Question 1 PET E 366: Petroleum Production Operations, Winter 2023 Assignment 2, Due 4:00 pm Wednesday, Feb 08 A dry gas well with a radius of 0.4 ft produces gas with a specific gravity of 0.65 at a stabilized rate of 50 MMscf/day. The reservoir pressure has been depleting at a rate of 0.5 psia/day since the start of the production resulting in a present average reservoir pressure of 5,000 psia (implying the flow regime is pseudo steady-state). A transient well test indicated the overall effective permeability of the reservoir to gas was 100 md, and the skin effect was +5. The average thickness of the reservoir can be assumed to be 30 ft. The drainage zone of the wellbore could be assumed to be circular and was assessed to be 40 acres. The average compressibility factor and viscosity of the reservoir gas were evaluated to be 0.85 and 0.023 cp, respectively, at the reservoir temperature of 120 F and the average reservoir pressure. a) Calculate the flowing bottomhole pressure neglecting the turbulence effect b) Calculate the gas productivity index for the present reservoir conditions Question 2 Given average reservoir pressure of 3,000 psia and bubble point pressure of 4,000 psia, the well produces oil at a rate of 1,000 STB/day and water at a rate of 2,000 bbl/day at a drawdown pressure of 500 psia. The produced gas-to-oil ratio is 3,000 scf/STB. a) Calculate the liquid productivity index b) Estimate the gas productivity index Question 3 A gas well is produced at a stabilized bottomhole pressure of 3600 psi. The wellbore radius is 0.3 ft. the following additional data are available: Reservoir overall effective permeability to gas= 65 md Net average reservoir height= 15 ft Pressure at drainage radius= 4,400 psi Drainage radius= 1,000 ft Gas viscosity at average pressure= 0.0267 cp Reservoir temperature= 140 F Compressibility factor at average pressure= 0.862 Plot the pressure profile in the reservoir at steady-state condition Question 4 A well productivity test yields the following measurements: qo-350 STB/day Pwf=2,000 psig average reservoir pressure= 2,500 psig The bubble-point pressure is p=2,600 psig. Using Vogel's method, calculate: a) the absolute open-flow potential (AOF) of the well b) oil flow rate at pw=1,850 psig c) Plot the inflow performance curve Use the constant J approach and compare the inflow performance curves from the two method