METHODS AND SYSTEMS FOR MONITORING NEAR-WELLBORE AND FAR-FIELD RESERVOIR PROPERTIES USING FORMATION-EMBEDDED PRESSURE SENSORS

• US 20080230221A1
• Filed: 03/21/2007
• Published: 09/25/2008
• Est. Priority Date: 03/21/2007
• Status: Abandoned Application

• Current Assignee: Schlumberger Technology Corporation (SLB)
• Original Assignee: Schlumberger Technology Corporation (SLB)
• Inventors: Zafari, Mohammad, Jalali, Younes
• Application Number:
  US11/688,934
• Publication Number:
  US 20080230221A1
• Time in Patent Office: Days
• US Class Current: 166/254.1
• CPC Class Codes: E21B 47/06 Measuring temperature or pressure
• 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
• CPC Class Codes: E21B 49/087 Well testing, e.g. testing for reservoir productivity or formation parameters

Abstract

A method for measuring formation property includes obtaining a set of measurements indicative of wellbore pressures for a selected duration after a pressure perturbation is created in a wellbore; obtaining at least one additional set of measurements indicative of formation pressures for the selected duration after the pressure perturbation; and deriving the formation property based on the set of measurements indicative of the wellbore pressures and the at least one additional set of measurements indicative of formation pressures. A system for measuring formation property includes a first pressure sensor disposed proximate a wellbore for measuring pressures in the wellbore; a second pressure sensor disposed in a formation at a predetermined distance from the wellbore; and a flow rate measuring device.

Claims

1. A method for measuring formation property, comprising:

obtaining a set of measurements indicative of wellbore pressures for a selected duration after a pressure perturbation is created in a wellbore;

obtaining at least one additional set of measurements indicative of formation pressures for the selected duration after the pressure perturbation; and

deriving the formation property based on the set of measurements indicative of the wellbore pressures and the at least one additional set of measurements indicative of formation pressures.

2. The method of claim 1, wherein the deriving comprises calculating differences or ratios between the first set of measurements and the at least one additional set of measurements.

3. The method of claim 1, wherein the formation property relates to a near wellbore hydraulic resistance.

4. The method of claim 1, wherein the formation property is a far field formation property.

5. The method of claim 4, wherein the far-field formation property relates to a reservoir boundary.

6. The method of claim 1, wherein the deriving involves using a Homer curve or a Bourdet curve.

7. A system for measuring formation property, comprising:

a first pressure sensor disposed proximate a wellbore for measuring pressures in the wellbore;

a second pressure sensor disposed in a formation at a predetermined distance from the wellbore; and

a flow rate measuring device.

8. The system of claim 7, further comprising a third pressure sensor disposed in the formation in the same zone as the second pressure sensor, but at a location different from that of the second pressure sensor.

9. The system of claim 8, wherein the second pressure sensor and the third pressure sensor are disposed at azimuthally different locations relative to the wellbore.

10. The system of claim 9, wherein the second pressure sensor and the third pressure sensor have an azimuthal angle separation of about 180 degrees relative to the wellbore.