The document summarizes research on the gas reservoir characteristics of shale beds in India. Some key findings include: - Shale samples from various coalfields and basins in India contain sufficient total organic carbon and gas content to be prospective for shale gas. Gas content ranges from 0.26 to 4.42 m3/t depending on location and depth. - Analysis of pyrolysis data and vitrinite reflectance indicates the organic matter in many of the shales is thermally mature for gas generation. - Testing of adsorption isotherms and pore structure show the shales have adequate surface area and microporosity for gas storage.

1. Gas Reservoir Characteristics of Shale Beds in India
By,
V. A. Mendhe, Subhashree Mishra, Alka D. Kamble and
Abhay M. Varade
CENTRAL INSTITUTE OF MINING AND FUEL RESEARCH
(COUNCIL OF SCIENTIFIC AND INDUSTRIAL RESEARCH)
BARWA ROAD, DHANBAD - 826015
28-30 November 2013, Manipur University, Imphal

2. Why Shale Gas?
CBM Recovery
 The demand of gas is significantly rising in India.
 India Natural gas demand is currently about >180 MMSCMD, while
the domestic supply is only 80 MMSCMD.
Methane Gas derived from shale is a clean energy resource.
 Shale gas is contained within the shales predominantly in adsorbed
form, in the macro, meso & micro-pores and micro-fractures.
 The gas is usually thermogenic but it also may be biogenic.
 Shale gas boom in recent years has been due to modern
technology in hydraulic fracturing to create extensive artificial
fractures around well bores.
 Development in Horizontal drilling within the shale, to create
maximum borehole surface area in contact with the shale.

3. Sedimentary
Basin of India
Source: DGH
Sedimentary area of 3.14
million Sq. Km.
26 sedimentary basins
1.35 million Sq Km. area is
in deep water
1.79 million Sq Km. area is
in onland and shallow
offshore.
At present 1.06 million Sq
Km. area is held under
Petroleum Exploration

4. Gondwana and Tertiary
Basins in India
COALFIELDS AND LIGNITE
OCCURRENCES OF INDIA
COALFIELDS AND LIGNITE
OCCURRENCES OF INDIA
500 0 500 Kilometers
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4
2
4
2
5
5
6
8
2
6 7
9
1
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1
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9 1
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1
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1 1
8 1
6
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7
2
7
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4
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1 3
4 3
0
4
4 4
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2
8
4
1
3
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3
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9
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5
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8 3
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5
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6
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6
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7
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0
Calcu tta
New Delhi
Mumbai
Chen nai
Patna
Bhu baneswar
Hyderabad
Bang alore
Gan dhin agar
Jaipur
Chan digarh
Simla
Srin agar
Lucknow
Bho pal
Gan gtok
Dispur
Shillo ng
Koh ima
Imphal
Agartala
Aizawl
Itanagar
m
96°
m
92°
m
88°
m
84°
m
80°
m
76°
m
72°
m
68°
m 24°
m20°
m28°
m32°
m 16°
m8°
m12°
m 36°
m
m m m m
88° 92°
m 84°
80°
76°
72°
36°
32°
28°
24°
20°
16°
12°
8°
%
#
5
9
1
5
2
6
2
5
4
6
0
6
1
3
2
5
5
6
5
8
6
6
5
8
5
6
3
5
3
6
4
9
4
6
7
7
5
1
5
6
6
8 6
9
3
4
1
7
5
0
1
9
2
1
6
5
7
3
0
1
8
4
8
3
1
2
2
1
1
3
2
1
2
1
6
3
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3
3
4
5
4
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2
0
2
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1
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9
1. Miao-bum
2. Namchik - Namphuk
3. Makum
4. Dilli - Jeypore
5. Tiru
6. Borjan
7. Tuen Sang
8. Jhanzi-Disai
9. Koilajan
10. Diphu
11. Bapung
12. Pynursia
13. Cherrapunji
14. Laitryngew
15. Mawsynram
16. Mawlong S hella
17. Langrin
18. Balphakram - Pendenggru
19. West Daranggiri
20. Rongrenggri
21. Siju
79. Kalakot - Mahogala
Tertiary Coalfields
22. Singrimari
23. Abor Hills
24. Daphla Hills
25. Aka Hills
26. Darjeeling
27. Rajmahal
28. Birbhum
29. Tangsuli
30. Kundait Kariah
31. Saharjuri
32. Jainti
33-34. Giridih
35. Raniganj
36. Barjora
37. Jharia
38. East Bokaro
39. West Bokaro
40. Ramgarh
41. North Karanpura
42. South Karanpura
43. Chope
44. Itkhori
45. Auranga
46. Hutar
47. Daltonganj
48-49-50. Tatapani-Ramkola
51. Singrauli
52. Korar
53. Umaria
54. Johilla
55. Sohagpur
56. Sonhat-Jhilimili
57. Bisrampur
58. Lakhanpur
59. Panchbahini
60. Dhamamunda
61. Koreagarh
62. Chirimiri
63. Sendurgarh
64. Hasdo-Arand
65. Korba
66. Mand- Raigarh
67. Ib River
68. Talcher
69. Godavari
70. Yellendu
71. Wardha
72. Bander
73. Umrer
74. Kamptee
75. Pench Kanhan
76. Pathakhera
77. Tawa
78. Mohpani
Gondwana Coalfields
1. Nichaho m Baramula
2. Nagbal
3,4. Firozpur Sh alig an ga
5. Khari
6. Gangashahr
7,8. Sarup Desar
9. Kolayat
10. Gura
11. Chaneri
12. Bithno k
13. M an dal Charn an
14. Raneri
15. Hira KiDhani
16. Lalamdesar
17. Bar Sing hsar
18. P alana
19. Kasnau
20. Kuchera
21. Nimbri
22. M arw ar Chapri
23. Butati
24. M erta Road
25. Hansiyas
26. Gangard a
27. Lamba Jatan
28. M okala
29. Indawar
30. Nagarda
31. Nimla
32. Bharka
33. Botiya
34. Hamir ji kiDhani
35. Kapurdi
36. Jalipa
37. Lakhpat
38. Dhedadi
39. Pranpur
40. Kaiyari
41. Panandhro
42. Akhrimota
43. Fu lradam
44. Umarsar
45. M udia
46. M ata No Madh
47. Jularai
48. Waghapadar
49. Lefri
50. Hamla
51. Nanaratad ia
52. Lakhanka Kharsalia
53. Bhuri
54. Shah Vastan
55. Ratnagiri
56. Nileswaram
57. M ad ayi
58. Warkala
59. M an nargudi
60. Jayamkond a Cholap uram
61. Lalpettai
62. Srimushnam
63. Neyveli Sou th
64. Bhuban giri
65. Neyveli East
66. Bahur
67,68,69. Elu ru - Rajamun
70. Domra
Lignite Occurrences
Trivandrum
km

5. Shale Bearing Gondwana and Tertiary Formations in India
Gondwana Formations Containing Shale
 Panchet
 Raniganj
 Barren Measures
 Barakar
 Karharbari
Tertiary Basins Containing Shale
 Cambay Basin
 Barmer - Sanchor
 Rajamundry
 Assam-Arakan

6. Shale Gas Potentiality Study in India
Determined in-situ gas content by Direct method including
desorbed gas, lost gas and residual gas.
Constructed adsorption isotherm and degree of gas saturation
of shale
TOC and Pyrolysis of shale samples
Surface area, pore size and pore volume

7. Samples Location
b
North &
South
Karanpura
Barmer-
Sanchor
INDIA
DELHI
Raniganj
Rajamundry
Penugonda,
West
Godavari.
West Nada
Neyveli

8. Shale Samples

9. In-Situ Gas Content by Direct Method
 Lost Gas (Q1)
 Desorbed Gas (Q2)
 Residual Gas (Q3)
Desorbed Measurements
Lost gas calculation
y = 191.73x - 923.67
R2
= 0.983
-5000
-4000
-3000
-2000
-1000
0
1000
2000
3000
4000
5000
0.00 5.00 10.00 15.00 20.00
Square root of Time (min)
Cumm.
desorbed
gas
(cc)

10. Gas Content of Shales
Coalfield/Basin Depth of Shale
(m)
Gas Content
(m3/t)
Sorption
Capacity
(m3/t)
South Karanpura 450.0 – 720.0 0.26 – 1.75 3.7 – 5.6
North Karanpura 511.0 – 791.0 1.11 – 1.69 4.5 – 4.8
Barmer - Sanchor 668.0 – 2142.0 0.94 – 2.94 3.1 – 4.7
Raniganj 520.0 – 780.0 0.90 – 2.20 4.5 – 5.8
Neyveli 105.0 – 490.0 0.42 – 1.10 4.2 – 6.4
West Godavari 2970.0 – 3020.0 2.35 – 4.42 4.0 – 5.4
Narmada Broach 2800.0 – 2850.0 1.40 – 4.50 4.4 – 5.2

11. Depth vs. Gas Content of Shale Samples

12. TOC and Pyrolysis of shale samples
• Shale contains sufficient amount of organic matter.
• TOC is essentially the total amount of organic matter
(kerogen) in a given sample of rock and TOC initiates
the evaluation of shale play.
• Shale should be subjected to the geologic processes
needed to convert organic material to oil and/or gas.
• Rock-Eval Pyrolysis evaluates the type and the
maturity of the organic matter as well as
determining its petroleum potential.
• Vitrinite reflectance (VRo) is used for determining the
thermal maturity of the shale.

13. OI vs. HI of Shale Samples
0
150
300
450
600
750
0 50 100 150 200
HI
(mg
HC/g
TOC)
OI (mg CO2/g TOC)
Type I
(Oil Prone)
Type II
(Oil Prone)
Type III
(Gas Prone)
Type IV Dry Gas

14. 0
100
200
300
400
500
600
700
800
900
1000
0.40 0.60 0.80 1.00 1.20 1.40 1.60 1.80 2.00
HI
(mg
HC/g
TOC)
VRo (%)
Type I (Oil Prone Lacustrine)
Type II (Oil Prone Marine)
Type III (Gas Prone)
Type IV
Oil Window
Wet Gas Window
Dry Gas Window
VRo Vs. HI of Shale Samples

15. 0
100
200
300
400
500
600
700
800
900
1000
360 390 420 450 480 510
HI
(mg
HC/g
TOC)
Tmax °C
Type IV
Type III
(Gas Prone)
Type II
(Oil Prone Marine)
Type I
(Oil Prone Lacustrine)
Ro % = 0.55
Oil Window
Condensate-Wet Gas Window
Ro % = 1.40 Dry Gas Window 0
200
400
600
800
1000
380 400 420 440 460 480 500
HI
(mg
HC/g
TOC)
Tmax °C
I
II
Immature Mature Post mature
0.5% Ro
1.35% Ro
Tmax vs. HI of Shale samples

16. Kerogen type
0
100
200
300
400
500
0 10 20 30 40
S2
(mg
HC/g
TOC)
TOC (wt. %)
Type I
Type II
Type III

17. Surface area, Pore size and Pore volume
y = 0.2371x
R² = 0.9965
C=129.494569
Vm=4.2176 cm3/g STP
Surface area=19.2146m2/g
y = 0.6744x + 0.0071
R² = 0.9999
C=96.600347
Vm=1.4673 cm3/g STP
Surface area=6.3885m2/g
0.00
0.05
0.10
0.15
0.20
0.25
0.00 0.05 0.10 0.15 0.20 0.25 0.30 0.35
1/[V(Po/P
-
1)]
Relative Pressure (P/Po)
0.000
0.002
0.004
0.006
0.008
0.010
0.012
0.014
0.016
0 500 1000 1500 2000
Cumulative
volume
(cm3/g)
Pore Size (Å)
NKS3
NKS2

18. Surface area Method used Result obtained
NK-S2 NK-S3
Single point surface area at P/Po 18.6201m2/g 6.2184m2/g
BET surface area 19.2146m2/g 6.3885m2/g
Micropore area T-plot micropore area 2.1267m2/g -
External surface area T-plot external surface area 17.0879m2/g 6.4602m2/g
Surface area of pores BJH adsorption 14.874m2/g 5.866m2/g
BJH desorption 16.5340m2/g 9.1857m2/g
Pore Volume Single point: Total pore volume (P/Po= 0.99) 0.028492 cm3/g 0.016255 cm3/g
Micropore Volume T-plot micropore volume 0.000798 cm3/g -
Cumulative Volume of Pores BJH adsorption 0.026232 cm3/g 0.015809 cm3/g
BJH desorption 0.026088 cm3/g 0.016518 cm3/g
Pore Size BET method 61.206 Å 101.77 Å
Adsorption average pore width
BJH adsorption 70.547 Å 107.811 Å
BJH desorption 60.115 Å 71.929 Å
DFT pore size Volume in pores < 14.83 Å 14.83 Å
Total volume in pores <= 1,172.33 Å <= 1,475.96 Å
Area in pores > 1,172.33 Å > 1,175.96 Å
Total area in pores >= 14.83 Å >= 14.83 Å
Surface area, Pore size and Pore volume

19. High Pressure Methane Adsorption Isotherm

20. Location Langmuir
Volume
(VL)
Langmuir
Pressure
(PL)
South
Karanpura
5.2 6669
4.9 6712
3.7 7022
4.8 5985
4.9 5992
South
Karanpura
5.4 6079
5.6 5837
5.4 6682
5.2 6578
5.0 6894
4.8 6472
South
Karanpura
5.6 6064
4.1 4502
South
Karanpura
4.50 6085
5.10 6208
Barmer-
Sanchor basin
4.3 6679
3.1 6899
Barmer-
Sanchor basin
3.1 7169
3.3 6638
3.6 6423
Raniganj-
coalfield
4.9 6672
Neyveli 7.9 5517
7.6 5643
Neyveli 7.7 5845
West
Godavari
4.5 6207
4.5 6131
Narmada
Broach Block
4.4 6167
4.9 5820
High Pressure Methane Adsorption Isotherm Curve

21. Shale Mineralogy
South Karanpura North Karanpura

22. NK-S2 NK-S3
Shale Mineralogy

23. Scanning Electron Microscope (SEM)
NK-S2 NK-S3

24. Summary and Conclusions
 In-situ gas content of shale core samples is observed to be low.
 Large cumulative thickness of shale beds encourage the shale gas
potential even the low gas content of shale beds.
 Investigated shale samples have indicated low moisture and sufficient TOC
content.
 Investigated shale beds having Type III kerogen and prone for gas generation.
 Adsorption isotherm results are compared with the estimated in-situ gas
content of the shale samples revealed that under to moderately saturation of
shale horizons.
 Studied shale contains mostly mesopores.
 Need of more detailed investigation on Indian shale deposits considering
viz. shale occurrence, thickness, depositional facies, shale mineralogy, type of
clays, TOC content, inorganic content, grain size, porosity and permeability for
better understanding of the shale as gas reservoir.
 Enough Shale Reservoir exist in the country.

25. Thanks for Your
Kind
Attention . . .