Planning and real time optimization of electrode transmitter excitation

Patent metadata

Field	Value
Publication number	US-10508534-B2
Application number	US-201615533520-A
Country	US
Kind code	B2
Filing date	Sep 28, 2016
Priority date	Sep 28, 2016
Publication date	Dec 17, 2019
Grant date	Dec 17, 2019

Abstract

Planning and real time optimization of one or more modules of a downhole tool provide efficient and cost-effective deployment of a measurement system, for example, for a ranging tool. Considerations of the environment and type of operation may be considered prior to the deployment of a downhole tool such that the downhole tool comprises modules that may be optimized. Certain modules may be activated for specific operations without having to extract the downhole tool as all modules necessary to perform the specific tasks for a given operation are included prior to deployment of the downhole tool. The one or more modules may be optimized in real time based, for example, on received measurements or previous survey results. The modularity of the downhole tool allows for flexibility in fine tuning the tool according to a varying formation environment and other parameters.

First claim

What is claimed is:

1. A method for downhole ranging within a formation, the method comprising:
requesting one or more collected parameters, wherein the one or more collected parameters are requested based on a predicted operating condition for an operation;
receiving one or more collected parameters, wherein the one or more collected parameters comprise one or more ranging parameters, a frequency of a signal, a power level, a voltage level, a current level, a formation resistivity, a mud resistivity, and a borehole diameter;
determining a first configuration of a ranging tool positioned in a borehole, wherein the ranging tool comprises one or more modules, wherein each of the one or more modules are selectable and activatable, wherein the one or more modules are modular, and wherein determining the first configuration comprises:
selecting at least one of the one or more modules for the first configuration while the ranging tool is positioned in the borehole based, at least in part, on at least one of the one or more collected parameters, wherein the one or more modules comprise at least one of a transmitter module, a return module, a receiver module, a spacer module, a gap sub module, and a tool module;

activating at least one of the one or more modules of the first configuration of the ranging tool while the ranging tool is positioned in the borehole;
receiving a first measurement associated with the first configuration of the ranging tool;
determining a second configuration of the ranging tool, wherein determining the second configuration comprises:
selecting at least one of the one or more modules for the second configuration while the ranging tool is positioned in the borehole based, at least in part, on the one or more collected parameters and one or more operational conditions;

activating the at least one of the one or more modules of the second configuration of the ranging tool while the ranging tool is position in the borehole;
receiving a second measurement associated with the second configuration of the ranging tool;
analyzing operational efficiency for each of the first configuration and the second configuration based, at least in part, on the one or more collected parameters;
selecting a configuration from one of the first configuration or the second configuration based, at least in part, on the analyzed operational efficiency for each of the first configuration and the second configuration;
calculating a ranging parameter based, at least in part, on the first measurement and the second measurement; and
adjusting at least one operational parameter based, at least in part, on the calculated ranging parameter.

2. The method of claim 1 , further comprising:
comparing a simulated signal from a target to a noise level for each of the first configuration and the second configuration; and
discarding a configuration with a signal strength of the signal from the target lower than that of the noise level.

3. The method of claim 1 , wherein analyzing the operational efficiency for each of the first configuration and the second configuration comprises performing electromagnetic simulations for each of the first configuration and the second configuration.

4. The method of 1 , further comprising:
collecting the at least one of the one or more collected parameters by making a downhole measurement using the selected configuration; and
determining at least one of a distance, a direction and an orientation to a target based, at least in part, on the downhole measurement.

5. The method claim 4 , further comprising adjusting a drilling parameter based, at least in part, on the determined at least one of the distance, the direction and the orientation to the target.

6. The method of claim 1 , further comprising analyzing one or more operational constraints, wherein the one or more operational constraints comprise at least one of drilling rate, bending radius, bottom hole assembly length, total power consumption associated with each configuration, and wherein analyzing the operational efficiency for each of the first configuration and the second configuration is based, at least in part on the analyzed operational constraints.

7. The method of claim 1 , further comprising selecting at least one of the transmitter module and at least one of the receiver module based, at least in part, on a sensitivity parameter for at least one of the first configuration and the second configuration.

8. The method of claim 1 , wherein at least one of the one or more modules of the first configuration and the second configuration comprise the tool module, wherein the tool module comprises a telemetry module.

9. The method of claim 1 , wherein at least one of the first configuration and the second configuration comprises the transmitter module, the receiver module, the spacer module, the gap sub module, and the tool module, wherein the tool module comprises at least one telemetry module.

10. The method of claim 1 , wherein at least one of the first configuration and the second configuration comprises two transmitter modules and two receiver modules, wherein the receiver modules are on either side of the transmitter modules, and wherein the two receiver modules comprise at least one of a coil or magnetometer.

11. A wellbore drilling system for drilling in a subsurface earth formation, comprising:
a ranging tool coupled to a drill string;
an information handling system communicably coupled to the ranging tool, the information handling system comprises a processor and memory device coupled to the processor, the memory device containing a set of instruction that, when executed by the processor, cause the processor to:
request one or more collected parameters, wherein the one or more collected parameters are requested based on a predicted operating condition for an operation;
receive the one or more of the collected parameters, wherein the one or more collected parameters comprise one or more ranging parameters, a frequency of a signal, a power level, a current level, formation resistivity, mud resistivity, and borehole diameter;
determine a first configuration of a ranging tool positioned in a borehole, wherein the ranging tool comprises one or more modules, wherein each of the one or more modules are selectable and activatable, wherein the one or more of modules are modular, and wherein determining the first configuration comprises:
selecting at least one of the one or more modules for the first configuration while the ranging tool is positioned in the borehole based, at least in part, on at least one of the one or more collected parameters, wherein the one or more modules comprise at least one of a transmitter module, a receiver module, a spacer module, a gap sub module, and a tool module;

activate the at least one of the one or more modules of the first configuration of the ranging tool while the ranging tool is positioned in the borehole;
receive a first measurement associated with the first configuration;
determine a second configuration of the ranging tool, wherein determining the second configuration comprises:
selecting at least one of the one or more modules for the second configuration while the ranging tool is positioned in the borehole based, at least in part, on the one or more collected parameters and one or more operational conditions;

activate the at least one of the one or more modules of the second configuration of the ranging tool while the ranging tool is positioned in the borehole;
receive a second measurement associated with the second configuration;
analyze operational efficiency for each of the first configuration and the second configuration based, at least in part, on the

Assignees

• Halliburton Energy Services Inc

Inventors

• Guner Baris
• Donderici Burkay
• Capoglu Ilker R

Classifications

• E21B47/092

  by detecting magnetic anomalies · CPC title

• E21B47/022 Primary

  of the borehole, e.g. using geomagnetism · CPC title

• E21B43/2406

  Steam assisted gravity drainage [SAGD] · CPC title

• E21B47/0905

  Fixed Constructions · mapped topic

• E21B47/02216 Primary

  Fixed Constructions · mapped topic