Systems and methods of providing compensated geological measurements

Patent metadata

Field	Value
Publication number	US-2016154133-A1
Application number	US-201314347037-A
Country	US
Kind code	A1
Filing date	May 7, 2013
Priority date	May 7, 2013
Publication date	Jun 2, 2016
Grant date	—

Abstract

Disclosed are systems and method for providing compensated measurements for more accurate downhole measurement data. One measurement system includes at least two transmitters and at least two receivers disposed within at least one borehole formed in a subterranean formation, and a data acquisition system communicably coupled to the at least two transmitters and the at least two receivers and configured to activate the at least two transmitters and process time-lapsed signals received from the at least two receivers in order to generate compensated signals that minimize or eliminate multiplicative effects.

First claim

1 . A measurement system, comprising:
at least two transmitters and at least two receivers disposed within at least one borehole formed in a subterranean formation, wherein at least one of the at least two transmitters or the at least two receivers is permanently installed in the at least one borehole; and a data acquisition system communicably coupled to the at least two transmitters and the at least two receivers and configured to activate the at least two transmitters and process two or more signals received from the at least two receivers in order to generate compensated signals that minimize or eliminate multiplicative effects, wherein at least one time-lapsed compensated signal is generated from a difference between a first compensated signal and a second compensated signal.

2 . The measurement system of claim 1 , wherein the at least two transmitters and the at least two receivers are one of magnetic dipole sensors, electric dipole sensors, acoustic transmitters, or acoustic sensors.

3 . The measurement system of claim 2 , wherein the magnetic dipole sensors or electric dipole sensors are selected from a group consisting of non-tilted coil antennas, tilted coil antennas, solenoid antennas, toroidal antennas, electrode-type antennas, transceivers, and combinations thereof.

4 . The measurement system of claim 2 , wherein the acoustic transmitters and acoustic sensors are selected from a group consisting of piezoelectric transducers, magnetostrictive transducers, sparker-type transmitters, hammer-type transmitters, a drill bit, mechanical vibrators, and hydraulic vibrators.

5 . The measurement system of claim 1 , wherein at least one of the at least two transmitters and the at least two receivers is a transceiver.

6 . The measurement system of claim 1 , wherein the at least one borehole is a production well.

7 . The measurement system of claim 1 , wherein the at least one borehole is an injection well configured to inject a flood into the subterranean formation.

8 . The measurement system of claim 1 , wherein the at least one borehole comprises a first borehole and a second borehole and the at least two transmitters and the at least two receivers are disposed in at least one of the first and second boreholes.

9 . The measurement system of claim 8 , wherein at least one of the first and second boreholes is a production well.

10 . The measurement system of claim 8 , wherein at least one of the first and second boreholes is an injection well.

11 . The measurement system of claim 8 , wherein the second borehole is a lateral borehole extending from the first borehole.

12 . The measurement system of claim 8 , wherein the data acquisition system is arranged in one of the first or second boreholes.

13 . The measurement system of claim 1 , wherein the multiplicative effects include amplitude or phase shifts that are attributable to electronic drift, drift as a result of temperature change, unknown phases or amplitudes, and manufacturing and electronic differences of the at least two transmitters and the at least two receivers.

14 . The measurement system of claim 1 , wherein the at least one time-lapsed compensated signal is derived by generating a ratio from the first and second compensated signals and performing an inversion operation on the ratio to determine properties of the subterranean formation that changed between a time t 1 and a time t 2 .

15 . The measurement system of claim 14 , wherein the subterranean formation contains a flood and the compensated signals are indicative of a position of the flood at time t 1 and time t 2 .

16 . A method of monitoring a subterranean formation, comprising:
activating at least two transmitters with a data acquisition system communicably coupled thereto; collecting signals received by at least two receivers with the data acquisition system, wherein the at least two transmitters and the at least two receivers are disposed within at least one borehole formed in the subterranean formation; and generating compensated signals from the signals collected with the data acquisition system.

17 . The method of claim 16 , wherein the compensated signals comprise at least a first compensated signal calculated at a time t 1 and a second compensated signal calculated at a time t 2 , wherein time t 2 is greater than time t 1 , and wherein generating the compensated signals comprises:
generating a difference of an analytical function of the first and second compensated signals; and performing an inversion operation on the difference to determine properties of the subterranean formation that changed between time t 1 and time t 2 such that a time-lapsed compensated signal is generated.

18 . The method of claim 17 , wherein at least one property of the subterranean formation includes a position of a flood within the subterranean formation, the method further comprising determining the position of the flood at time t 1 and time t 2 .

19 . The method of claim 16 , wherein the at least one borehole is a production well or an injection well configured to inject a flood into the subterranean formation.

20 . The method of claim 16 , wherein the at least one borehole comprises a first borehole and a second borehole and the at least two transmitters and that at least two receivers are disposed in either or both of the first and second boreholes.

21 . The method of claim 20 , wherein at least one of the first and second boreholes is a production well.

22 . The method of claim 20 , wherein at least one of the first and second boreholes is an injection well configured to inject a flood into the subterranean formation.

23 . The method of claim 20 , wherein the second borehole is a lateral borehole extending from the first borehole.

24 . The method of claim 16 , further comprising using the compensated signals to minimize or eliminate multiplicative effects comprising at least one of amplitude or phase shifts that are attributable to electronic drift, drift as a result of temperature change, unknown phases or amplitudes, and manufacturing and electronic differences of the at least two transmitters and the at least two receivers.

25 . A non-transitory, computer readable medium programmed with computer executable instructions that, when executed by a processor of a computer unit, performs the method of claims 16 to 24 .

Assignees

• Halliburton Energy Services Inc

Inventors

• Donderici Burkay
• Rodney Paul

Classifications

• G01V3/38

  Processing data, e.g. for analysis, for interpretation, for correction · CPC title

• G01V1/42

  using generators in one well and receivers elsewhere or vice versa (G01V1/52 takes precedence) · CPC title

• G01V11/00 Primary

  Prospecting or detecting by methods combining techniques covered by two or more of main groups G01V1/00 - G01V9/00 · CPC title

• G01V3/30

  operating with electromagnetic waves · CPC title

• G01V1/50 Primary

  Analysing data · CPC title