Method of determining inflow rates from underbalanced wells

• US 5,635,636 A
• Filed: 05/29/1996
• Issued: 06/03/1997
• Est. Priority Date: 05/29/1996
• Status: Expired due to Fees

• Current Assignee: Integrated Production Services Incorporated (SESI Holdings, Inc.)
• Original Assignee: Lloyd G. Alexander
• Inventors: Alexander, Lloyd G.
• Primary Examiner(s): BROCK, MICHAEL J
• Application Number:
  US08/654,964
• Time in Patent Office: 370 Days
• Field of Search: 73/152.18, 73/152.23, 73/152.24, 73/152.27, 73/152.28, 73/152.31, 73/152.29, 73/152.37, 73/152.38, 73/152.55, 73/152.0 5, 166/250.01, 166/250.02, 166/250.07, 175/2
• US Class Current: 73/152.29
• CPC Class Codes: E21B 47/10 Locating fluid leaks, intrusions or movements
• CPC Class Codes: E21B 49/008 by injection test; by analysing pressure variations in an injection or production test, e.g. for estimating the skin factor measuring pressure E21B47/06

Abstract

A method is provided for determining the inflow rates of gas and liquid upon completion of an underbalanced well. The casing is placed, blocking fluid communication between the well and the formation. A tubing string is run in, forming an annular space and a tubing bore. The well is conditioned by removing sufficient liquids to create an underbalanced state and leaving a gas-filled space above any residual liquid. The volume of the gas-filled space in the annular space and the tubing bore is determined. The well is perforated, opening communication between the well and the formation. Pressure within the tubing bore and annulus is measured as a function of time. The rate of change of pressure is dependent upon the nature of the incoming fluid; be it gas or liquid. From the above, the rate of incoming fluid can be established as a function of the volume of the gas-filled space and the rate of change of pressure. The inflow rates of solely gas or solely liquid may be determined whether substantially all the liquid is removed during conditioning or only some of the liquid is removed.

Claims

1. A method of determining the flowrate of fluid into the wellbore of a well, the well having a tubing string extending downwardly from a wellhead into a casing string which penetrates a fluid-bearing formation, said strings forming an annulus between them, said tubing string having a bore and a means for perforating the casing being located at the tubing string'"'"'s lower end, the casing initially acting to block communication of the fluid with the wellbore, comprising:

removing sufficient liquid from the well so that it is in an underbalanced state and has a gas-filled space being formed above any liquid remaining therein;

establishing the volume of the gas-filled space;

blocking all means of fluid egress from the tubing bore and annulus at the wellhead;

perforating the casing at the fluid-bearing formation;

measuring the change in pressure in the tubing bore and annulus at the wellhead over time to determine its rate of change; and

establishing the rate of fluid inflow to the tubing bore and annulus as a function of the volume of the gas-filled space and said pressure change rate.

2. The method as recited in claim 1 wherein the rate of fluid inflow is established using the relationship ##EQU20## where Q is the fluid inflow rate, T_sc and P_sc are the temperature and pressure of the well respectively at standard conditions, V is the volume of the gas-filled space, T and P are the average temperature and the average pressure respectively in the well, dV/dt is the rate of change of the gas-filled volume over time, z is the gas deviation factor and dP/dt is the rate of change of pressure in the well after perforation of the casing.

3. The method as recited in claim 1 wherein sufficient liquid is removed so that prior to perforation of the casing, the resulting liquid level is at or below the fluid-bearing formation, the fluid flowing into the well from the formation is solely gaseous and its rate inflow is established using the relationship ##EQU21## where Q is the gaseous inflow rate, T_sc and P_sc are the temperature and pressure of the well respectively at standard conditions, V is the volume of the gas-filled space, T is the average temperature in the well, z is the gas deviation factor and dP/dt is the rate of change of pressure in the well after perforation of the casing.

4. The method as recited in claim 1 wherein the fluid flowing into the well from the formation is solely liquid and its rate is established using the relationship ##EQU22## where dV/dt is the rate of change of the gas-filled volume over time, V is the volume of the gas-filled space, P is the average pressure in the well and dP/dt is the rate of change of pressure in the well after perforation of the casing.

5. The method as recited in claim 1 wherein only enough liquid is removed so that the well is underbalanced and the resulting liquid level is above the fluid-bearing formation, and that after perforation of the casing the fluid flowing into the well from the formation is solely gaseous and acts to drive the liquid laying above the formation up the well in a contiguous cushion, the gaseous inflow rate being established using the relationship ##EQU23## where Q is the gaseous inflow rate, T_sc and P_sc are the temperature and pressure of the well respectively at standard conditions, T is the average temperature in the well, z is the gas deviation factor, V_o is the volume of the gas-filled space prior to perforation of the casing, P_s is the pressure of the gas-filled space measured at the wellhead, P_o is the hydrostatic pressure exerted by the height of the liquid cushion and the height of gas in the well above the formation plus the P_s, P_o is the original pressure of the gas-filled space measured at the wellhead and dP/dt is the rate of change of pressure in the well after perforation of the casing.