Determination of three-phase fluid saturations from production and pressure measurements from a well
The determination of subsurface three-phase saturation (that is, oil, water, and gas saturation) across perforations and open completions of production wells using production rates and pressure measurements. A process may use the surface production rates of oil, water, and gas and measured pressures to determine well fractional flows. The subsurface three-phase saturation may be determined using the cell fractional flows calculated from the well fractional flows. Computer-readable media and systems for determining subsurface three-phase saturation are also provided.
1. A computer implemented method for determining three-phase saturation of a subsurface reservoir from data measurements of a well in the reservoir during production, the method comprising:
obtaining a surface production rate of oil, a surface production rate of water, and a surface production rate of gas from the well;
obtaining a static bottomhole pressure at a datum depth in the well;
determining a productivity index for each of a plurality of perforated cells associated with the well;
setting an initial well fractional flow, the initial well fractional flow comprising an initial well fractional flow of oil, an initial well fractional flow of gas, and an initial well fractional flow of water;
setting an initial bottomhole pressure for each of the plurality of perforated cells associated with the well;
determining, using the well fractional flow, a cell fractional flow of oil, a cell fractional flow of gas, and a cell fractional flow of water for each of the plurality of perforated cells;
determining, using the static bottomhole pressure, a cell bubble point pressure for each of the plurality of perforated cells;
determining, using the cell bubble point pressure for each of the plurality of perforated cells, a pressure-volume-temperature (PVT) property for each of the plurality of perforated cells;
determining, using the PVT property for each of the plurality of perforated cells, an oil density, a gas density, and a water density for each of the plurality of perforated cells;
determining, using the oil density, the gas density, and the water density for each of the plurality of perforated cells and the cell fractional flow of oil, the cell fractional flow of gas, and the cell fractional flow of water for each of the plurality of perforated cells, an average oil density, an average gas density, and an average water density for each of the plurality of perforated cells;
determining, using the PVT property for each of the plurality of perforated cells and the cell fractional flow of oil, the cell fractional flow of gas, and the cell fractional flow of water for each of the plurality of perforated cells, a PVT property for the well;
determining, using the PVT property for the well, a total production rate for the well at reservoir conditions, the total production rate comprising a total production rate of oil, a total production rate of gas, and a total production rate of water;
determining, using the total production rate for the well and the PVT property for the well, a new well fractional flow of oil, a new well fractional flow of gas, and a new well fractional flow of water;
using the new well fractional flow of oil, the new well fractional flow of gas, and the new well fractional flow of water, to determine the three-phase saturation of the subsurface reservoir, wherein the three-phase saturation comprises an oil saturation, a gas saturation, and a water saturation;
identifying a drilling site using the three-phase saturation; and
drilling a well based on the identification.
2. The method of claim 1 , wherein the PVT property for each of the plurality of perforated cells comprises a cell oil formation volume factor, a cell gas formation volume factor, a cell water formation volume factor, and a cell solution gas-oil ratio.
3. The method of claim 1 , wherein the PVT property for the well comprises a well oil formation volume factor, a well gas formation volume factor, a well water formation volume factor, and a well solution gas-oil ratio.
4. The method of claim 1 , comprising;
comparing the new well fractional flow of oil to the initial well fractional of oil to determine an oil error value;
comparing the oil error value to a first threshold;
comparing the new well fractional flow of gas to the initial well fractional of gas to determine a gas error value;
comparing the gas error value to a second threshold;
comparing the new well fractional flow of water to the initial well fractional of water to determine a water error value; and
comparing the water error value to a third threshold.
5. The method of claim 1 , comprising determining a new static bottomhole pressure for each of the plurality of perforated cells using the average oil density, the average gas density, and the average water density for each of the plurality of perforated cells.
6. The method of claim 5 , comprising:
comparing the new static bottomhole pressure for each of the plurality of perforated cells to the initial bottomhole pressure for each of the plurality of perforated cells to determine a pressure value; and
comparing the pressure value to a third threshold.
7. A non-transitory computer-readable storage medium having executable code stored thereon for determining three-phase saturation of a subsurface reservoir from data measurements of a well in the reservoir during production, the executable code comprising a set of instructions that causes a processor to perform operations comprising:
obtaining a surface production rate of oil, a surface production rate of water, and a surface production rate of gas from the well;
obtaining a static bottomhole pressure at a datum depth in the well;
determining a productivity index for each of a plurality of perforated cells associated with the well;
setting an initial well fractional flow, the initial well fractional flow comprising an initial well fractional flow of oil, an initial well fractional flow of gas, and an initial well fractional flow of water;
setting an initial bottomhole pressure for each of the plurality of perforated cells associated with the well;
determining, using the well fractional flow, a cell fractional flow of oil, a cell fractional flow of gas, and a cell fractional flow of water for each of the plurality of perforated cells;
determining, using the static bottomhole pressure, a cell bubble point pressure for each of the plurality of perforated cells;
determining, using the cell bubble point pressure for each of the plurality of perforated cells, a pressure-volume-temperature (PVT) property for each of the plurality of perforated cells;
determining, using the PVT property for each of the plurality of perforated cells, an oil density, a gas density, and a water density for each of the plurality of perforated cells;
determining, using the oil density, the gas density, and the water density for each of the plurality of perforated cells and the cell fractional flow of oil, the cell fractional flow of gas, and the cell fractional flow of water for each of the plurality of perforated cells, an average oil density, an average gas density, and an average water density for each of the plurality of perforated cells;
determining, using the PVT property for each of the plurality of perforated cells and the cell fractional flow of oil, the cell fractional flow of gas, and the cell fractional flow of water for each of the plurality of perforated cells, a PVT property for the well;
determining, using the PVT property for the well, a total production rate for the well at reservoir conditions, the total production rate comprising a total production rate of oil, a total production rate of gas, and a total production rate of water;
determining, using the total production rate for the well and the PVT property for the well, a new well fractional flow of oil, a new well fractional flow of gas, and a new well fractional flow of water;
using the new well fractional flow of oil, the new well fractional flow of gas, and the new well fractional flow of water, to determine the three-phase saturation of the subsurface reservoir, wherein the three-phase saturation comprises an oil saturation, a gas saturation, and a water saturation;
identifying a drilling site using the three-phase saturation; and
drilling a well based on the identification.
8. The non-transitory computer-readable storage medium of claim 7 , wherein the PVT property for each of the plurality of perforated cells comprises a cell oil formation volume factor, a cell gas formation volume factor, a cell water formation volume factor, and a cell solution gas-oil ratio.
9. The non-transitory computer-readable storage medium of claim 7 , wherein the PVT property for the well comprises a well oil formation volume factor, a well gas formation volume factor, a well water formation volume factor, and a well solution gas-oil ratio.
10. The non-transitory computer-readable storage medium of claim 7 , the operations comprising;
comparing the new well fractional flow of oil to the initial well fractional of oil to determine an oil error value;
comparing the oil error value to a first threshold;
comparing the new well fractional flow of gas to the initial well fractional of gas to determine a gas error value;
comparing the gas error value to a second threshold;
comparing the new well fractional flow of water to the initial well fractional of water to determine a water error value; and
comparing the water error value to a third threshold.
11. The non-transitory computer-readable storage medium of claim 7 , the operations comprising determining a new static bottomhole pressure for each of the plurality of perforated cells using the average oil density, the average gas density, and the average water density for each of the plurality of perforated cells.
12. The non-transitory computer-readable storage medium of claim 11 , the operations comprising:
comparing the new static bottomhole pressure for each of the plurality of perforated cells to the initial bottomhole pressure for each of the plurality of perforated cells to determine a pressure value; and
comparing the pressure error value to a third threshold.
13. A system for determining three-phase saturation of a subsurface reservoir from data measurements of a well in the reservoir during production, comprising:
a processor;
a non-transitory computer-readable memory accessible by the processor and having executable code stored thereon, the executable code comprising a set of instructions that causes the processor to perform operations comprising:
obtaining a surface production rate of oil, a surface production rate of water, and a surface production rate of gas from the well;
obtaining a static bottomhole pressure at a datum depth in the well;
determining a productivity index for each of a plurality of perforated cells associated with the well;
setting an initial well fractional flow, the initial well fractional flow comprising an initial well fractional flow of oil, an initial well fractional flow of gas, and an initial well fractional flow of water;
setting an initial bottomhole pressure for each of the plurality of perforated cells associated with the well;
determining, using the well fractional flow, a cell fractional flow of oil, a cell fractional flow of gas, and a cell fractional flow of water for each of the plurality of perforated cells;
determining, using the static bottomhole pressure, a cell bubble point pressure for each of the plurality of perforated cells;
determining, using the cell bubble point pressure for each of the plurality of perforated cells, a pressure-volume-temperature (PVT) property for each of the plurality of perforated cells;
determining, using the PVT property for each of the plurality of perforated cells, an oil density, a gas density, and a water density for each of the plurality of perforated cells;
determining, using the oil density, the gas density, and the water density for each of the plurality of perforated cells and the cell fractional flow of oil, the cell fractional flow of gas, and the cell fractional flow of water for each of the plurality of perforated cells, an average oil density, an average gas density, and an average water density for each of the plurality of perforated cells;
determining, using the PVT property for each of the plurality of perforated cells and the cell fractional flow of oil, the cell fractional flow of gas, and the cell fractional flow of water for each of the plurality of perforated cells, a PVT property for the well;
determining, using the PVT property for the well, a total production rate for the well at reservoir conditions, the total production rate comprising a total production rate of oil, a total production rate of gas, and a total production rate of water;
determining, using the total production rate for the well and the PVT property for the well, a new well fractional flow of oil, a new well fractional flow of gas, and a new well fractional flow of water; and
using the new well fractional flow of oil, the new well fractional flow of gas, and the new well fractional flow of water, to determine the three-phase saturation of the subsurface reservoir, wherein the three-phase saturation comprises an oil saturation, a gas saturation, and a water saturation;
identifying a drilling site using the three-phase saturation; and
drilling a well based on the identification.
14. The system of claim 13 , wherein the PVT property for each of the plurality of perforated cells comprises a cell oil formation volume factor, a cell gas formation volume factor, a cell water formation volume factor, and a cell solution gas-oil ratio.
15. The system of claim 13 , wherein the PVT property for the well comprises a well oil formation volume factor, a well gas formation volume factor, a well water formation volume factor, and a well solution gas-oil ratio.
16. The system of claim 13 , the operations comprising;
comparing the new well fractional flow of oil to the initial well fractional of oil to determine an oil error value;
comparing the oil error value to a first threshold;
comparing the new well fractional flow of gas to the initial well fractional of gas to determine a gas error value;
comparing the gas error value to a second threshold;
comparing the new well fractional flow of water to the initial well fractional of water to determine a water error value; and
comparing the water error value to a third threshold.
17. The system of claim 13 , the operations comprising determining a new static bottomhole pressure for each of the plurality of perforated cells using the average oil density, the average gas density, and the average water density for each of the plurality of perforated cells.
18. The system of claim 17 , the operations comprising:
comparing the new static bottomhole pressure for each of the plurality of perforated cells to the initial bottomhole pressure for each of the plurality of perforated cells to determine a pressure value; and
comparing the pressure value to a third threshold.