomaceous earth, ground walnut shells, fuller's earth and organic synthetic high molecular weight water-insoluble adsorbents. The composite may be introduced into an oil or gas well with a carrier fluid.

Abstract: An improved well completion system for completing two or more separate production zones in a well bore during a single downhole trip is disclosed. The improved completion system comprises a completion assembly comprising two or more production zone assemblies and a completion tool assembly. Each production zone assembly may comprise an automatic system locating assembly and at least two inverted seal systems for sealing against the tool assembly.

Abstract: A cementitious composition for cementing an oil or gas well and which exhibits when cured, increased flexural strength and a flexural strength to compressive strength ratio between from about 0.29 to about 0.80, contains a hydraulically-active cementitious material, such as Portland cement, and substantially spherical zeolite. Representative zeolites include natrolite, heulandite, analcime, chabazite, stilbite, and clinoptilolite. The weight percent of zeolite in the cement composition is generally less than or equal to 15 percent. In practice, a well bore may be cemented by pumping the activated slurry and pumping it within the well bore to a pre-selected location and allowing it to solidify.

Abstract: Corrosive effects arising during oilfield treatment applications are inhibited and/or prevented by introducing into an oil or gas well at least one compound of formula I: wherein: R1 is independently H, —[—CnH2nO—]a—H, or an alkyl group having from 1 to about 24 carbon atoms; R2 is independently H or —[—CnH2nO—]b—H, R3 is independently —[—CH2]c—, or —Cd2d—[—OCnH2n—]e—, R4 is independently H or —[—CnH2nO—]f—H, R5 is independently H or —[—CnH2nO—]g—H, a is from about 1 to about 8; b+f+g is between 0 to about 30; c is from about 1 to 6; d is from about 1 to 6; e is from about 1 to about 8; and n is 2 or 3. Such corrosive effects are especially inhibited in the treatment of sour wells where H2S corrosion is a potential problem as well as conduits used during the treatment of subterranean formations.

Abstract: Fluid producing or injecting wells may be treated with a water-in-oil emulsion for the removal or inhibition of unwanted particulates, including pipe dope, asphaltenes and paraffins. In addition, such emulsions are effective in the displacement of oil base drilling muds and/or residues from such muds from wells. The emulsion may also be used to break the interfacial and/or rheological properties of oil base mud and synthetic oil base mud filter cakes, and act as a demulsifier to break the water-in-oil emulsion present in such oil base and synthetic oil base muds. The water-in-oil emulsions may optionally contain a dispersing agent as well as a surfactant.

Abstract: A frangible flapper valve that may be closed to hydraulically isolate a portion of a wellbore tubular. The flapper valve is made of a frangible material adapted to shatter upon impact from an impact sleeve. The sleeve may be used to initially hold open the flapper valve. A latching mechanism may be used to retain the sleeve above its initial position allowing the flapper to close isolating a portion of the tubular. The latching mechanism may engage a piston to retain the sleeve at the second position. A shearable device adapted to shear under a predetermined pressure selectively connects the piston to the tubular. When the pressure within the tubular increases above the predetermined amount the shearable device releases the piston and pushes the sleeve into the closed flapper valve causing the flapper valve to shatter. A second latching mechanism may prevent further movement of the sleeve.

Abstract: An improved cone and integral slip assembly is described for use in the anchoring assembly of a downhole tool, such as a bridge plug, frac plug, or cement retainer. The cone may include external fins that are integral to and run axially along the cone. The integral slip assembly includes at least one axial slot, which facilitates subsequent breaking up of the integral slip assembly into individual slip segments. Each slip segment may include a channel that is adapted to mate with an external fin of the cone. As the integral slip assembly traverses the cone, the channels of the slip segments ride on the fins encouraging the integral slip assembly to break apart along the slots into the slip segments. The spacing of the fins and corresponding channels in the slip segments are positioned such to ensure that the slip segments are advantageously positioned around the cone thus, locating the packing element of the plug in the center of the wellbore.

Abstract: The annular surface between the tubing and casing of an oil or gas well may be contacted with a foamed well treatment composition containing a gas, a foaming agent and a liquid well treatment agent, such as a scale inhibitor, corrosion inhibitor, salt inhibitor, scale remover or biocide. The foam, upon destabilization, renders a thin film of concentrated well treatment agent on the external surfaces of the tubing, inside the casing and in the perforations.

Abstract: The present invention provides a cementing system and method for wellbores by cementing an annulus between a wellbore casing and a wellbore. In at least one embodiment, the invention includes a landing collar defining a restricted passage, a wellbore casing defining a passage coupled to the landing collar, a top cementing plug for sealingly engaging the wellbore casing, a bottom cementing plug for sealingly engaging the wellbore casing, and a fluid injection assembly coupled to the wellbore casing for injecting fluidic materials into the wellbore casing and controllably releasing the top cementing plug and the bottom cementing plug into the wellbore casing. The bottom cementing plug includes a plug body defining a plug passage, a frangible membrane for sealing the plug passage, and a one-way valve for controlling the flow of fluidic materials through the plug passage. The invention also includes the bottom cementing plug and methods for operation.

Abstract: A method for completing a well in a single trip, including: inserting a completion tool assembly into the well, the completion tool assembly having a gravel packing assembly and a service tool assembly slidably positioned substantially within an interior cavity in the gravel packing assembly; removably coupling the service tool assembly and the gravel packing assembly; plugging at a first location, whereby fluid is blocked from flowing through the interior channel; diverting fluid blocked by the plugging at the first location through a first fluid flow path to an exterior of the completion tool assembly; circulating a gravel pack slurry through the completion tool assembly; plugging at a second location, whereby fluid is blocked from flowing through the interior channel; diverting fluid blocked by the plugging at the second location through a second flow path that reenters the interior channel at a location distal of the first and second plugging locations; and circulating a filter cake stimulating fluid thro

Abstract: An increase in effective propped lengths is evidenced in hydraulic fracturing treatments by the use of ultra lightweight (ULW) proppants. The ULW proppants have a density less than or equal to 2.45 g/cc and may be used as a mixture in a first proppant stage wherein at least one of the proppants is a ULW proppant. Alternatively, sequential proppant stages may be introduced into the formation wherein at least one of the proppant stages contain a ULW proppant and where at least one of the following conditions prevails: (i.) the density differential between the first proppant stage and the second proppant stage is greater than or equal to 0.2 g/cc; (ii.) both the first proppant stage and the second proppant stage contain a ULW proppant; (iii.) the rate of injection of the second proppant stage into the fracture is different from the rate of injection of the first proppant stage; or (iv.) the particle size of the second proppant stage is different from the particle size of the first proppant stage.

Abstract: A wellhead assembly for an injection tubing string is provided which allows a master valve to be closed without damaging the injection tubing string while still allowing for the use of a back pressure valve to isolate the tree. Wellhead assemblies and related methods of the present invention include a wellhead apparatus adapted to be connected to a wellhead. The assembly also includes a mandrel adapted to being inserted into the longitudinal bore of the wellhead apparatus, the mandrel having a port for communicating with an injection port which extends radially through the wellhead apparatus. The assembly further includes a hanger adapted to connect to the upper end of the injection string, wherein the hanger is further adapted to land in the longitudinal bore of the mandrel. The hanger includes a communication passageway for facilitating fluid communication between the port of the mandrel and the injection tubing string.

Abstract: Apparatuses and methods to communicate with a zone below a subsurface safety valve (104, 204) independent of the position of a closure member (106) of the safety valve are disclosed. The apparatuses and methods include deploying a subsurface safety valve (104, 204) to a profile located within a string of production tubing. The subsurface safety valve (104, 204) is in communication with a surface station through an injection conduit (150,152; 250,252) and includes a bypass pathway (144, 244) to inject various fluids to a zone below.

Abstract: A downhole device used to divert fluid flow out of a work string into an annulus. The downhole device is activated by the movement of a plurality of pistons within the downhole device. Fluid flow through a restriction of the downhole device creates an increase in fluid pressure causing the movement of the pistons. The pistons move a flow tube between various locations within the device. In one location, the flow tube prevents fluid flow to the annulus while in another location the flow tube allows fluid flow to be diverted into the annulus. The downhole device may include a locating sleeve having a continuous j-track allowing the flow tube to be selectively retained at the various locations within the downhole device. Fluid flow through the downhole is used to cycle the device between diverting fluid flow to the annulus and forcing fluid flow down the work string.

Abstract: Fluid producing wells may be treated with a water-in-oil emulsion for the removal or inhibition of unwanted solid particulates, including pipe dope, asphaltenes and paraffins. Such emulsions are of particular applicability in the displacement of oil base drilling muds and/or residues from such muds from producing wells. The water-in-oil emulsions may optionally contain a dispersing agent as well as a surfactant.

Abstract: Disclosed is a method for fracture stimulating well bores using gaseous nitrogen and/or liquid carbon dioxide combined with a partially dehydrated proppant. The method includes mixing proppant with a fracturing fluid to create a proppant-laden slurry, removing the majority of the fluid from the proppant using centrifugal forces, blending the proppant with gaseous nitrogen and/or liquid carbon dioxide, and thereafter utilizing that combination to fracture-stimulate well bores. The method also includes the use of monitoring and flow control equipment to regulate and/or automate the method.

Abstract: Apparatuses and methods to communicate with a zone below a subsurface safety valve (104, 204, 404) independent of the position of a closure member (106) of the safety valve are disclosed. The apparatuses and methods include deploying a subsurface safety valve (104, 204, 404) to a profile located within a string of production tubing. The subsurface safety valve (104, 204, 404) is in communication with a surface station through an injection conduit (150,152; 250,252; 450;452) and includes a bypass pathway (144, 244, 444) to inject various fluids to a zone below. A redundant control to actuate subsurface safety valve (104, 204, 404) can include a three-way valve (180, 280) or three-way manifold 480 connecting the injection conduit (150,152; 250,252; 452) or the hydraulic ports (140,142; 240,242; 442?) to the subsurface safety valve (104, 204, 404).

Abstract: Cementitious slurries capable of controlling and/or preventing strength retrogression during the cementing of a formation contain a bismuth salt or derivative thereof. Bismuth trioxide is preferred. The cementitious slurry may further contain a density modifying agent and/or strength enhancer. The cementitious slurries of the invention are suitable for use over a broad temperature range of from about 45° F. to about 500° F.

Abstract: A step ratchet mechanism that allows for the incremental movement of an assembly that may be adapted to incrementally open or close an adjustable orifice. The step ratchet mechanism may be comprised of a modified body lock ring that permits incremental movement along a mandrel in either direction along the mandrel. The step ratchet mechanism may be actuated a designated distance by the application of pressure to the mechanism. The step ratchet mechanism may be ideal for using pressure to drive a downhole multi-position device. The modified body lock ring is adapted to both secure the mechanism at each set position as the mandrel is pumped down as well as allowing the mechanism to ratchet when the mandrel is pumped back.

Abstract: A kit for converting an existing wireline retrievable surface controlled subsurface safety valve (170, 270, 370) into a bypass passageway apparatus (100) allowing the injection of production-enhancing fluid into a wellbore while maintaining the operation of the closure member (374). Bypass passageway (280) can extend between upper (260) and lower (275) adapters external to the existing wireline retrievable surface controlled subsurface safety valve (270) to allow fluid injection bypass thereof. Conversion kit can include a tubing string hanger to suspend a velocity tubing string (407, 507), a gas lift valve (475) for gas lift operations, a locking mandrel (220), and/or a spacer tube (240).