Method for remediation of subterranean-formed metal-polymer complexes using a metal complexing agent
View Patent ↗This disclosure describes formulations and methods for remediating subterranean-formed metal-polymer complexes in wells in subterranean formations. In one embodiment, the method includes injecting a metal-polymer complex remediation mixture containing a metal complexing agent into a subterranean formation adjacent to a well at a pressure below the fracture pressure of the formation. A sufficient contact time is allowed and then the metal-polymer complex remediation mixture is pumped from the subsurface. This has been shown to remediate polymer-containing, subterranean-formed metal-polymer complexes in shale formations. Without being held to a particular theory it appears that the metal complexing agent is forming metal complexes with the metals in the complexes, and particularly divalent metal ions. This removal of naturally occurring metals may be un-crosslinking and causing the metal-polymer complexes to go into solution, thereby removing the blockages caused by the metal-polymer complexes.
1. A method for remediating a subterranean-formed metal-polymer complex in a pre-existing well in a subterranean shale formation, the method comprising:
producing hydrocarbons from the well;
monitoring hydrocarbon production from the well;
observing a well production decrease due, at least in part, to metal naturally present within the subterranean shale formation complexing with polymers in fracturing fluids;
providing a metal-polymer complex remediation mixture containing between 0.1% and 60% by weight metal complexing agent selected from the group consisting of ethylenediaminetetraacetic acid (EDTA), propylenediaminetetraacetic acid (PDTA), nitrilotriacetic acid (NTA), N-(2-hydroxyethyl)ethylenediaminetriacetic acid (HEDTA), diethylenetriaminepentaacetic acid (DTPA), hydroxyethyliminodiacetic acid (HEIDA), cyclohexylenediaminetetraacetic acid (CDTA), diphenylaminesulfonic acid (DPAS), ethylenediaminedi(o-hydroxyphenylacetic) acid (EDDHA), glucoheptonic acid, gluconic acid, oxalic acid, malonic acid, succinic acid, glutaric acid, adipic acid, pimelic acid, suberic acid, azelaic acid, sebacic acid, phthalic acid, terephthalic acid, aconitic acid, carballylic acid, trimesic acid, isocitric acid, citric acid, acetic acid, erythorbic acid, formic acid, nitrilotriacetic acid (NTA), phosphonic acid, salts thereof, and mixtures thereof;
injecting the metal-polymer complex remediation mixture into the well at a pressure less than a fracture pressure of the subterranean shale formation until at least some of the metal-polymer complex remediation mixture contacts the subterranean-formed metal-polymer complex, the metal of the subterranean-formed metal-polymer complex including metal naturally present within the subterranean shale formation;
maintaining the metal-polymer complex remediation mixture in contact with the subterranean-formed metal-polymer complex for a contact time of between about 1 minute and about 100 days, thereby allowing the metal complexing agent to cause the subterranean-formed metal-polymer complex to dissociate and dissolve, thereby creating a low viscosity flow back fluid comprising the spent metal-polymer complex remediation mixture and the metal-polymer complex components; and
removing the low viscosity flow back fluid from the well after the contact time, thereby improving the hydrocarbon production of the well relative to the hydrocarbon production immediately prior to performance of the method.
2. The method of claim 1 wherein the metal complexing agent is citric acid.
3. The method of claim 1 wherein the metal complexing agent is acetic acid.
4. The method of claim 1 wherein the metal complexing agent is ethylenediaminetetraacetic acid (EDTA).
5. The method of claim 1 wherein the metal-polymer complex remediation mixture comprises:
between 1% and 60% by weight metal complexing agent;
between 1 and 10,000 parts per million (ppm) of a corrosion inhibitor;
between 1 and 10,000 ppm of a biocide;
between 1 and 10,000 ppm of-a colloidal silica deposition inhibitor; and
between 1 and 500 gallons mutual solvent per thousand gallons (gpt) of water.
6. The method of claim 1 wherein the metal-polymer complex remediation mixture further comprises a pH modifier.
7. The method of claim 1 wherein the injecting operation further comprises:
alternately injecting a first amount of metal-polymer complex remediation mixture and a second amount of a diverting mixture into the well.
8. The method of claim 1 wherein the injecting operation further comprises:
injecting the metal-polymer complex remediation mixture until pressure within the well reaches a predetermined target that does not cause substantial fracturing of the formation.
9. The method of claim 1 wherein the injecting operation further comprises:
injecting the metal-polymer complex remediation mixture until the pressure within the well reaches a predetermined target pressure calculated based on the fracture pressure of the subterranean formation; and
upon reaching the target pressure, shutting in the well.
10. The method of claim 1 further comprising:
monitoring at least one of pH and well pressure during the maintaining operation; and
initiating the removing operation based on results of the monitoring operation.
11. The method of claim 1 wherein the contact time is between about 4 hours and about 4 days.
12. A method for remediating an existing, low-producing well in a hydrocarbon-bearing subterranean shale formation, comprising:
fracturing the hydrocarbon-bearing subterranean shale formation with fracturing fluids containing polymers;
producing hydrocarbons from the well;
monitoring the production of the well; and
after observing a well production decrease, and before injecting any remediation mixtures into the well, determining that a subterranean-formed metal-polymer complex has formed in the well, the metal of the subterranean-formed metal-polymer complex including metal naturally present within the subterranean shale formation complexed with polymers from the fracturing fluids;
providing a metal-polymer complex remediation mixture containing between 1% and 95% by weight metal complexing agent selected from the group consisting of citric acid, acetic acid, ethylenediaminetetraacetic acid (EDTA), erythorbic acid, formic acid, nitrilotriacetic acid (NTA), phosphonic acid, salts thereof, and mixtures thereof;
injecting the metal-polymer complex remediation mixture into the well at a pressure less than a fracture pressure of the subterranean shale formation until at least some of the metal-polymer complex remediation mixture contacts the subterranean-formed metal-polymer complex;
maintaining the metal-polymer complex remediation mixture in contact with the subterranean-formed metal-polymer complex for a contact time of between about 1 minute and about 100 days, thereby allowing the metal complexing agent to cause the subterranean-formed metal-polymer complex to dissociate and dissolve, thereby creating a low viscosity flow back fluid comprising the spent metal-polymer complex remediation mixture and the metal-polymer complex components; and
removing the low viscosity flow back fluid from the well after the contact time, thereby improving the hydrocarbon production of the well relative to the hydrocarbon production immediately prior to performance of the method.
13. The method of claim 12 , wherein the remediation mixture comprises between 1% and about 60% by weight metal complexing agent;
between 1 and 10,000 parts per million (ppm) of a corrosion inhibitor;
between 1 and 10,000 ppm of a biocide;
between 1 and 10,000 ppm of a colloidal silica deposition inhibitor;
a mutual solvent; and
wherein the contact time is between about 4 hours and about 4 days.
14. The method of claim 12 , wherein the injecting operation further comprises:
injecting the remediation mixture until the pressure within the well reaches a predetermined target pressure calculated based on the fracture pressure of the hydrocarbon-bearing subterranean formation; and
upon reaching the target pressure, shutting in the well.
15. The method of claim 14 , further comprising:
monitoring at least one of pH and well pressure during the maintaining operation; and
initiating the removing operation based on results of the monitoring operation.