A patented coupled reservoir and wellbore surveillance technology that accurately determines well performance in a single zone or commingled production well, using a new approach to multiphase flow modeling in wellbores, has been invented. This technology is called The Production Profile Predictor Method (3PM) and is in the form of a software package. 3PM applies to both conventional and unconventional wells as the mechanics of multiphase wellbore flow is similar for each. Since 3PM applies to a flowing well its results can only be used to determine refracturing candidate stages as opposed to determining fracturing candidate stages before the well begins production. In addition 3PM applies to wells producing gas and at least one liquid phase, from vertical to horizontal, flowing naturally, on continuous flow gas lift, and on Electric Submersible Pump (ESP) under steady state flow. Shale gas wells only producing water from its fracture fluid can also be analyzed by 3PM.
The following well data is needed for The 3PM Analysis Of A Well without the use of wellbore intervention, all well data needed for wellbore flow modeling (no reservoir data):
Two different stabilized measured wellhead pressures (or down hole pressures) from two well tests (Test No. 1 and Test No. 2);
Corresponding different estimates of the total gas, and oil and/or water flow rates at each measured pressure of the two well tests. The single trend of both the change of the estimated total gas, and oil and/or water flow rates of Test No. 1 to the accurate total gas, and oil and/or water flow rates of the measured pressure at Test No. 1 and the change of the estimated total gas, and oil and/or water flow rates of Test No. 2 to the accurate total gas, and oil and/or water flow rates of the measured pressure at Test No. 2 needs to be accurate. This means that the wellhead or downhole pressure and corresponding fluids flow rates at each well test should be taken consistently at the same time;
The following black oil PVT data of the produced fluids (gas, and oil and/or water): Oil gravity, Gas gravity, Water gravity, Average temperature at the depth of pressure measurements, and Average bottom hole temperature;
The measured depth of the depth of pressure measurements, Ft. using the same reference depth as the measurements e) and f) described next;
The following wellbore I.D. profile from the wellhead to the end of the wellbore: The measured depth of the end of each segment of the wellbore of a constant I.D., Ft., and The I.D. of the segment., In.; and
The following wellbore deviation survey from the wellhead to the end of the wellbore: The measured depth (Ft.) vs. true vertical depth (Ft.) of each segment of the wellbore of a constant inclination angle describing the entire trajectory of the wellbore from vertical to horizontal.
