1. Deep Gas Reservoir Play, Central and Eastern Gulf

2. Summary Introduction Petroleum System Analysis Resource Assessment
Exploration Strategy

3. Introduction

4. Gulf Coast Interior Salt Basins

5. Stratigraphy

6. Petroleum System Analysis

7. Petroleum Source Rocks
Upper Jurassic Smackover lime mudstone beds served as an effective regional petroleum source rock
Upper Cretaceous Tuscaloosa Marine shale beds served as a local source rock
Upper most Jurassic and Lower Cretaceous beds were possible source rocks

8. Burial History

9. North Louisiana Salt Basin Cross Sections LocationK’

10. North Louisiana Salt Basin Cross Section
Well logs have been digitized. The types of logs used are SP and resistivity. Tops of each formation at individual well are recognized by well log signals. The strata thickness increases from updip to downdip. In the updip of the basin, parts of the Lower Cretaceous strata have been eroded.
VE: 32X

11. Burial History Profile North Louisiana Salt Basin
API:
- Sediment accumulation
rates were greatest in the
Jurassic ( ft/my)
% of the tectonic
subsidence occurred in the
Late Jurassic ( ft/my)
Fastest subsidence rates late Jurassic and Early Cretaceous
Mid-Cenomanian and Late Cretaceous Uplift resulted in slower subsidence rates
Subsidence increased in early Paleocene
Subsidence continued through Miocene, although at slower rates
Present-day depths are maximum burial depths

12. North Louisiana Salt Basin, Sabine Uplift Cross Section
VE: 22X

13. Burial History Profile NLSB, Sabine Uplift

14. North Louisiana Salt Basin, Monroe Uplift Cross Section
VE: 30X

15. North Louisiana Salt Basin Cross SectionW E
VE: 22X

16. Burial History Profile NLSB, Monroe Uplift

17. Mississippi Interior Salt Basin Cross Section Location

18. Mississippi Interior Salt Basin Cross Section
VE: 16X

19. Burial History Profile Mississippi Interior Salt Basin

20. Thermal Maturation and Expulsion History

21. North Louisiana Salt Basin Cross Section LocationK’

22. Model Calibration

23. Thermal Maturation History Profile North Louisiana Salt Basin

24. Thermal Maturation Profile Cross Section North Louisiana Salt Basin
Average Maturation Depth
6,500ft
12,000ft

25. Hydrocarbon Expulsion Profile North Louisiana Salt Basin
Peak Oil
Peak Gas
To adjust for the loss of organic carbon due to thermal maturation process, the original TOC values in the study area were estimated according to the method of Daly and Edman (1987) for thermal maturation modeling. The results show that original TOC was reduced by times during the thermal maturity process.

26. Thermal Maturation History Profile NLSB, Sabine Uplift

27. Hydrocarbon Expulsion Plot NLSB, Sabine Uplift

28. Thermal Maturation History Profile NLSB, Monroe Uplift

29. Hydrocarbon Expulsion Plot NLSB, Monroe Uplift

30. Mississippi Interior Salt Basin Cross Section Location

31. Thermal Maturation History Profile Mississippi Interior Salt Basin

32. Average Maturation Depth
Thermal Maturation Profile Cross Section Mississippi Interior Salt Basin
Average Maturation Depth
8,000ft
16,000ft

33. Hydrocarbon Expulsion Plot Mississippi Interior Salt Basin
Peak Oil
Peak Gas

34. Comparison of NLSB and MISB
Modified from Mancini et al. (2006a)

35. Event Chart for Smackover Petroleum System in the North Louisiana and Mississippi Interior Salt Basins

36. Geologic Model SSW-NNE Section (B-B’)

37. Oil Migration SW-NE Section (B-B’)

38. Gas Migration SW-NE Section (B-B’)

39. Gas Migration at 99 Ma
SW-NE Section (B-B’)

40. Geologic Model NW-SE Section

41. Gas Migration Profile NW-SE Section

42. Gas Migration at 99 Ma NW-SE Section

43. Geologic Model N-S Section

44. Oil Migration N-S Section

45. Gas Migration at 99 Ma N-S Section

46. Geologic Model N-S Section (Monroe Uplift)

47. Oil Migration N-S Section (Monroe Uplift)

48. Gas Migration at 52 Ma N-S Section (Monroe Uplift)

49. Resource Assessment

50. Production Data

51. Production Data

52. Methodology for Resource Assessment

53. Schmoker (1994)
The mass of hydrocarbons generated from a petroleum source
rock can be calculated by using the following equations:
1. (TOC wt%100)(FD)(VU) = MOG
2. HI Original – HI Present = HG
3. (MOG) (HG) (10-6kg/mg) = HCG
Where: TOC = total organic carbon
FD = formation density
VU = volume of unit
MOG = mass of organic carbon
HI = hydrogen index
HG = hydrocarbons generated per gram of organic carbon
HCG = hydrocarbon generated by source rock unit

54. Key Parameters

55. Basin Parameters

56. NLSB Platte River Software — Gas Generated
TOC = 1.0%
Type II kerogen
Transient heat flow
6,400 TCF
By P. Li

57. NLSB Platte River Software — Gas Expelled
TOC = 1.0%
Type II kerogen
1,280 TCF
By P. Li

58. MISB Platte River Software — Gas Generated
TOC = 1.5%
Type II kerogen
Transient heat flow
3,130 TCF
By P. Li

59. MISB Platte River Software — Gas Expelled
TOC = 1.5%
Type II kerogen
Transient heat flow
843 TCF
Saturation threshold = 0.1
By P. Li

60. Comparison of Hydrocarbon Generation & Expulsion Volumes
Modified from Mancini et al. (2006b)

61. Gas Resource
*Assuming that 75% of total gas calculated with the Platte River Software Approach is from late cracking of oil
in the source rock.
**Assuming a 1 to 5% efficiency in expulsion, migration and trapping processes.

62. Exploration Strategy

63. NLSB Thermal Maturation

64. MISB Thermal Maturation

65. Manila-Conecuh Thermal Maturation

66. Reservoir Characteristics

67. Deep Gas Reservoir Areal Distribution

68. Conclusions
In the North Louisiana Salt Basin, Upper Jurassic and Lower Cretaceous Smackover, Cotton Valley, Hosston, and Sligo have high potential to be deeply buried gas reservoirs (>12,000 ft).
In the Mississippi Interior Salt Basin, Upper Jurassic and Lower Cretaceous Norphlet, Smackover, Haynesville, Cotton Valley, Hosston, and Sligo have high potential to be deeply buried gas reservoirs (>16,500 ft).