Ph control in fluid treatment
Described herein are methods of treating fluid including hydrocarbons, water, and polymer being produced from a hydrocarbon-bearing formation. The methods include 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. The viscosity reducer is buffered at a pH of 7 or less. 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.
1. 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:
a pH of the viscosity reducer is lowered to a pH of 7 or less;
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,
wherein the concentration of the viscosity reducer is added at a first location, and wherein the concentration of the neutralizer is added at a second location.
2. The system of claim 1 , wherein the fluid is passed through the surface fluid processing equipment to separate the hydrocarbons and the water, and wherein a concentration of additional polymer is added to the separated water to increase the viscosity of the separated water, and
wherein the separated water with the increased viscosity is injected into the hydrocarbon-bearing formation, a different hydrocarbon-bearing formation, or any combination thereof.
3. The system 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.
4. The system of claim 3 , wherein the surface fluid processing equipment comprises the heat exchanger and wherein at least a portion of the heat exchanger is coated with a coating to reduce polymer adherence.
5. The system of claim 4 , wherein the coating has a thickness of from 5 microns to 120 microns.
6. The system of claim 4 , wherein the coating comprises from one to three layers.
7. The system of claim 4 , wherein the coating comprises an organic-inorganic hybrid coating, a fluoropolymer coating, or any combination thereof.
8. The system of claim 1 , wherein the first location is prior to any downhole fluid lifting equipment in the production wellbore.
9. The system of claim 8 , wherein the downhole fluid lifting equipment comprises an electronic submersible pump, a hydraulic submersible pump, gas lift equipment, or any combination thereof.
10. The system of claim 9 , wherein the downhole fluid lifting equipment comprises the electric submersible pump and wherein at least a portion of the electric submersible pump is coated with a coating to reduce polymer adherence.
11. The system of claim 10 , wherein the coating has a thickness of from 5 microns to 120 microns.
12. The system of claim 10 , wherein the coating comprises an organic-inorganic hybrid coating, a fluoropolymer coating, or any combination thereof.
13. The system of claim 1 , wherein the first location is downstream of a wellhead of the production wellbore.
14. The system of claim 1 , wherein the surface fluid processing equipment comprises a free water knockout, and the second location is upstream of the free water knockout.
15. The system of claim 14 , wherein the surface fluid processing equipment comprises a heat exchanger downstream of the free water knockout, and the second location is upstream of the free water knockout.
16. The system of claim 14 , wherein the surface fluid processing equipment comprises a flotation cell, an induced gas flotation apparatus, a hydrocyclone, a filter, or any combination thereof downstream of the free water knockout, and the second location is upstream of the free water knockout.
17. The system of claim 14 , wherein the first location and the second location are upstream of the free water knockout.
18. The system of claim 1 , wherein the first location is sufficiently upstream of the second location to allow for complete chemical degradation of the polymer prior to the fluid reaching the second location, and wherein the second location is sufficiently upstream of any of the surface fluid processing equipment to allow for complete neutralization of the excess viscosity reducer in the fluid prior to the fluid reaching any of the surface fluid processing equipment.
19. The system of claim 1 , wherein the concentration of the viscosity reducer and the concentration of the neutralizer are added continuously to the fluid.
20. The system 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.