1. Requirements and Challenges Extended Laterals
Anders Storaune, P.E.

2. True Vertical Depth Vs. Vertical Section Well Profiles Drilled to Date
Drilled Wells
2007
Aspect Ratio (AR) = 4
Aspect Ratio (AR) = 3
Aspect Ratio (AR) = 2
Aspect Ratio (AR) = 1
5000 wells drilled over the last decade.
FSD, WV, NEPA.
Well design description.
DP size. NC50.
Hole size.
9-10 DLS curve.
All wells are geosteered by in house OSC.

3. True Vertical Depth Vs. Vertical Section Well Profiles Drilled to Date
Drilled Wells
Aspect Ratio (AR) = 4
Aspect Ratio (AR) = 3
Aspect Ratio (AR) = 2
Aspect Ratio (AR) = 1
5000 wells drilled over the last decade.
FSD, WV, NEPA.
Well design description.
DP size. NC50.
Hole size.
9-10 DLS curve.
All wells are geosteered by in house OSC.

4. True Vertical Depth Vs. Vertical Section Well Profiles Drilled to Date
Drilled Wells
Aspect Ratio (AR) = 4
Aspect Ratio (AR) = 3
Aspect Ratio (AR) = 2
Aspect Ratio (AR) = 1
5000 wells drilled over the last decade.
FSD, WV, NEPA.
Well design description.
DP size. NC50.
Hole size.
9-10 DLS curve.
All wells are geosteered by in house OSC.

5. True Vertical Depth Vs. Vertical Section Well Profiles Drilled to Date
Drilled Wells
Aspect Ratio (AR) = 4
Aspect Ratio (AR) = 3
Aspect Ratio (AR) = 2
Aspect Ratio (AR) = 1
5000 wells drilled over the last decade.
FSD, WV, NEPA.
Well design description.
DP size. NC50.
Hole size.
9-10 DLS curve.
All wells are geosteered by in house OSC.

6. True Vertical Depth Vs. Vertical Section Well Profiles Drilled to Date
Drilled Wells
Aspect Ratio (AR) = 4
Aspect Ratio (AR) = 3
Aspect Ratio (AR) = 2
Aspect Ratio (AR) = 1
5000 wells drilled over the last decade.
FSD, WV, NEPA.
Well design description.
DP size. NC50.
Hole size.
9-10 DLS curve.
All wells are geosteered by in house OSC.

7. True Vertical Depth Vs. Vertical Section Well Profiles Drilled to Date
Drilled Wells
Aspect Ratio (AR) = 4
Aspect Ratio (AR) = 3
Aspect Ratio (AR) = 2
Aspect Ratio (AR) = 1
5000 wells drilled over the last decade.
FSD, WV, NEPA.
Well design description.
DP size. NC50.
Hole size.
9-10 DLS curve.
All wells are geosteered by in house OSC.

8. True Vertical Depth Vs. Vertical Section Well Profiles Drilled to Date
Drilled Wells
Aspect Ratio (AR) = 4
Aspect Ratio (AR) = 3
Aspect Ratio (AR) = 2
Aspect Ratio (AR) = 1
5000 wells drilled over the last decade.
FSD, WV, NEPA.
Well design description.
DP size. NC50.
Hole size.
9-10 DLS curve.
All wells are geosteered by in house OSC.

9. True Vertical Depth Vs. Vertical Section Well Profiles Drilled to Date
Drilled Wells
Aspect Ratio (AR) = 4
Aspect Ratio (AR) = 3
Aspect Ratio (AR) = 2
Aspect Ratio (AR) = 1
5000 wells drilled over the last decade.
FSD, WV, NEPA.
Well design description.
DP size. NC50.
Hole size.
9-10 DLS curve.
All wells are geosteered by in house OSC.

10. True Vertical Depth Vs. Vertical Section Well Profiles Drilled to Date
Drilled Wells
Aspect Ratio (AR) = 4
Aspect Ratio (AR) = 3
Aspect Ratio (AR) = 2
Aspect Ratio (AR) = 1
5000 wells drilled over the last decade.
FSD, WV, NEPA.
Well design description.
DP size. NC50.
Hole size.
9-10 DLS curve.
All wells are geosteered by in house OSC.

11. True Vertical Depth Vs. Vertical Section Well Profiles Drilled to Date
Drilled Wells
2007-Present
Aspect Ratio (AR) = 4
Aspect Ratio (AR) = 3
Aspect Ratio (AR) = 2
Aspect Ratio (AR) = 1
5000 wells drilled over the last decade.
FSD, WV, NEPA.
Well design description.
DP size. NC50.
Hole size.
9-10 DLS curve.
All wells are geosteered by in house OSC.

12. True Vertical Depth Vs. Vertical Section Future Wells
Drilled Wells
Future Wells
AR = 4
AR= 1
Cost to LP is getting higher.
Mobilization – pad cost, road limitations, curfews, etc.
Pushing completable latereral length to improve project economics.

13. True Vertical Depth Vs. Vertical Section Cost Effective with Rotary Steerable
Drilled Wells
Future Wells
Rotary Steerable
AZ GR. Near bit GR for quicker reaction time. Determine if cutting up or down structure.
Higher percentage in zone – 15%.
Tighter targets. Able to stay within tighter targets.
More inclination changes.
Smoother wellbore – DLS are cumulative. Ff reduction of Continuouse DLS vs. microdoglegs/ledges with motor. Breaking static friction factor.
Smooth wellbore – limited lowside ST capability.
Curve lateral runs – more flexible tool – more wag on AZ

14. True Vertical Depth Vs. Vertical Section Requires 7,500 psi Mud Pumps
Drilled Wells
Future Wells
Rotary Steerable
7,500 psi Mud Pumps
All our active rigs have 7500 psi mud pumps.
Utilize motor assist RSS on most wells.
Our wells have 8.5” production hole. Used 12.0 ppg pumping at 650 gpm.
Can LD motor to reduce some SPP.
Can drill further, but have to back down on flow rate, which will slow down ROP and hole cleaning.

15. True Vertical Depth Vs. Vertical Section Requires 5.5” Drillpipe
Drilled Wells
Future Wells
Rotary Steerable
7,500 psi Mud Pumps
5.5” Drillpipe
Get out to around 25,000 ft MD:
Pressure limit even with 7500 psi mud pumps.
Reaching TQ limit on NC50 connections.
Reaching tensile limit on 5” S # DP.
TQ limit – 0.3 ff.
Tensile limit.

16. Challenges Going Forward
Fatigue Failures
Fishing Options
Sidetrack Options
Historically, fatigue accounts for roughly 80% of DP mechanical failures. Stress relieve groove.

17. Thank You