1. New Exploration Gas Prospect
Simulation Study Investigating:
Well arrangements to recover hydrocarbons
Production profiles and recovery factors
Sensitivity to rock compressibility
Sensitivity to target deliverability rate
Sensitivity to tubing size – 3.5 versus 4.5

2. New Exploration Gas Prospect
Top of Structure – Sand A

3. Eugene Island -Thunderbolt Prospect
Top of Structure - Sand B

4. New Exploration Gas Prospect
Top of Structure - Sand C

5. New Exploration Gas Prospect
Sand A BCF

6. New Exploration Gas Prospect
Gas Zone - Sand B, 938 BCF

7. New Exploration Gas Prospect
Gas Zone - Sand C, 642 BCF

8. Completion Strategy Objectives:
Maintain deliverability targets – 300 / 715 mmcf/d cases
Produce all fault blocks efficiently
Complete largest targets first
Only plugback completions
Resulting Completion Strategy:
11 wells required
2 wells in Sand A
6 wells in Sand B
3 wells in Sand C
6 wells required at time 0 for 300 mmcf/d case
2 recompletions – A and E both from to ft.

9. Well Completions in Sand A
715 mmcf/d, 4.5 tbg, Cr =15E-6
Well I BCF
Well K – 105 BCF

10. Well Completions in Sand B Well E – 29 BCF, recompletion
715 mmcf/d, 4.5 tbg, Cr =15E-6
Well E – 29 BCF, recompletion
Well H – 150 BCF
Well F – 189 BCF
Well J – 174 BCF
Well B – 123 BCF
Well C – 56 BCF
Well D – 34 BCF

11. Well Completions in Sand C
715 mmcf/d, 4.5 tbg, Cr =15E-6
Well E – 86 BCF
Well G – 185BCF
Well A – 178 BCF

12. Comparison – low vs. high Crock
715 mmcf/d, 3.5 tbg, Cr =15E-6 and 5E-6

13. Comparison – 3.5 vs 4.5 tbg
715 mmcf/d, Cr = 5E-6

14. Conclusions Recoveries between 45-52 % possible
Low recoveries for high Crock, 3/1 Aquifer
11 wells for 715 mmcf/d
6 wells followed by 5 drilled wells for 300 mmcf/d
4.5 tubing increases gas recovery for 715 mmcf/d
50 BCF additional reserves vs. 3.5 tubing
Tubing size does not increase ultimate recovery or deliverability significantly for 300 mmcf/d case