Wellbore servicing methods and compositions comprising degradable polymers
Methods and compositions for use in a wellbore penetrating a subterranean formation are provided. In one embodiment, the method of servicing a wellbore may comprise preparing a wellbore servicing fluid comprising a degradation accelerator wherein the degradation accelerator comprises an alkanolamine, an oligomer of aziridine, a polymer of aziridine, a diamine, or combinations thereof; and placing the wellbore servicing fluid comprising a degradation accelerator into the wellbore, the subterranean formation or both wherein the degradation accelerator contacts the degradable polymer.
1. A method of servicing a wellbore wherein a degradable polymer resides within a portion of the wellbore, the method comprising:
preparing a wellbore servicing fluid comprising a degradation accelerator wherein the degradation accelerator comprises an oligomer of aziridine, a polymer of aziridine; and
placing the wellbore servicing fluid into the wellbore, the subterranean formation or both wherein the degradation accelerator contacts the degradable polymer residing within the portion of the wellbore and at least partially accelerates the degradation of the degradable polymer.
2. The method of claim 1 wherein the oligomer of aziridine comprises a linear aziridine oligomer, a branched aziridine oligomer, any derivatives thereof, or any combinations thereof.
3. The method of claim 1 wherein the number of repeating units in the oligomer of aziridine is less than about 100.
4. The method of claim 1 wherein the oligomer of aziridine comprises a compound characterized by Formula II:
where n may range from about 2 to about 100 and R 3 comprises a primary amine.
5. The method of claim 1 wherein the oligomer of aziridine comprises a compound characterized by Formula III:
where m ranges from about 2 to about 100 and R 4 comprises a methyl group.
6. The method of claim 1 wherein the oligomer of aziridine comprises a compound characterized by Formula IV:
where the repeating units occur in a total amount of about (x+y) wherein the total value of (x+y) ranges from about 2 to about 50.
7. The method of claim 1 wherein the oligomer of aziridine comprises diethylene triamine, triethylenetetraamine, and tetraethylenepentamine, or combinations thereof.
8. The method of claim 1 wherein the polymer of aziridine comprises greater than about 100 repeating units.
9. The method of claim 1 wherein the degradation accelerator solution is an aqueous solution with a pH of less than about 11.
10. The method of claim 1 wherein the degradable polymer comprises an aliphatic polyester, a poly(lactide), a poly(glycolide), a poly(ε-caprolactone), a poly(hydroxy ester ether), a poly(hydroxybutyrate), a poly(anhydride), a polycarbonate, a polyether ester, a polyester amide, a copolymer thereof, or any combinations thereof.
11. The method of claim 1 wherein the degradable polymer comprises a copolymer of lactic and glycolic acid.
12. The method of claim 1 wherein the degradable polymer further comprises a plasticizer.
13. The method of claim 12 wherein the plasticizer comprises a compound selected from the group consisting of: a polyethylene glycol (PEG); a polyethylene oxide; an oligomeric lactic acid; a citrate ester; a glucose monoester; a partially hydrolyzed fatty acid ester; a PEG monolaurate; a triacetin; a poly(ε-caprolactone); a poly(hydroxybutyrate); a glycerin-1 -benzoate-2,3 -dilaurate; a glycerin-2 -benzoate-1,3 -dilaurate; a bis(butyl diethylene glycol)adipate; an ethylphthalylethyl glycolate; a glycerin diacetate monocaprylate; a diacetyl monoacyl glycerol; a polypropylene glycol; an epoxy derivative of a polypropylene glycol; a poly(propylene glycol)dibenzoate; a dipropylene glycol dibenzoate; a glycerol; an ethyl phthalyl ethyl glycolate; a poly(ethylene adipate)distearate; a di-iso-butyl adipate, and any combination thereof.
14. The method of claim 1 wherein the wellbore servicing fluid comprises a suspending agent.
15. The method of claim 14 wherein the suspending agent comprises colloidal materials, clays, gel forming polymers, or combinations thereof.
16. The method of claim 1 wherein the degradation accelerator is present in the wellbore servicing fluid in an amount of from about 0.1 wt.% to about 50 wt.% based on the total weight of the wellbore servicing fluid.
17. A method of servicing a wellbore penetrating a subterranean formation comprising:
placing a fracturing fluid comprising a degradable polymer into the subterranean formation via the wellbore wherein the degradable polymer comprises a polymer selected from the group consisting of: an aliphatic polyester, a poly(lactide), a poly(glycolide), a poly(e-caprolactone), a poly(hydroxy ester ether), a poly(hydroxybutyrate), a poly(anhydride), a polycarbonate, a polyether ester, a polyester amide, and any combination thereof;
introducing a wellbore servicing fluid comprising a degradation accelerator into the subterranean formation via the wellbore, wherein the degradation accelerator comprises an oligomer of aziridine, a polymer of aziridine; and
contacting the degradable polymer with the wellbore servicing fluid.
18. The method of claim 17 wherein the degradable polymer is immersed in the degradation accelerator prior to placement in the wellbore.
19. The method of claim 17 wherein the degradable polymer is present in a downhole tool.
20. The method of claim 17 wherein the degradable polymer is present in a fracturing fluid.
21. A method of servicing a wellbore comprising:
providing a degradable polymer within a portion of a wellbore, a subterranean formation or both;
preparing a wellbone servicing fluid comprising a degradation accelerator wherein the degradation accelerator comprises an oligomer of arziridine, a polymer of aziridine,
wherein the wellbore servicing fluid does not comprise a viscoelastic surfactant; and
placing the wellbore servicing fluid into the wellbore, the subterranean formation or both wherein the degradation accelerator contacts the degradation polymer.