Abstract: A thermal insulating packer fluid contains at least one water superabsorbent polymer and optionally water and/or brine, and a viscosifying polymer. The composition is capable of inhibiting unwanted heat loss from production tubing or uncontrolled heat transfer to outer annuli. The viscosity of the composition is sufficient to reduce the convection flow velocity within the annulus.

Abstract: A flapper for use as a component of a safety valve designed for deployment in a well bore having well bore fluids. The flapper includes a flapper body forming a flapper valve bore therethrough. The flapper body further forms a groove proximate to the flapper bore. The flapper also includes a plunger member sized and configured to be received in the flapper valve bore. The plunger member includes a first end portion and a second end portion. Additionally, the flapper includes a leaf spring including a primary end portion and a secondary end portion, the primary end portion of the leaf spring detachably attached to the second end portion of the plunger member and unattached to the flapper body and the secondary end portion of the leaf spring being sized and configured to be received and retained in the groove and to bias the plunger member into the flapper valve bore.

Abstract: A process for fracturing a subterraneous formation in the production of an oil well is described. The process steps include injecting an initial charge of a mixture, the mixture being formed from at least a water-insoluble adsorbent and at least one well treatment agent, into a well bore formed in the subterraneous formation so as to form a downhole matrix within the formation; injecting a solution comprised of an additional amount of the well treatment agent into the formation after the initial charge of the at least one well treatment agent has been substantially depleted; and then pressurizing the well bore for a time and under conditions sufficient to reactivate the downhole matrix in the formation, so that the treatment agent activity of the matrix is increased relative to the treatment agent activity of the matrix just prior to injecting the solution.

Abstract: Methods for cleaning out horizontal wellbores using coiled tubing are provided for use during downhole operations. A coiled tubing having a bottom hole assembly is deployed into a horizontal wellbore. Fluid is circulated down the annulus of the wellbore and up the bottom hole assembly while the bottom hole assembly is moved upward at a selected rate and distance. This method may be used to remove downhole solids, such as formation sands and proppant.

Abstract: An apparatus that can determine the water wettability of fluid at simulate downhole conditions. For example, a spacer fluid and a drilling mud mixture can be tested under a specified pressure and a specified temperature that simulate downhole conditions. Additionally, a shear rate may be applied to the fluid mixture that is substantially identical to the shear rate that will be exerted on the mixture due to downhole geometries and conditions. The apparatus may also provide the viscosity of the fluid under the designated pressure, at the specific temperature, and under the specified shear rate. The apparatus may also be used to determine the amount of spacer fluid that would need to be added to a drilling mud to improve the rheological properties of the mixture to provide adequate water wettability as well as the displacement of the mixture during the cementing process of a wellbore.

Abstract: A production tubing comprising a liner is placed downhole in a wellbore. A fluid pill containing proppant is squeezed into the annulus between the formation and liner, thereby packing the proppant into the annulus, effectively isolating the annulus. The packed proppant is permeable to liquids but impermeable to fracturing proppants. After isolation of the annulus, the wellbore may be perforated using a resettable perforation assembly. Once perforating is complete, the wellbore is fractured. The presence of the packed proppant in the annulus generates resistance to the flow of fracturing fluid along the annulus, forcing the fracture to propagate down the perforation tunnels, while also allowing subsequent production fluids to be produced along the annulus.

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: Bypass assembly 100 includes stinger 150 received by receptacle bore 172 of tubular receiver 120 attached to tube 106. Bypass pathway 140 connects stinger port(s) (158, 158?) to slip hanger 122 supported hydraulic conduit 108 to bypass the tube 106. Tube 106 can be a subsurface safety valve or hydraulic nipple anchored within production tubing. Bypass assembly 200 includes upper 202 and lower 203 hydraulic nipples in production tubing 210, with respective tubular anchor seal assemblies (220, 230) engaged therein. Bypass pathway 214 connects hydraulic conduit 208 to slip hanger 242 supported hydraulic conduit 216 to bypass tubular anchor seal assemblies (220, 230). Bypass assembly 300 includes upper 302 and lower 303 hydraulic nipples in production tubing 310, with respective tubular anchor seal assemblies (320, 330) engaged therein. Bypass passage 318 connects stinger 350 to slip hanger 342 supported hydraulic conduit 316 to bypass tubular anchor seal assemblies (320, 330).

Abstract: An improved method for building a plug in a horizontal wellbore using a fluid pill pumped into the wellbore at the end of a fracturing treatment. The fluid pill includes a high concentration of an ultra lightweight proppant, such as a neutrally buoyant proppant or an ultra lightweight proppant mixture. The fluid pill is pumped down the wellbore until it almost reaches fractures within a zone of interest. The pumping is then ceased or reduced, allowing the fractures to partially close. The ultra lightweight proppant remains suspended within the fluid pill while stationary. The pumping is then resumed at a very slow rate or as a short pump burst, thus causing the proppant in the fluid pill to bridge off until a bridge plug is formed.

Abstract: A subterranean formation having natural fractures, which is to be subjected to hydraulic fracturing, is first pre-treated with an ultra lightweight (ULW) proppant having an average particle size between from about 12/20 to about 40/70. The small ULW proppant flows into the natural fractures and packs the fractures. The formation is then subjected to hydraulic fracturing. The pre-treatment serves to enhance the effective propped fracture length of the formation during the hydraulic fracturing by reducing the loss of fluid from the subsequently pumped fracturing fluid. The method is applicable to hydrocarbon bearing formations as well as non-hydrocarbon bearing formations and has particular applicability to coal beds.

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. 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: A method for treating a subterranean formation by introducing into a gas or oil well a stable foam well treatment fluid which exhibits high viscosity. The well treatment fluid is prepared by first forming a mixture of crosslinking agent and foaming agent and then introducing the mixture to an aqueous fluid containing a crosslinkable polymer followed by the addition of a gas or gaseous liquid.

Abstract: Prior to a hydraulic fracturing treatment, the requisite injection rate for a desired propped fracture length of a fracture may be estimated with knowledge of certain physical properties of the proppant and transport fluid such as fluid viscosity, proppant size and specific gravity of the transport slurry as well as fracture geometry and the fracture length. The requisite injection rate may be determined for the desired propped fracture length of the fracture, DPST, in accordance with Equation (I): (qi)=[1/(DPST)B]×[(1/A)×CTRANS×(d2prop)×(1/?fluid)×(?SGPS)]??(I) wherein: A is the multiplier and B is the exponent from the Power Law equation of velocity of the transport slurry vs. distance for the fracture geometry; CTRANS is the transport coefficient; dprop is the median proppant diameter, in mm.

Abstract: Methods and compositions useful for subterranean formation treatments, such as hydraulic fracturing treatments and sand control that include porous materials. Such porous materials may be selectively configured porous material particles manufactured and/or treated with selected glazing materials, coating materials and/or penetrating materials to have desired strength and/or apparent density to fit particular downhole conditions for well treating such as hydraulic fracturing treatments and sand control treatments. Porous materials may also be employed in selected combinations to optimize fracture or sand control performance, and/or may be employed as relatively lightweight materials in liquid carbon dioxide-based well treatment systems.

Abstract: The permeability of a subterranean formation is improved by introducing into the formation a water-in-oil emulsion. Unwanted particulates deposited in the formation during the production of oil are dissolved or loosened by the outer phase of the emulsion and dispersed in the aqueous phase.

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).

Abstract: A thermal insulating composition containing an organic solvent of low thermal conductivity and a gelling agent hydratable in the solvent is useful for controlling heat transfer from a production tubing or transfer pipe in a wellbore to a surrounding annuli and/or the environment. Further, the composition is capable of reducing convection flow velocity within the annulus surrounding production tubing or a transfer pipe.

Abstract: This invention provides polymers having side chain groups selected from at least one of the following: a) a group comprising an ester of a polycarboxylic acid or polycarboxylate salt, an aminoalkylphosphate ester, or an ammoniumalkylphosphate ester; b) a group comprising an alkanolamino group, a fatty quaternary ammonium moiety, a heterocyclic ring moiety having at least five members, which ring has at least one nitrogen atom, said ring further comprising either unsaturation or at least one additional heteroatom, or both a fatty quaternary ammonium moiety and a heterocyclic ring moiety having at least five members, which ring has at least one nitrogen atom, said ring further comprising either unsaturation or at least one additional heteroatom; c) a group comprising an alkylamino ethoxylate or an alkylamino propoxylate; d) a group comprising a trialkylhexahydrotriazine moiety; e) a group comprising a fatty alkyl ester; and f) a group comprising (i) an ester of a polycarboxylic acid or polycarboxylate salt, an

Abstract: Methods and compositions useful in acidizing a subterranean formation with an oil-in-water emulsion that includes a sulfonate ester, a fluoride salt, a proppant, and water. The reaction of the ester and fluoride salt is delayed so that hydrofluoric acid is produced in-situ.

Abstract: The present invention provides systems and methods for injecting or retrieving tubewire into or out of coiled tubing. The system comprises an injector, coiled tubing coupled to the injector and a pumping mechanism. The injector is adapted to apply a force to inject or retrieve the tubewire into or out of the coiled tubing while the pump pumps fluid in the direction of the force to provide fluid drag on the tubewire. The tubewire may be bent or straightened, and may include a protuberance on its free end to assist in the injection and retrieval process. During injection, the coiled tubing may remain on a reel or may be stretched out along a surface.