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Deep Gas Reservoir Play, Central and Eastern Gulf.

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Presentation on theme: "Deep Gas Reservoir Play, Central and Eastern Gulf."— Presentation transcript:

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 Location K’

10 North Louisiana Salt Basin Cross Section N S VE: 32X

11 API: 1706920079 Burial History Profile North Louisiana Salt Basin - Sediment accumulation rates were greatest in the Jurassic (196-264 ft/my) - 50-60% of the tectonic subsidence occurred in the Late Jurassic (135-157 ft/my)

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

13 Burial History Profile NLSB, Sabine Uplift

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

15 North Louisiana Salt Basin Cross Section W 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 N S

19 Burial History Profile Mississippi Interior Salt Basin

20 Thermal Maturation and Expulsion History

21 North Louisiana Salt Basin Cross Section Location Cross Section Location K’

22 Model Calibration

23 Thermal Maturation History Profile North Louisiana Salt Basin

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

25 Hydrocarbon Expulsion Profile North Louisiana Salt Basin Peak Oil Peak Gas

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

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

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


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