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8/4/2019 Fire in Ice Milkov
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Gas Hydrate Resource Potentialin the Gulf of Mexico
Alexei V. Milkov
BP America, Houston TX
This work has been done at Texas A&M University and
Woods Hole Oceanographic Institution.
The presented interpretations and ideas do not
necessarily reflect the viewpoint of BP.
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U.S. natural gas demand and supply
Provided by DOE
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What is gas hydrate?
Pictures provided by ODP, GEOMAR, A.V. Milkov, and R.Sassen
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Global distribution of gas hydrates
After Milkov and Sassen, 2002
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Global submarine gas hydrate estimates
Milkov (in press, Earth-Science Reviews)
Kvenvolden
(1988)ODP 164
ODP 204
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Looking for trends
Milkov (in press, Earth-Science Reviews)
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Organic carbon in the Earth
Kvenvolden, 1988
Milkov (in press, Earth-Science Reviews)
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Gas hydrates in the Gulf of Mexico
Modified from Milkov and Sassen, 2003 (bathymetry courtesy of Dr. W.Bryant)
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Conceptual model for gas hydrate occurrence
0
2
4
6
8
10
12
14
16
18
20
22
Abyssalplain
Sigsbee ScarpShelfIsolated
stocks
Minibasin
D e p t h ,
k m
Area of gas hydrate occurrence
SaltBacterial methanehydrates in minibasins
Bacterial and thermogenicstructurally-focused gas hydrates
Milkov and Sassen, 2001
G l i l ifi i f h d
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Geologic classification of gas hydrateaccumulations
Gulf of Mexico
Hydrate Ridge(southern summit)
Blake Ridge
Nankai Trough(???)
Haakon Mosby
mud volcano
Caspian Sea
Blake Ridge(???)
Milkov and Sassen, 2002
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Origin of gas hydrates
Data from Paull et al., 2000 and Sassen et al., 1999
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Area of gas hydrate resource estimation
Gas hydrates, seeps, and fields after Sassen et al., 1999
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Data and assumptions (1)
• Gas availability and composition (%)
Sample C1 C2 C3 i-C4 n-C4 i-C5 n-C5
1 100 0 0 0 0 0 0
2 95.9 2.4 1.2 <0.1 0.3 0.2 <0.1
3 90.4 4.5 3.7 0.6 0.6 0.2 <0.1
Data after Sassen et al., 1999
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Data and assumptions (2)• Pore water salinity - 35 g/l
• Hydrostatic pressure gradient - 10 MPa/km
• The effect of porous media is not considered
Sloan’s (1998) CSMHYD Hydrate Program was used
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Bathymetry of the study area
East Breaks
Alaminos Canyon Keathley Canyon
Garden Banks
Walker Ridge Lund
Atwater
MississippiCanyon
50 km Green Canyon
2 1 0 0
7 0 0
9 0 0
1 1 0 0
1 3 0 0
1 5 0 0
1 7 0 0
1 9 0 0
7 0 09 0 0
1 1 0 0
1 3 0 0
7 0 0
9 0 0
1 1 0 0 1 3 0
0
1 5 0 0
1 9 0
0
9 0 0
7 0 0
Shallow thermogenic gas hydrate
Oil and gas seeps with chemosynthetic communities
Shallow and deep biogenic gas hydrate
Boundary of the gas hydrate resource estimation area7 0 0
Bathymetry contour lines
After Bryant et al., 1990
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Bottom water temperature vs. water
depth in the study area
T = 295.08xB-0.5727
R2 = 0.9664
25
20
15
10
5
00 1000 2000 3000
Water depth (B), m
W a t e r t e m
p e r a t u r e ( T ) , 0 C
Data after Wash et al., 1998
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Geothermal gradients in the study area
East Breaks
Alaminos Canyon Keathley Canyon
Garden Banks
Walker Ridge
Green Canyon
Lund
Atwater
Mississippi
Canyon
50 km
34.123.7 19.3
30.6
18.1 18.1 18.3
20.9
18.8
23.618.5
22.0 24.2 20.6
27.7
21.7 23.0
18.125.4
22.1
30.1
17.0
20.0
8.0
Geothermal gradients calculated from BHT
Boundary of the gas hydrate resource estimation area
Geothermal gradients calculated from heat flow measurements
Data courtesy of MMS and from Epp et al. (1970)
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Geothermal gradients vs. water depth
in the study area
G = -9.6092xLn(B) + 88.4
R2 = 0.5917
25
20
15
10
5
0 1000 2000 3000
Water depth (B), m
G e o t h e r m a l g r a d i e n t ( G ) , o C / k m
30
35
40
Data courtesy of MMS and from Epp et al. (1970)
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Gas hydrate stability conditions
25
20
15
10
5
00 1000 2000 3000
Depth (D), m
T e m p
e r a t u r e ( T s t
) , 0 C
Tst_90.4 = 6.6877xLn(D) - 27.637
R2 = 0.9942
Tst_95.9 = 7.1458xLn(D) - 33.908
R2 = 0.9963
Tst_100 = 8.9449xLn(D) - 50.148
R2 = 0.9991
30
4000
100% CH4:
95.9% CH4:
90.4% CH4:
Calculated using Sloan’s (1998) CSMHYD Hydrate Program
G h d bili
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Gas hydrate stability zones vs.
water depth in the study area
Milkov and Sassen, 2001
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Thickness of the methane GHSZ
East Breaks
Alaminos Canyon Keathley Canyon
Garden Banks
Walker Ridge Lund
Atwater
MississippiCanyon
50 kmGreen Canyon
Boundary of the gas hydrate resource estimation area
Thickness of GHSZ (100% CH4) contour lines
2 0 0
2 0 0
0
4 0 0
6 0 0
1 0 0 0
800
1 2 0 0
0
2 0 0
400 6 0
0
8 0 0
1 0 0 0
2 0 0
0 4 0 0
Milkov and Sassen, 2001
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Thickness of the thermogenic
(95.9% C1) GHSZ
East Breaks
Alaminos Canyon Keathley Canyon
Garden Banks
Walker Ridge Lund
Atwater
MississippiCanyon
50 km Green Canyon
Boundary of the gas hydrate resource estimation area
Thickness of GHSZ (95.9% CH4) contour lines
1 0 00
1 2 0 0
1 2 0 0
6 0 0
8 0 0
2 0 0
400
2 0 0
2 0 0
6 0 0
8 0 0
1 0 0
0
400
2 0 0
4 0 0
6 0 0
8 0 0
Milkov and Sassen, 2001
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Thickness of the thermogenic
(90.4% C1) GHSZ
3 0 0
500
7 0 0
9 0 0
5 0 07 0 0
9 0 0
1 1 0 0
1 3 0 0
1 5 0 0
5 0 0
7 0 0
3 0 0
9 0 0
110 0
1 3 0 0
1 5 0 0
East Breaks
Alaminos Canyon Keathley Canyon
Garden Banks
Walker Ridge Lund
Atwater
MississippiCanyon
50 kmGreen Canyon
Boundary of the gas hydrate resource estimation area
Thickness of GHSZ (90.4% CH4) contour lines
Milkov and Sassen, 2001
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Salt distribution map
50 kmEast Breaks
Alaminos Canyon Keathley Canyon
Garden Banks
Walker Ridge
Atwater
Mississippi
Canyon
Green Canyon
Boundary of the gas hydrate resource estimation area
Top salt less than 1.0 sec subseafloor
Top salt 1.0 - 2.0 sec subseafloor
Top salt 2.0 - 4.0 sec subseafloor
Top salt >4.0 sec subseafloor
Shallow thermogenic gas hydrate
Oil and gas seeps with chemosynthetic communities
Shallow and deep biogenic gas hydrate
After Watkins et al., 1996
Mi ib i
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Minibasin geometry map
East Breaks
Alaminos Canyon Keatley Canyon
Garden Banks
Walker Ridge Lund
Atwater
Mississippi
Canyon
50 km
Green Canyon
Minibasins
Allochthonous salt
Shallow thermogenic gas hydrate
Oil and gas seeps with chemosynthetic communities
Shallow and deep biogenic gas hydrate
Mississippi Fan
Boundary of the gas hydrate resource estimation area
Compiled from Koch et al., 1998 and Risch, 1995
St t ll f d h d t
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Structurally-focused gas hydrate
between minibasins• The total volume of the GHSZ between minibasins:
- ~12,000 km3 for 95.9 % of C1
- ~16,000 km3 for 90.4 % of C1
• Gas hydrate saturation: 0.5 vol.% of sediments
• Gas hydrate yield: 140 m3 of gas per 1 m3 of gas hydrate at STP
8-11 x 1012 m3 (280-390 TCF) at STP
(methane + C2+ hydrocarbon gases)
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Gas hydrate in minibasins
• The total volume of the GHSZ between minibasins:
- ~12,000 km3 excluding Mississippi Fan
- ~17,000 km3 including Mississippi Fan
• Gas hydrate saturation: 0.1 vol.% of sediments
• Gas hydrate yield: 150 m3 of gas per 1 m3 of gas hydrate at STP
2-3 x 1012 m3 (70-105 TCF) of methane at STP
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Summary of GoM regional estimation
• Combined estimate of the gas hydrate resource in the Gulf ranges from 10 to 14 trillion m3 (~350-495 TCF) :
- Significantly less than previous (Collett, 1995) estimate;
- ~ 30-40 times more gas than in conventionalreservoirs.
• Bacterial gas hydrate in minibasins is disseminated and noteconomically significant.
• Structurally-focused gas hydrate accumulations are
economically viable and should be a priority for further researchin the GoM.
See Milkov and Sassen (2001, Marine Geology) for details
Estimates of hydrate bound gas in
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Estimates of hydrate-bound gas in
individual accumulations
Oil&Gas Journal., 1999
Seismic
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Seismic
profiles acrossgas hydrate
accumulations Lee, 1995
Lee, 1995
Sager and Kennicutt, 2000
S b i h d t t bilit
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Submarine gas hydrate stability zone
Bottom water temperature
Geothermal gradient
Pressure
Pore water salinity
Gas composition
Milkov and Sassen, 2003
Southern summit of Hydrate Ridge
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Juan de Fucaplate
B l a n c o T r a n s f o r m
Mendocino Transform
Gordaplate
Explorerplate
Oregon
HydrateRidge
North Americanplate
Southern summit of Hydrate Ridge
• A poor but the only availabledrilled analogue for GoM high-flux
accumulations?
• Southern summit: high seafloor
reflectivity, gas vents, exposed gashydrate, and a chemosynthetic
community surrounding a 50-m-
high carbonate pinnacle
• Sites 1249 and 1250 lie beneath778–796 m of water
• A strong BSR at ~110-115 mbsf
• Brine (>106 g kg-1) present in
shallow sediments• Gas hydrate was sampled and
inferred to occur throughout the
section
But what are theconcentrations???
Images from Tréhu et al., 2002
ODP Pressure Core Sampler
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p
• PCS is a downhole tool developed at
ODP (Pettigrew, 1992) to samplemarine sediments under in situpressure (up to ~70 MPa).
• If the recovered sediment core is notpressurized, about 99% of gas may belost (Paull and Ussler, 2001). Thus,the PCS is a great tool to measure the
in situ concentration of natural gases.• Data obtained from the PCS degassing
experiments and properly analyzed
may be used to estimate gas and gashydrate concentration in situ.
• PCS has been successfully used onLegs 164, 201, and 204.
Milkov et al., 2003
Volume of hydrate bound gas
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Volume of hydrate-bound gas
• Gas hydrate concentrations at
Sites 1249 and 1250:
~1% to 43% of porosity (average
~11%) above the BSR (all corestaken)
• Area: 0.19 km2 (high seafloor
reflectivity)
• Thickness of the hydrate-bearingsediments: 115 m
• Gas yield of hydrate-bearing
sediments: ~13.5 m3 /m3
Images from Tréhu et al., 2002
V=VGHZ
×D = 0.19×106 m3 ×115m × 13.5 m3 /m3=
= ~3 ×108 m3 = ~0.01 tcf See Milkov et al. (2003, Geology) for details
Gas hydrate concentrations
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Gas hydrate concentrations
Hydrate Ridge offshore OR(summit = high gas flux setting)
Chen and Cathles, 2003
Milkov and Sassen, 2003
Gulf of Mexico
Milkov et al., 2003
Green Canyon (GC) 184/185) )
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Green Canyon (GC) 184/185
Water depth: 540-650 mArea:
Bush Hill mound – 101,300 m2
Hazy reflections – 350,700 m2
GHSZ:
Thickness – 370-390 m
Volume – 0.175×109
m3
GH concentration: 1-10%
GH composition: 77.5% C1
Volume of gas: (0.5-1.6)×109
m3
0.017-0.056 tcf
M i l k o v a n d S a s s e n ,
2 0 0 3
( b a s e d o n N e u r a u t e r
a n d B r y a n t (
1 9 9 0 ) , C o o k
a n d D ’ O n f r o
( 1 9 9 1 )
Major uncertainty:
Gas hydrate distribution
Mississippi Canyon (MC) 852/853
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Mississippi Canyon (MC) 852/853
Water depth: 1080-1120 mArea: 1,935,500 m2
GHSZ:
Thickness – 780 m
Volume – 1.5×109 m3
GH concentration: 5-10%
GH composition: 75.2% C1
Volume of gas:
(11.4-22.7)×109 m3
0.4-0.8 tcf M
i l k o v a n d S a s s e n , 2
0 0 3
( b a s e d o n S a g e r a n
d K e n n i c u t t ( 2 0 0 0 ) a n d p r o p r i e t a r y d a t a )
Major uncertainty: GHSZ
Effect of migrating brines?
Green Canyon (GC) 204
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Green Canyon (GC) 204
M i l k o v a n d S
a s s e n , 2 0 0 3
( b a s e d o n B r o
o k s e t a l . ( 1 9
8 6 ) , S a s s e n e
t a l . ( 2 0 0 3 ) ) Water depth: 850-1000 m
Area: 26,131,000 m2
GHSZ:
Thickness – 640 m
Volume – 16.7×109 m3
GH concentration: 1-5%
GH composition: 61.9% C1
Volume of gas:
(25.1-126)×109 m3
0.9-4.5 tcf
Major uncertainty:Gas hydrate distribution
Atwater Valley (AT) 425/426
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Atwater Valley (AT) 425/426
Water depth: 1920-1940 mArea: 5,650,000 m2
GHSZ:
Thickness – 380 m
Volume – 2.2×109 m3
GH concentration: 5-10%
GH composition: 91.9% C1
Volume of gas:
(16-32)×109 m3
0.6-1.1 tcf M
i l k o v a n d S a
s s e n , 2
0 0 3
( b a s e d o n S a g e r a n
d K e n n i c u t t ( 2 0 0 0 ) a n d p r o p r i e t a r y d a t a )
Major uncertainty: GHSZ
Effect of migrating brines?
Resource and economic potential
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Resource and economic potential
Characteristic GC184/185
GC234/235 B
88
MC798/842
GC204
MC852/
853
AT425
Water depth (m) 500-650 500-670 650-750 807-820 850-1000 1080-
1120
1920-
1940
Resource
(m3 (×108))
(tcf)
4.9-15.9
0.017-
0.056
18.4-36.8
0.065-0.13 1.2-237
.11-0.84
.7-14
.017-0.050
251-1260
0.9-4.5114-
227
0.4-0.8
160-
320
0.6-1.1
Recovery factor High High High High High High High
Development and
production costs
Low Low Low Average Average Aver. High
Infrastructure Good Average Good Average Good Good Poor
Economic potential
(rank)Low
(6)
Low
(5)
Aver.
(3) ow
7)
Average
(2)
High
(1)
Aver
(4)
See Milkov and Sassen, 2003 (Marine and Petroleum Geology) for details
Major exploration challenges
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Major exploration challenges
• Define gas hydrate plays and types of accumulations:
- No data below 6 mbsf at high flux sites;
- To date, no significant concentrations at depth <40 mbsf awayfrom high flux sites.
- Are there other gas hydrate plays? Are there shallow sandreservoirs within the GHSZ accessible to hydrocarbon charge?Are there free gas accumulations trapped by hydrates?
• Understand the variations in the GHSZ:
- What is the composition of hydrocarbon charge?
- What is the salinity of migrating fluids?
- What is the heat flow?
A new gas hydrate play?
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g y p y
Gas accumulations
trapped by gas hydrates?
Image from Snyder et al. (NETL Gas Hydrate web site)
Major technological challenges
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Major technological challenges
• No proven recovery technologies:
- Onshore (polar) accumulation may not be an appropriateanalogue? Depressurization is not a viable mechanism?
- Thermal stimulation with chemical inhibition? But tooshallow for horizontal wells?
• Seafloor instability. Gas hydrates appear to be relativelystable and cementing sediments at present, but theirdecomposition during recovery may result in seafloorinstability.
• Chemosynthetic communities. What are the environmentalimplications of gas hydrate recovery?
See Milkov and Sassen, 2003 (Marine and Petroleum Geology) for details
Conclusions
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• The results and interpretations of gas hydrate resource potential in
the GoM bear huge uncertainties.
• Significant progress has been made during the last 5 years through
integration of available “academic” information on gas hydrate
distribution and geochemistry.
• The volume of hydrate-bound gas in the GoM may be large, but
smaller than previously thought.
• Some shallow structural accumulations in the GOM may provide
gas reserves and deserve both attention and investment. New gas
hydrate plays may emerge but need to be tested.• The academia lacks many capabilities and sometimes lacks focus.
More active involvement of industry and collaboration between
industry, academia and government are the keys to the betterevaluation of the prize.
A k l d t
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Acknowledgments
Applied Gas Hydrate Research Program at GERG/TAMU
Postdoctoral Scholarship at WHOIBP America for continuous support
The scientists and crew of the R.V. Edwin Link and the Johnson Sea-Link research submersibles, University of
North Carolina at Wilmington and NOAA/NURP for
assistance in collecting deep sea floor samples.
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Additional Slides
Green Canyon (GC) 234/235
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y ( )
Water depth: 500-670 mArea: 612,400 m2
GHSZ:
Thickness – 400 mVolume – 0.25×109 m3
GH concentration: 5-10%
GH composition: 74.3% C1
Volume of gas:
(1.8-3.7)×109 m3
0.065-0.13 tcf
Major uncertainty:
Gas hydrate distribution M i
l k o v a n d S a s s e n , 2
0 0 3 ( b a s e d o n R e i l l y
e t a l . ( 1 9 9 6 ) )
Garden Banks (GB) 388
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Water depth: 650-750 m
Area: 3,200,000 m2
GHSZ:
Thickness – 130-495 m
Volume – (0.4-1.6)×109 m3
GH concentration: 5-10%
GH composition: ??-99.5% C1
Volume of gas:
(3.1-23.7)×109 m3
0.11-0.84 tcf
Major uncertainty: GHSZ
Gas composition?
Effect of migrating brines? M
i l k o v a n d S a s s e n ,
2 0 0 3 ( b a s e d o n R e i l l y e t a l . ( 1 9 9 6 ) )
Mississippi Canyon (MC) 798/8420
) )
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M i l k o v a n d S a s s e n ,
2 0 0 3 ( b a s e d
o n N e u r a u t e r a n d B r y a n t ( 1 9 9 0
Water depth: 807-820 mArea:
Mound – 55,600 m2
Hazy reflections – 217,400 m
2
GHSZ:
Thickness – 575-580 m
Volume – 0.16×10
9
m
3
GH concentration: 1-10%
GH composition: ?? C1
Volume of gas: (0.5-1.4)×109
m3
0.017-0.050 tcf
Major uncertainty:
Gas hydrate distribution