Well testing and monitoring

Patent metadata

Field	Value
Publication number	US-2016265341-A1
Application number	US-201415035722-A
Country	US
Kind code	A1
Filing date	Nov 13, 2014
Priority date	Nov 13, 2013
Publication date	Sep 15, 2016
Grant date	—

Abstract

A technique facilitates testing and monitoring of a well. An artificial lift system is operated to produce a well fluid, and data is collected as the artificial lift system is operated at different flow rates. The data collected at the different, e.g. varying, flow rates is used in estimating flow performance and to enable continued monitoring of the well. In some applications, the data may be obtained by utilizing a virtual flow metering technique.

First claim

What is claimed is:

1 . A method for monitoring a petroleum well, comprising:
operating an electric submersible pumping system in a wellbore to produce a fluid at a well flow rate; varying the well flow rate; calculating a flow rate of the electric submersible pumping system using a virtual flow metering technique; analyzing the calculated flow rate at different well flow rates to establish a differential in the calculated flow rates; and using the differential in the calculated flow rates to determine a performance parameter of the petroleum well.

2 . The method as recited in claim 1 , wherein operating comprises operating in a production mode.

3 . The method as recited in claim 1 , wherein calculating comprises correcting for depth.

4 . The method as recited in claim 1 , wherein analyzing the calculated flow rate comprises using steady-state analysis.

5 . The method as recited in claim 1 , wherein analyzing the calculated flow rate comprises using transient analysis.

6 . The method as recited in claim 1 , wherein calculating comprises using the virtual flow metering technique by analyzing head or delta pressure.

7 . The method as recited in claim 1 , wherein calculating comprises using the virtual flow metering technique by performing nodal analysis.

8 . The method as recited in claim 1 , wherein calculating comprises using the virtual flow metering technique by employing a neural network analysis.

9 . The method as recited in claim 1 , wherein calculating comprises using the virtual flow metering technique by employing a power equation analysis.

10 . The method as recited in claim 1 , further comprising determining an inflow performance relationship for the well by comparing an intake pressure versus a surface flow rate.

11 . The method as recited in claim 10 , further comprising determining a productivity index and an extrapolated reservoir pressure.

12 . The method as recited in claim 1 , wherein varying the well flow rate comprises varying the well flow rate without stopping the well.

13 . A method, comprising:
calculating a downhole electric submersible pumping system flow rate or pressure; introducing a transient event into the well; calculating a differential in the downhole electric submersible pumping system flow rate or pressure from before and after the transient event using a virtual flow rate technique; and analyzing the differential in calculated flow rate or pressure over time to determine a well or formation parameter.

14 . The method as recited in claim 13 , wherein analyzing comprises measuring a skin effect of a petroleum well.

15 . A system for automatically testing an oil well installation positioned in a reservoir, comprising:
an electric submersible pumping system positioned in a well for pumping a fluid; at least one sensor for sensing an operating parameter related to pumping the fluid; and an automatic testing module receiving data from the at least one sensor, the automatic testing module automatically adjusting operating controls based on the data from the at least one sensor to determine characteristics of the well installation and the reservoir, the automatic testing module providing a closed loop control over the operating controls to make continued adjustment based on the data received from the at least one sensor.

16 . The system as recited in claim 15 , wherein the at least one sensor comprises a pressure gauge which is powered by a secondary power source separate from a primary power source providing power to the electric submersible pumping system.

17 . The system as recited in claim 16 , wherein the pressure gauge measures pressure build.

18 . The system as recited in claim 15 , wherein the automatic testing module incrementally adjusts the operating controls.

19 . The system as recited in claim 15 , further comprising a pressure choke valve, wherein the automatic testing module incrementally adjusts the pressure choke valve during testing.

20 . The system as recited in claim 15 , further comprising a variable speed drive for a pump motor, wherein the automatic testing module incrementally adjusts the drive frequency for the variable speed drive during testing.

Assignees

• Schlumberger Technology Corp

Inventors

• Subervie Yves-Marie Clet Robert
• Rendusara Dudi Abdullah
• Mackay Roderick Ian

Classifications

• E21B47/008 Primary

  Monitoring of down-hole pump systems, e.g. for the detection of "pumped-off" conditions · CPC title

• F04D15/0066

  by changing the speed, e.g. of the driving engine · CPC title

• E21B47/06

  Measuring temperature or pressure · CPC title

• F04D13/10

  adapted for use in mining bore holes · CPC title

• E21B43/12 Primary

  Methods or apparatus for controlling the flow of the obtained fluid to or in wells (E21B43/25 takes precedence; valve arrangements E21B34/00) · CPC title