Products and processes that are related to phosphonated polysaccharide compositions, including phosphonated polysaccharide gels, having a substituent degree of substitution with a lower limit of 0.02 and an upper limit of 3, and having a weight average molecular weight with an upper limit of 5,000,000 g/mole, as well as to oil field application or fracturing fluid compositions comprising such phosphonated polysaccharide compositions.

Herein is provided a process which includes hydraulically fracturing a subterranean formation with a fracking fluid that includes a nanobubble solution. Alternatively, herein is provide a process that includes hydraulically fracturing a subterranean formation that includes nanobubbles with a fracking fluid that may or may not include a nanobubbles.

Products and processes that are related to phosphonated polysaccharide compositions, including phosphonated polysaccharide gels, having a substituent degree of substitution with a lower limit of 0.02 and an upper limit of 3, and having a weight average molecular weight with an upper limit of 5,000,000 g/mole, as well as to oil field application or fracturing fluid compositions comprising such phosphonated polysaccharide compositions.

The present disclosure relates to a particularly effective well configuration that can be used for heat based oil recovery methods. Fishbone multilateral wells are combined with inline electric heaters and a thermally conductive proppant. Preferably, an array of overlapping fishbone wells cover the pay, allowing more complete production of the pay, and the use of the proppants prevents the open-hole fishbone laterals from collapsing. These methods can be applied in variety of configurations, including traditional vertically spaced well-pairs, laterally spaced well-pairs, producers only, and combinations thereof.

A method for increasing the retention of a scale inhibitor within a hydrocarbon producing system is provided. The method includes, the steps of: (i) pre-flushing the system with a liquid; (ii) treating the system with a scale inhibitor; and (iii) over-flushing the system with a composition comprising an ionic polymer and a liquid carrier. The concentration of the ionic polymer in the composition is 5 to 50% wt.

A method for increasing the retention of a scale inhibitor within a hydrocarbon producing system by (i) pre-flushing the system with a liquid; (ii) treating the system with a scale inhibitor; and (iii) over-flushing the system with a composition comprising an ionic polymer and a liquid carrier. The concentration of the ionic polymer in the composition is 5 to 50% wt.

In one aspect, embodiments disclosed herein relate to a wellbore strengthening composition including at least one polymer capable of polymerizing through a free radical polymerization reaction from the group of epoxy acrylates, modified epoxy acrylates, epoxy precursors, modified epoxy vinyl esters, unsaturated polyesters, urethane (meth)acrylates, polyester acrylates, epoxy vinyl ester resins having the wherein R and R.sup.1-R.sup.5 may be CH.sub.3 or H and R.sup.6-R.sup.21 may be H or Br, and polymer combinations thereof; and at least one initiator, wherein the resin is present in the amount from about 10 to about 90 weight percent.

In one aspect, embodiments disclosed herein relate to a wellbore strengthening composition including at least one polymer capable of polymerizing through a free radical polymerization reaction from the group of epoxy acrylates, modified epoxy acrylates, epoxy precursors, modified epoxy vinyl esters, unsaturated polyesters, urethane (meth)acrylates, polyester acrylates, epoxy vinyl ester resins having the formula (I), wherein R and R.sup.1-R.sup.5 may be CH.sub.3 or H and R.sup.6-R.sup.21 may be H or Br, and polymer combinations thereof; and at least one initiator, wherein the resin is present in the amount from about 10 to about 90 weight percent. ##STR00001##

Mineral particles may provide for wellbore fluids with tailorable properties and capabilities, and methods relating thereto. Mineral particles may be utilized in methods that include introducing a wellbore fluid having a density of about 7 ppg to about 50 ppg into a wellbore penetrating a subterranean formation, the wellbore fluid comprising a base fluid and a plurality of mineral particles, and the wellbore fluid having a first viscosity; contacting at least some of the mineral particles with a linking agent so as to link the at least some of the mineral particles, thereby increasing the first viscosity to a second viscosity.

A method of servicing a wellbore comprising providing a flowable component comprising syntactic foam, communicating the flowable component into a wellbore, and allowing the flowable component to be removed from the wellbore.