Methods of treating a subterranean formation are disclosed that include introducing a treatment fluid including thermally shrinkable fibers and a particulate material into a subterranean formation via a wellbore, adjusting at least one parameter of the treatment fluid to trigger the association of the thermally shrinkable fibers, and forming a porous pack including a network of shrunken fibers by applying heat sufficient to raise the temperature of the thermally shrinkable fibers to a temperature at or above a shrinking initiation temperature of the thermally shrinkable fibers.

Weakly consolidated formations, semi consolidated formations, or unconsolidated formations treated with an aggregating, agglomerating or conglomerating composition, which alters an aggregation or zeta potential of formation surfaces and particulate to increase a maximum sand free production rate of producing formations and increases the injection rate of injection formations.

An actuation member for use in fracking operations, which immediately prior to fracking locates a sand screen at a desired location along a tubing liner and eliminates having to trip out the frac string prior to commencing production. The actuation member comprises a cylindrical hollow collet sleeve, with one or more radially-outwardly biased protuberances forming a unique profile which further matingly engages a corresponding mating profile on one of a plurality of sliding sleeve members in the tubular liner. A longitudinally-extending sand screen is provided, longitudinally slidable on the actuation member. A spring member, adapted to be forcibly compressed by the sand screen member when pressurized fluid is applied, and decompressed upon removal of pressurized fluid, is further provided on the actuation member.

A coating reservoir defining a chamber operable retain to a liquid coating. A retractable application assembly includes a nozzle fluidically coupled to the coating reservoir. The nozzle is configured to dispense the liquid coating onto a wall of a wellbore. A spreader is proximal to the nozzle. The spreader is configured to regulate a thickness of the liquid coating dispensed by the nozzle. A flexible coating housing is positioned between the coating reservoir and the nozzle. The coating housing is configured to seal against a wall of the wellbore and seal the nozzle, spreader, and dispensed liquid coating from contamination within the wellbore.

Treatment method for a rock formation against sand infiltration during production of fluid from this rock formation via a well drilled through said rock formation, comprising at least one step of injecting a geopolymer cement grout into said rock formation, in particular around the edges of said well and/or through said well.

Methods may include calculating a formation permeability for a subterranean formation from a combination of dielectric measurements and acoustic measurements, wherein the formation permeability is calculated according to the formula: k.sub.g=a(V.sub.xσ.sub.w/ε.sub.r).sup.b, where V.sub.x is either V.sub.p, V.sub.s, or V.sub.p/V.sub.s, σ is formation conductivity, Ø.sub.w is water-filled porosity, and a and b are constants that are empirically determined for the frequency selected with respect to V.sub.x; and creating a design for a wellbore operation from the calculated formation permeability. Methods may also include obtaining a dielectric measurement from a downhole formation; obtaining an acoustic measurement from a downhole formation; and calculating a formation permeability from a combination of the dielectric measurement and the acoustic measurement.

A method for fracking a hydrocarbon formation. An actuating member, flowable along a production string, is provided. A unique key portion thereon engages a desired sliding sleeve covering an associated port in the production string. Applying uphole fluid pressure causes the sliding sleeve and actuating member to move so as to uncover the associated port. After fracking and cessation of supply of pressurized fracturing fluid, a compressed spring on the actuating member decompresses so as to reposition a sand screen immediately beneath the port so as to prevent sand from flowing into the production string. Flowable insertion of additional “keyed” actuating members allows similar opening of additional successive uphole ports and fracking in the regions of such additional opened ports, with similar location of sand screens at each opened port. Plug members on each actuating member thereafter dissolve or are successively burst to thereby allow production.

Methods for treating a formation may include introducing components of a treatment solution into a wellbore such that the treatment solution contacts the formation to be treated, where the treatment solution may include urea, urease, a calcium ion source, one or more polysaccharides, a casein protein, a protease, an ionic compound, and a sugar, where the formation may have an amount of sand production before treatment and may be in fluid contact with the wellbore, and where an amount of sand production after treatment may be less than the amount of sand production before treatment. Consolidated sand structure compositions may include previously unconsolidated sand interlinked by inter-particle cementitious bonds comprising deposited calcium carbonate crystals, where the consolidated sand has a structural strength and the consolidated sand structure is porous to permit fluid flow through the composition.

A coating reservoir defining a chamber operable retain to a liquid coating. A retractable application assembly includes a nozzle fluidically coupled to the coating reservoir. The nozzle is configured to dispense the liquid coating onto a wall of a wellbore. A spreader is proximal to the nozzle. The spreader is configured to regulate a thickness of the liquid coating dispensed by the nozzle. A flexible coating housing is positioned between the coating reservoir and the nozzle. The coating housing is configured to seal against a wall of the wellbore and seal the nozzle, spreader, and dispensed liquid coating from contamination within the wellbore.

A system and method for fracking a hydrocarbon formation. An actuating member, flowable along a production string, is provided. A unique key portion thereon engages a desired sliding sleeve covering an associated port in the production string. Applying uphole fluid pressure causes the sliding sleeve and actuating member to move so as to uncover the associated port. After fracking and cessation of supply of pressurized fracturing fluid, a compressed spring on the actuating member decompresses so as to reposition a sand screen immediately beneath the port so as to prevent sand from flowing into the production string. Flowable insertion of additional “keyed” actuating members allows similar opening of additional successive uphole ports and fracking in the regions of such additional opened ports, with similar location of sand screens at each opened port. Plug members on each actuating member thereafter dissolve or are successively burst to thereby allow production.