Modeling and production of tight hydrocarbon reservoirs

Patent metadata

Field	Value
Publication number	US-10072481-B2
Application number	US-201314013207-A
Country	US
Kind code	B2
Filing date	Aug 29, 2013
Priority date	Aug 29, 2013
Publication date	Sep 11, 2018
Grant date	Sep 11, 2018

Abstract

Methods for modeling a tight hydrocarbon reservoir intersected by a borehole. Methods include using an estimated hydrocarbons-in-place value for the tight hydrocarbon reservoir and a gas parameter associated with drilling the borehole to create a drilling model. The model may determine an operation of a well control device associated with the borehole; or correlate the hydrocarbons-in-place value with the gas parameter for the tight hydrocarbon reservoir. Other methods include determining, during the forming of the borehole, an operation of a well control device associated with the borehole using an estimated hydrocarbons-in-place for the tight hydrocarbon reservoir and a gas parameter. The gas parameter may comprise a detected gas parameter normalized using at least one corresponding drilling parameter. Further methods include employing the model for performing operations in another borehole drilled in the same reservoir. Further methods include using the model to estimate a second hydrocarbons-in-place value in the other borehole.

First claim

We claim:

1. A method for modeling a tight hydrocarbon reservoir intersected by a borehole, the method comprising:
using a drilling system to form a borehole intersecting the tight hydrocarbon reservoir by drilling the reservoir, the drilling including rotating a drill bit of the drilling system to disintegrate the tight hydrocarbon reservoir and thereby producing gas comprising gas released from pore space within rock of the formation and liberated gas released from source rock of the formation via disintegration;
using an estimated hydrocarbons-in-place value for the tight hydrocarbon reservoir and a gas parameter associated with drilling the borehole to create a drilling model, wherein the gas parameter comprises a detected gas parameter normalized using at least one corresponding drilling parameter of the drilling to account for the liberated gas released from source rock of the formation via disintegration, the detected gas parameter determined from gas information detected during the drilling using a sensor associated with the drilling system.

2. The method of claim 1 , wherein the drilling model determines an operation of a well control device associated with the borehole.

3. The method of claim 2 further comprising:
operating the well control device according to the drilling model.

4. The method of claim 1 , wherein the drilling model determines the presence of an underbalanced condition of the borehole in dependence upon a current hydrocarbons-in-place value and a current gas parameter.

5. The method of claim 1 , further comprising estimating a pore pressure associated with the tight hydrocarbon reservoir using the gas parameter.

6. The method of claim 5 wherein the drilling model determines the presence of an underbalanced condition of the borehole in dependence upon a current hydrocarbons-in-place value and at least one of: i) the gas parameter; and ii) the estimated pore pressure.

7. The method of claim 5 further comprising correlating a peak in the detected gas parameter with nominal drilling conditions using the hydrocarbons-in-place value.

8. The method of claim 1 wherein the gas parameter comprises the detected gas parameter normalized using at least one of: i) rate of penetration; ii) bit diameter; iii) borehole diameter; and iv) pump rate.

9. The method of claim 8 wherein the gas parameter comprises the detected gas parameter normalized using the formula:
GN=G ·( ROP N /ROP )·( D N /D ) 2 ·( Q/Q N )·(1/ E ),

where G N is normalized gas units, G is measured gas units, ROP N is reference rate of penetration, ROP is actual rate of penetration, D N is reference bit diameter, D is actual hole diameter, Q N is reference pump rate, Q is actual pump rate, and E is gas system efficiency.

10. The method of claim 1 wherein the detected gas parameter comprises a parameter in a wellbore during drilling, the parameter comprising at least one of i) a rate of gas production; and ii) a gas pressure.

11. The method of claim 1 further comprising estimating hydrocarbons-in-place.

12. The method of claim 1 further comprising normalizing the detected gas parameter using the drilling parameter.

13. The method of claim 1 further comprising deriving the estimated hydrocarbons-in-place using the gas parameter.

14. The method of claim 1 further comprising:
correlating an absence of kick with at least one of: i) a decreasing normalized gas trend or ii) an increasing hydrocarbons-in-place trend.

15. The method of claim 1 further comprising:
correlating kick with at least one of: i) an increasing normalized gas trend or ii) a decreasing hydrocarbons-in-place trend.

16. The method of claim 1 , wherein the model correlates the hydrocarbons-in-place value with the gas parameter for the tight hydrocarbon reservoir.

17. A method for producing a hydrocarbon from a tight hydrocarbon reservoir, the method comprising:
forming a borehole intersecting the tight hydrocarbon reservoir by drilling the reservoir, the drilling including rotating a drill bit of the drilling system to disintegrate the tight hydrocarbon reservoir and thereby producing gas comprising gas released from pore space within rock of the formation and liberated gas released from source rock of the formation via disintegration;
determining, in real-time during the forming of the borehole, an operation of a well control device associated with the borehole using an estimated hydrocarbons-in-place for the tight hydrocarbon reservoir and a gas parameter, the gas parameter comprising a detected gas parameter normalized using a drilling parameter associated with the drilling operation to account for the liberated gas released from source rock of the formation via disintegration; and
operating the well control device according to the determination.

18. The method of claim 17 further comprising using the estimated hydrocarbons-in-place value and the gas parameter to determine the mud weight.

19. The method of claim 17 wherein operating the well control device comprises leaving the well control device untriggered.

20. A method for producing hydrocarbons from a tight hydrocarbon reservoir, the method comprising:
employing a drilling model created using the method of claim 1 to perform operations in another borehole drilled in the same reservoir.

21. The method of claim 20 wherein the model correlates the hydrocarbons-in-place value with the gas parameter for the tight hydrocarbon reservoir, the method further comprising using the model to estimate a second hydrocarbons-in-place value in the another borehole.

22. The method of claim 20 further comprising creating the drilling model using the method of claim 1 .

Assignees

• Baker Hughes Inc
• Baker Hughes A Ge Co Llc

Inventors

• Bordoloi Sanjeev
• Park Namsu
• Ward Christopher David

Classifications

• E21B49/003

  by analysing drilling variables or conditions (E21B49/005 takes precedence; systems specially adapted for monitoring a plurality of drilling variables or conditions E21B44/00) · CPC title

• E21B43/00 Primary

  Methods or apparatus for obtaining oil, gas, water, soluble or meltable materials or a slurry of minerals from wells (applicable only to water E03B) · CPC title