Treating fluid comprising hydrocarbons, water, and polymer

1. A method of treating fluid comprising hydrocarbons, water, and polymer being produced from a hydrocarbon-bearing formation via a production wellbore, the method comprising:

adding a concentration of a viscosity reducer to the fluid to degrade the polymer present in the fluid; and

adding a concentration of a neutralizer to the fluid to neutralize the viscosity reducer in the fluid; wherein:

the addition of the concentration of the viscosity reducer is in a sufficient quantity to allow for complete chemical degradation of the polymer prior to the addition of the concentration of the neutralizer in the fluid such that excess viscosity reducer is present in the fluid; and

the addition of the concentration of the neutralizer is sufficiently upstream of any surface fluid processing equipment to allow for complete neutralization of the excess viscosity reducer such that excess neutralizer is present in the fluid prior to the fluid reaching any of the surface fluid processing equipment.

2. The method of claim 1 , wherein the viscosity reducer is in the fluid for 10 minutes or less to allow for complete chemical degradation of the polymer.

3. The method of claim 1 , wherein the neutralizer is in the fluid for 10 minutes or less to allow for complete neutralization of the excess viscosity reducer.

4. The method of claim 1 , wherein the concentration of the viscosity reducer is 10 ppm to 1,500 ppm.

5. The method of claim 1 , wherein the concentration of the neutralizer is 25 ppm to 7,500 ppm.

6. The method of claim 1 , wherein the viscosity reducer is added in a ratio of the polymer to the viscosity reducer of 1:1 to 5:1 by concentration.

7. The method of claim 1 , wherein the neutralizer is added in a ratio of the excess viscosity reducer to the neutralizer of 1:2.5 to 1:5 by concentration.

8. The method of claim 1 , wherein the viscosity reducer comprises sodium hypochlorite, sodium chlorite, hydrogen peroxide, Fenton's reagent, potassium permanganate, fluorine, hydroxyl radical, atomic oxygen, ozone, perhydroxyl radical, hypobromous acid, chlorine dioxide, hypochlorous acid, hypoiodous acid, chlorine, bromine, iodine, tetrakis(hyroxymethyl)-phosphonium sulfate, sodium persulfate, or any combination thereof.

9. The method of claim 1 , wherein the viscosity reducer is a non-sulfur containing viscosity reducer.

10. The method of claim 1 , wherein the neutralizer comprises ascorbic acid, sodium ascorbate, citric acid, sodium thiosulfate, sodium metabisulfite, or any combination thereof.

11. The method of claim 1 , wherein the neutralizer is a non-sulfur containing neutralizer.

12. The method of claim 1 , further comprising:

passing the fluid through the surface fluid processing equipment to separate the hydrocarbons and the water;

adding a concentration of additional polymer to the separated water to increase the viscosity of the separated water; and

injecting the separated water with the increased viscosity into the hydrocarbon-bearing formation, a different hydrocarbon-bearing formation, or any combination thereof.

13. The method of claim 1 , wherein the surface fluid processing equipment comprises a free water knockout, a heat exchanger, a separator, a flotation cell, an induced gas flotation apparatus, a hydrocyclone, a filter, or any combination thereof.

14. The method of claim 1 , wherein the surface fluid processing equipment comprises a free a heat exchanger, and wherein at least a portion of the heat exchanger is coated with a coating to reduce polymer adherence.

15. The method of claim 14 , wherein the coating comprises an organic-inorganic hybrid coating, a fluoropolymer coating, or any combination thereof.

16. The method of claim 1 , wherein the concentration of the viscosity reducer is added to the fluid prior to any downhole fluid lifting equipment in the production wellbore.

17. The method of claim 16 , wherein the downhole lifting equipment comprises an electrical submersible pump, and wherein at least a portion of the electric submersible pump is coated with a coating to reduce polymer adherence.

18. The method of claim 17 , wherein the coating comprises an organic-inorganic hybrid coating, a fluoropolymer coating, or any combination thereof.

19. The method of claim 1 , wherein the concentration of the viscosity reducer is added to the fluid-downstream of a wellhead of the production wellbore.

20. The method of claim 1 , wherein the concentration of the viscosity reducer and the concentration of the neutralizer are added continuously to the fluid.

21. The method of claim 1 , wherein the fluid has a viscosity of less than 1.4 cp with a minimum viscosity of 0.9 cp after separation of at least some of the hydrocarbons from the fluid by the surface fluid processing equipment.

22. A system of treating fluid, the system comprising:

a production wellbore for producing fluid comprising hydrocarbons, water, and polymer from a hydrocarbon-bearing formation;

a first injection apparatus for adding a concentration of a viscosity reducer to the fluid to degrade the polymer present in the fluid;

a second injection apparatus for adding a concentration of a neutralizer to the fluid to neutralize the viscosity reducer in the fluid; and

surface fluid processing equipment for separating the hydrocarbons from the fluid; wherein:

the addition of the concentration of the viscosity reducer is in a sufficient quantity to allow for complete chemical degradation of the polymer prior to the addition of the concentration of the neutralizer in the fluid such that excess viscosity reducer is present in the fluid; and

the addition of the concentration of the neutralizer is sufficiently upstream of any of the surface fluid processing equipment to allow for complete neutralization of the excess viscosity reducer such that excess neutralizer is present in the fluid prior to the fluid reaching any of the surface fluid processing equipment.