Method of testing a subsurface formation for the presence of hydrocarbon fluids

1. A method of testing a subsurface formation for the presence of hydrocarbon fluids, and the method comprising:

running a setting tool and an attached downhole tool assembly from a surface and into a wellbore, the downhole tool assembly having a whipstock member and a set of slips;

locating the downhole tool assembly at a desired first depth adjacent the subsurface formation;

actuating the setting tool to (i) rotate the whipstock member along the downhole tool assembly from a first run-in position, to a second set position, and (ii) actuate the slips along the downhole tool assembly from a first run-in position to a second set position, wherein the slips are pivoted outwardly to engage an inner wall of production casing and to anchor the downhole tool at the first depth;

retrieving the setting tool from the wellbore and back to the surface;

running a hydraulic jetting hose into the wellbore to the first depth along the subsurface formation;

forming a first window through the production casing at the first depth;

running the jetting hose through the first window by turning the jetting hose along a curved face of the whipstock member and across a full inner diameter of the production casing;

further injecting hydraulic fluid through the jetting hose to jet a first lateral borehole from the first window and into the subsurface formation;

monitoring fluid returns while jetting the first lateral borehole to determine the presence of hydrocarbon fluids; and

removing the jetting hose from the first lateral borehole and the first window.

2. The method of claim 1 , wherein:

the wellbore has a slim hole region above the subsurface formation, the slim hole region defining an inner diameter that is less than the inner diameter of the production casing;

the whipstock member is configured to rotate from its first run-in position such that the whipstock member may pass through the slim hole region along the wellbore, to its second set position below the slim hole region in response to a force applied to the downhole tool assembly within the wellbore.

3. The method of claim 2 , wherein:

running a hydraulic jetting hose into the wellbore comprises running the jetting hose through the slim hole region and along the curved face of the whipstock member adjacent the first window wherein the curved face creates a bend radius for the jetting hose;

in the set position, the whipstock member is configured to receive the jetting hose from the surface and to direct the jetting hose to a window location in the production casing; and

actuating the setting tool takes place after running the setting tool and the attached downhole tool assembly beyond the slim hole region.

4. The method of claim 1 , wherein:

the wellbore is completed vertically;

the hydraulic fluid comprises water and a suspended abrasive material; and

the first lateral borehole extends to a length of between 10 feet and 500 feet from the wellbore.

5. The method of claim 4 , further comprising:

removing the jetting hose from the wellbore;

re-running the setting tool into the wellbore to re-engage the downhole assembly;

releasing the slips from their second set position back to their first run-in position;

relocating the downhole assembly to a second depth along the wellbore, and re-setting the slip at the second depth;

disengaging the setting tool from the downhole tool assembly and retrieving the setting tool back to the surface;

forming a second window through the production casing at the second depth;

running the jetting hose through the second window;

injecting hydraulic fluid through the jetting hose to jet a second lateral borehole through the second window and into the subsurface formation; and

monitoring fluid returns while jetting the second lateral borehole to determine the presence of hydrocarbon fluids.

6. The method of claim 5 , wherein:

the wellbore is completed vertically;

the hydraulic fluid comprises water and a suspended abrasive material; and

the tool assembly has an outer diameter of 1.6 inches to 2.3 inches in its run-in position.

7. The method of claim 5 , wherein:

re-engaging the downhole assembly comprises re-actuating the setting tool to (i) rotate the whipstock member along the downhole tool assembly from its first run-in position to its second set position, and (ii) re-actuating the slips along the downhole tool assembly from their first run-in position back to their second set position, before running the jetting hose through the second window; and.

8. The method of claim 7 , further comprising:

producing formation fluids from the subsurface formation while injecting hydraulic fluid through the jetting hose and into the first lateral borehole; and

determining that hydrocarbon fluids are not present in desired volumes from monitoring fluid returns from the first lateral borehole.

9. The method of claim 7 , wherein:

the method further comprises:

producing formation fluids from the subsurface formation while injecting hydraulic fluid through the jetting hose and into the first lateral borehole; and

producing formation fluids from the subsurface formation while injecting hydraulic fluid through the jetting hose and into the second lateral borehole.

10. The method of claim 4 , wherein the slim hole region defines (i) one or more packers, (ii) one or more seating or profile nipples, (iii) a production tubing, (iv) a repair casing, or (v) combinations thereof placed along the inner diameter of the production casing.

11. The method of claim 4 , further comprising:

producing formation fluids from the subsurface formation while injecting hydraulic fluid through the jetting hose and into the first lateral borehole.

12. The method of claim 11 , wherein:

the wellbore is substantially horizontal at a depth of the subsurface formation; and

the first lateral borehole extends substantially normal to the wellbore.

13. The method of claim 4 , wherein:

the whipstock member comprises a curved face configured to receive the jetting hose and redirect the hose about 90 degrees when the whipstock member is rotated into its set and operating position; and

the force applied to the tool assembly comprises a hydraulic force.

14. The method of claim 4 , wherein the first window is formed by milling.

15. The method of claim 4 , wherein the first window is formed by hydraulic jetting using the jetting hose and a nozzle.

16. The method of claim 1 , further comprising:

determining that hydrocarbon fluids are present in desired volumes from monitoring fluid returns from the first lateral borehole;

removing the jetting hose from the wellbore;

re-running the setting tool into the wellbore to re-engage the downhole assembly;

rotating a portion of the downhole assembly supporting the whipstock member a designated number of degrees within the production casing about a longitudinal axis of the wellbore while the whipstock member is in its set position;

disengaging the setting tool from the whipstock member and retrieving the setting tool to the surface;

forming a second window through the production casing at the first depth;

re-running the jetting hose into the wellbore and through the second window; and

injecting additional hydraulic fluid through the jetting hose to jet a second lateral borehole through the second window and into the subsurface formation.

17. The method of claim 1 , wherein the whipstock member is configured to rotate substantially across, and the slips are configured to set in, production casing having an inner diameter of 3.8 inches to 6.5 inches.

18. The method of claim 1 , wherein the whipstock member rotates about a pin when moving from its run-in position to its set position.