CO2 Sequestration in Hydrates with Associated Methane Gas Production - - PowerPoint PPT Presentation

▶
co2 sequestration in hydrates with
SMART_READER_LITE
LIVE PREVIEW

CO2 Sequestration in Hydrates with Associated Methane Gas Production - - PowerPoint PPT Presentation

Jun 10, 2023 120 likes •1.09k views

Energy for the Future CO2 Sequestration in Hydrates with Associated Methane Gas Production by Prof. Arne Graue Dept. of Physics and Technology University of Bergen, NORWAY Whole Value Chain CCUS Student Week, Oct. 15 th - 19 th , 2018,

slide-1
SLIDE 1

Energy for the Future – CO2 Sequestration in Hydrates with Associated Methane Gas Production

by

  • Prof. Arne Graue
  • Dept. of Physics and Technology

University of Bergen, NORWAY

Whole Value Chain CCUS Student Week, Oct. 15th - 19th, 2018, Golden, CO, USA.

slide-2
SLIDE 2

Normal text - click to edit GAS HYDRATES

  • Solid state of gas and water where the water

molecules form a cavity that encapsulates the guest molecule.

slide-3
SLIDE 3

What is natural gas hydrate?

  • Methane and other

small non-polar (or slightly polar) molecules immersed in water will induce

  • rganisation of the

water structure that maximizes the entropy.

  • Above certain

pressures, and below certain temperatures , this results in a phase transition over to a solid like structure. The glass to the right contains water at 0 C The pipe to the left contains hydrate at 5 C

slide-4
SLIDE 4

Why are hydrates of interest?

  • Initial interest as a curiosity
  • Plugging of production and transportation pipelines

Department of Physics and Technology

slide-5
SLIDE 5

Renewed interest

– Significant amount of energy

  • Permafrost regions
  • Marine environments (high water column)

Hester and Brewer, 2009

Department of Physics and Technology

slide-6
SLIDE 6

University of Bergen - Department of Physics and Technology

6

Hydrate as Energy Resource

Gas Hydrates Resource Pyramid (left). To the right is an example gas resources pyramid for all non-gas-hydrate resources.

Ref.: Fire in the Ice, U.S. Department of Energy • Office of Fossil Energy • National Energy Technology Laboratory

slide-7
SLIDE 7

Modified from "GAS HYDRATES OF NORTHERN ALASKA", January 2005 Evaluation of Alaska North Slope Gas Hydrate Energy Resources: A Cooperative Energy Resource Assessment Project US Bureau of Land Management, US Geological Survey, & State of Alaska Division of Geological and Geophysical Surveys Bob Fisk, USBLM, Anchorage, Alaska, Tim Collett, USGS, Denver, Colorado & Jim Clough, DGGS, Fairbanks, Alaska

Gas Hydrate Production Methods

  • CO2 Flood
slide-8
SLIDE 8

Normal text - click to edit Depressurization: PROS AND CONS

  • Pros

– All of the methane is accessible for production by depressurization; at sufficient low pressures

  • Cons

– Large pressure drop may be needed to initiate hydrate dissociation – Water production may represent an economic challenge and an environmental issue – Hydrate melts; causing possible unstable formation

slide-9
SLIDE 9

Normal text - click to edit

GAS HYDRATE PRODUCTION METHODS

  • Move the gas hydrate outside its

stability region – Depressurization – Thermal stimulation – Hydrate inhibitors

  • CO2 exchange

Hydrate stable region Pressure Temperature Hydrate Reservoir Condition Unstable region

slide-10
SLIDE 10

Normal text - click to edit

  • The amount of energy bound in hydrates may be more than

twice the world’s total energy resources in conventional hydrocarbon reservoirs; i.e. oil-, gas- and coal reserves

  • Simultaneous CO2 Sequestration
  • Win-win situation for gas production
  • Need no hydrate melting or heat stimulation
  • Spontaneous process
  • No associated water production
  • Formation integrity

CO2 Exchange: Project Motivation

slide-11
SLIDE 11

CO2 storage in hydrates with associated methane gas production

Challenge:

Determine exchange mechanisms during potential sequestration of CO2 to produce methane from hydrates

slide-12
SLIDE 12

Three component Phase Field Theory

 

 

                                    

  

  i i ci i i i L S bulk bulk j i i j j i j i

c F c c c M c c c F M T c c c f p T c c c f p wTg f T c c c f c c c c T T r d F              

 

) , , ( 1 ) , , , ( ) ( ) , , , ( )] ( 1 [ ) ( ) , , , , ( 4 2

3 2 1 3 1 3 2 1 3 2 1 3 2 1 3 1 , 2 2 , 2 2

 

Parameters ε and w can be fixed from the interface thickness and interface free energy. ε ij set equal to ε

slide-13
SLIDE 13

CH4 PRODUCTION INDUCED BY CO2 INJECTION

  • Provides thermodynamically more stable gas hydrate than CH4

Husebø, 2008 Experimental Conditions

Department of Physics and Technology

slide-14
SLIDE 14

Normal text - click to edit

Experimental Setup

CO2 & CH4 Pumps Temperature & Confining Pressure Controls High Pressure Cell Inside Bore of Magnet Insulated Lines & Heat Exchanger

slide-15
SLIDE 15

Normal text - click to edit Experimental Setup

Ou t In

P

Ou t In

CH4 CO2 Cooling Bath Insulated Lines Confining Pressure Pump Reciprocatin g Pump Pore Pressure Pumps High Pressure Cell Core Plug Confining Pressure Pore Pressure

slide-16
SLIDE 16

Normal text - click to edit Experimental Setup

Ou t In

P

Ou t In

CH4 CO2 Cooling Bath Insulated Lines Confining Pressure Pump Reciprocatin g Pump Pore Pressure Pumps MRI High Pressure Cell Core Plug Confining Pressure Pore Pressure MRI Magnet

Monitor P-V-T and MRI Intensity During Hydrate Formation

slide-17
SLIDE 17

Normal text - click to edit Volumetrics and MRI Results

MRI Intensity in Core and CH4 Volume Consumption

0.2 0.4 0.6 0.8 1 20 40 60 80 100 120 140 160 Time [hours] MRI Intensity (Inverted and normalized) Methane Consumption (normalized)

slide-18
SLIDE 18

CONDITIONS OF A HYDRATE RESERVOIR

  • Hydrate reservoirs are often found in porous media

– Sedimentary rock

Mineralogy: mainly quartz Porosity: 22-23% Permeability: 1.1 D Pore diameter: 125 microns Department of Physics and Technology

slide-19
SLIDE 19

Normal text - click to edit

Conditions for Methane Hydrate Formation/Dissociation

slide-20
SLIDE 20

Normal text - click to edit

Core Sample Design

Bentheim Sandstone

20-25% porosity, ~1.1 D Perm

  • Whole Core
  • Longitudinal Cut With

Machined Spacer to Simulate Open Fracture.

1 cm

slide-21
SLIDE 21

Sample – BH-01

Sample halves saturated With methane and water Middle space saturated With methane

slide-22
SLIDE 22

Sample – BH-01

Run – 17-39 Time – 0min Started cooling sample To 4

0 C

slide-23
SLIDE 23

Sample – BH-01

Run – 18-01 Time – 55min

slide-24
SLIDE 24

Sample – BH-01

Run – 18-03 Time – 2hr 45min

slide-25
SLIDE 25

Sample – BH-01

Run – 18-05 Time – 4hr 35min

slide-26
SLIDE 26

Sample – BH-01

Run – 18-06 Time – 5hr 30min

slide-27
SLIDE 27

Sample – BH-01

Run – 18-07 Time – 6hr 25min Methane Hydrate forming

slide-28
SLIDE 28

Sample – BH-01

Run – 18-08 Time – 7hr 20min Methane Hydrate forming

slide-29
SLIDE 29

Sample – BH-01

Run – 18-09 Time – 8hr 15min Methane Hydrate forming

slide-30
SLIDE 30

Sample – BH-01

Run – 18-10 Time – 9hr 10min Methane Hydrate forming

slide-31
SLIDE 31

Sample – BH-01

Run – 18-11 Time – 10hr 05min Methane Hydrate forming

slide-32
SLIDE 32

Sample – BH-01

Run – 18-12 Time – 11hr 00min

slide-33
SLIDE 33

Sample – BH-01

Run – 18-14 Time – 12hr 50min Methane in spacer

slide-34
SLIDE 34

Sample – BH-01

Run – 18-16 Time – 14hr 40min Methane in spacer

slide-35
SLIDE 35

Sample – BH-01

Run – 18-17 Time – 15hr 35min Methane in spacer

slide-36
SLIDE 36

Sample – BH-01

Run – 18-19 Time – 17hr 25min

slide-37
SLIDE 37

Sample – BH-01

Run – 18-37 Time – 31hr 05min

slide-38
SLIDE 38

Sample – BH-01

Run – 18-42 Time – 36hr 20min

slide-39
SLIDE 39

Sample – BH-01

Run – 18-43 Time – 37hr 15min

slide-40
SLIDE 40

Sample – BH-01

Run – 18-43 Time – 37hr 15min

slide-41
SLIDE 41

Sample – BH-01

Run – 18-57 Time – 54hr 10min

slide-42
SLIDE 42

Run – 18-59

Sample – BH-01

Time – 56hr 00min

slide-43
SLIDE 43

Progress of Hydrate Front

  • Longitudinal Profile

in Core – 5 mm from Fracture.

  • Approximately 35

Hours, ~ Equal Time Increments.

  • Hydrate Growth

Slows with Time.

0.1 0.2 0.3 0.4 0.5

  • 2

2 4 6 8 10 Distance along plug (cm) MRI Intensity

Time

Water-Filled Pores

slide-44
SLIDE 44

Normal text - click to edit

33-03 0.0 hrs Methane in Spacer

slide-45
SLIDE 45

Normal text - click to edit

33-07 0.0 hrs Sw=0.5 + Methane

5 10 15 20 25 30 5 10 15 20 25 30 Time (hrs) Volume (cm3) 0.01 0.02 0.03 0.04 0.05 0.06 0.07

slide-46
SLIDE 46

Normal text - click to edit

33a-01 5.0 hrs Cooling Starts

5 10 15 20 25 30 5 10 15 20 25 30 Time (hrs) Volume (cm3) 0.01 0.02 0.03 0.04 0.05 0.06 0.07

slide-47
SLIDE 47

Normal text - click to edit

33c-01 7.2 hrs

5 10 15 20 25 30 5 10 15 20 25 30 Time (hrs) Volume (cm3) 0.01 0.02 0.03 0.04 0.05 0.06 0.07

slide-48
SLIDE 48

Normal text - click to edit

33c-02 9.4 hrs

5 10 15 20 25 30 5 10 15 20 25 30 Time (hrs) Volume (cm3) 0.01 0.02 0.03 0.04 0.05 0.06 0.07

slide-49
SLIDE 49

Normal text - click to edit

33c-03 12.0 hrs

5 10 15 20 25 30 5 10 15 20 25 30 Time (hrs) Volume (cm3) 0.01 0.02 0.03 0.04 0.05 0.06 0.07

slide-50
SLIDE 50

Normal text - click to edit

33c-04 14.0 hrs

5 10 15 20 25 30 5 10 15 20 25 30 Time (hrs) Volume (cm3) 0.01 0.02 0.03 0.04 0.05 0.06 0.07

slide-51
SLIDE 51

Normal text - click to edit

33c-05 16.3 hrs

5 10 15 20 25 30 5 10 15 20 25 30 Time (hrs) Volume (cm3) 0.01 0.02 0.03 0.04 0.05 0.06 0.07

slide-52
SLIDE 52

Normal text - click to edit

33c-06 18.6 hrs

5 10 15 20 25 30 5 10 15 20 25 30 Time (hrs) Volume (cm3) 0.01 0.02 0.03 0.04 0.05 0.06 0.07

slide-53
SLIDE 53

Normal text - click to edit

33c-07 20.9 hrs

5 10 15 20 25 30 5 10 15 20 25 30 Time (hrs) Volume (cm3) 0.01 0.02 0.03 0.04 0.05 0.06 0.07

slide-54
SLIDE 54

Normal text - click to edit

33c-08 23.2 hrs

5 10 15 20 25 30 5 10 15 20 25 30 Time (hrs) Volume (cm3) 0.01 0.02 0.03 0.04 0.05 0.06 0.07

slide-55
SLIDE 55

Normal text - click to edit

33c-09 25.5 hrs

5 10 15 20 25 30 5 10 15 20 25 30 Time (hrs) Volume (cm3) 0.01 0.02 0.03 0.04 0.05 0.06 0.07

slide-56
SLIDE 56

Normal text - click to edit

33c-10 27.7 hrs

5 10 15 20 25 30 5 10 15 20 25 30 Time (hrs) Volume (cm3) 0.01 0.02 0.03 0.04 0.05 0.06 0.07

slide-57
SLIDE 57

Normal text - click to edit

33c-11 30.0 hrs

5 10 15 20 25 30 5 10 15 20 25 30 Time (hrs) Volume (cm3) 0.01 0.02 0.03 0.04 0.05 0.06 0.07

Core Halves Saturated with hydrate

slide-58
SLIDE 58

Normal text - click to edit

0.0 hrs

0.004 0.008 0.012 0.016 100 200 300 400 500 600 Time (Hours) Intensity

slide-59
SLIDE 59

Normal text - click to edit

34a-01 9.1 hrs

0.004 0.008 0.012 0.016 100 200 300 400 500 600 Time (Hours) Intensity

slide-60
SLIDE 60

Normal text - click to edit

34b-01 20.6 hrs

0.004 0.008 0.012 0.016 100 200 300 400 500 600 Time (Hours) Intensity

slide-61
SLIDE 61

Normal text - click to edit

34b-02 32.0 hrs

0.004 0.008 0.012 0.016 100 200 300 400 500 600 Time (Hours) Intensity

slide-62
SLIDE 62

Normal text - click to edit

34b-03 43.4 hrs

0.004 0.008 0.012 0.016 100 200 300 400 500 600 Time (Hours) Intensity

slide-63
SLIDE 63

Normal text - click to edit

34b-04 54.9 hrs

0.004 0.008 0.012 0.016 100 200 300 400 500 600 Time (Hours) Intensity

slide-64
SLIDE 64

Normal text - click to edit

34b-05 66.3 hrs

0.004 0.008 0.012 0.016 100 200 300 400 500 600 Time (Hours) Intensity

slide-65
SLIDE 65

Normal text - click to edit

34b-06 77.8 hrs

0.004 0.008 0.012 0.016 100 200 300 400 500 600 Time (Hours) Intensity

slide-66
SLIDE 66

Normal text - click to edit

34b-07 89.2 hrs

0.004 0.008 0.012 0.016 100 200 300 400 500 600 Time (Hours) Intensity

slide-67
SLIDE 67

Normal text - click to edit

34b-08 100.6 hrs

0.004 0.008 0.012 0.016 100 200 300 400 500 600 Time (Hours) Intensity

slide-68
SLIDE 68

Normal text - click to edit

34b-09 112.1 hrs

0.004 0.008 0.012 0.016 100 200 300 400 500 600 Time (Hours) Intensity

slide-69
SLIDE 69

Normal text - click to edit

34b-10 123.5 hrs

0.004 0.008 0.012 0.016 100 200 300 400 500 600 Time (Hours) Intensity

slide-70
SLIDE 70

Normal text - click to edit

34b-11 135.0 hrs

0.004 0.008 0.012 0.016 100 200 300 400 500 600 Time (Hours) Intensity

slide-71
SLIDE 71

Normal text - click to edit

34b-12 146.4 hrs

0.004 0.008 0.012 0.016 100 200 300 400 500 600 Time (Hours) Intensity

slide-72
SLIDE 72

Normal text - click to edit

34b-13 157.8 hrs

0.004 0.008 0.012 0.016 100 200 300 400 500 600 Time (Hours) Intensity

slide-73
SLIDE 73

Normal text - click to edit

34b-14 169.3 hrs

0.004 0.008 0.012 0.016 100 200 300 400 500 600 Time (Hours) Intensity

slide-74
SLIDE 74

Normal text - click to edit

34b-15 180.7 hrs

0.004 0.008 0.012 0.016 100 200 300 400 500 600 Time (Hours) Intensity

slide-75
SLIDE 75

Normal text - click to edit

34b-20 237.9 hrs

0.004 0.008 0.012 0.016 100 200 300 400 500 600 Time (Hours) Intensity

slide-76
SLIDE 76

Normal text - click to edit

34b-25 295.1 hrs

0.004 0.008 0.012 0.016 100 200 300 400 500 600 Time (Hours) Intensity

slide-77
SLIDE 77

Normal text - click to edit

34b-30 352.3 hrs

0.004 0.008 0.012 0.016 100 200 300 400 500 600 Time (Hours) Intensity

slide-78
SLIDE 78

Normal text - click to edit

34b-35 409.5 hrs

0.004 0.008 0.012 0.016 100 200 300 400 500 600 Time (Hours) Intensity

slide-79
SLIDE 79

Normal text - click to edit

34b-40 501.0 hrs

0.004 0.008 0.012 0.016 100 200 300 400 500 600 Time (Hours) Intensity

slide-80
SLIDE 80

Normal text - click to edit

34b-45 523.8 hrs

0.004 0.008 0.012 0.016 100 200 300 400 500 600 Time (Hours) Intensity

slide-81
SLIDE 81

Normal text - click to edit

34b-52 603.9 hrs

0.004 0.008 0.012 0.016 100 200 300 400 500 600 Time (Hours) Intensity

slide-82
SLIDE 82

Scientific Conclusions

  • MRI Provides Unique Dynamic Data of Hydrate

Formation and Production Consistent with Conventional Results.

  • CO2 Exchange for CH4 in Hydrates Is Rapid and

Efficient.

  • No Free Water Observed During Exchange

Process.

  • Sufficient Permeability Remains During Hydrate

Formation and Subsequent Production.

slide-83
SLIDE 83

CO2 Storage in Hydrate Reservoirs with Associated Spontaneous Natural Gas Production

In-Situ imaging (MRI) of hydrate formation Methane production by CO2 injection in field test in Alaska 2012

Objectives: Experimentally and theorethically determine spontaneous methane production when hydrate is exposed to CO2; with the purpose of CO2 sequestration.

Methane hydrate reservoirs Arne Graue and Bjørn Kvamme, Dept. of Physics, University of Bergen, NORWAY Funding: ConocoPhillips, Statoil and The Research Council of Norway

slide-84
SLIDE 84

Normal text - click to edit

  • ConocoPhillips, USDOE and JOGMEC
  • US$ 11.6 mill funding from US DOE, total cost ca. US$30mill
  • CO2 injection

Alaska Field Injection Test 2011-2012

slide-85
SLIDE 85

Normal text - click to edit

Summary of Field Test (Injection Test)

Schedule:

  • Apr. 2011:

Drilling test well (Complete)

  • Nov. 2011:

Finalizing parameters for the field test Jan.-Apr. 2012: Field test Location： Prudhoe Bay operating unit in Alaska, USA Operator： ConocoPhillips Company (COP), through its wholly owned subsidiary, ConocoPhillips Alaska, Inc. Investors： The United States Department of Energy（DOE） JOGMEC; Japan Oil, Gas and Metals National Corp.

slide-86
SLIDE 86
slide-87
SLIDE 87
slide-88
SLIDE 88

Students and Staff :

slide-89
SLIDE 89
slide-90
SLIDE 90

Normal text - click to edit

slide-91
SLIDE 91
slide-92
SLIDE 92

Iġnik Sikumi #1 Flowback/Drawdown: Gas composition

Gas Production from the Field Test

slide-93
SLIDE 93

Conclusions on Industry Collaboration

  • Mutually beneficial
  • Students exposed to experienced senior

petroleum experts

  • Access to advanced and expensive

equipment

  • Leveraged research
  • Provides qualified candidates for Norway and

the oil industry

  • Recruitment of national students
slide-94
SLIDE 94

Energy for the Future Gas Production WITH CO2 Storage in Hydrates

Department of Physics and Technology

“While this is just the beginning, this research could potentially

yield significant new supplies of natural gas.”

U.S. Energy Secretary Steven Chu, May 2nd 2012

Methane hydrates are ice-like structures with natural gas trapped inside, and are found both onshore and offshore along nearly every continental shelf in the world.

What are Methane Hydrates? Energy bound in hydrates is more than combined energy in conventional oil, gas and coal reserves

DOE, ConocoPhillips and JOGMEC at the Iġnik Sikumi test site, Alaska

Excerpt from U.S. Energy Secretary Steven Chu’s statement

…to conduct a test of natural gas extraction from methane hydrate using a unique

production technology, developed through laboratory collaboration between the University of Bergen, Norway… [D]emonstrated that this mixture

could promote the production of natural gas. Ongoing analyses of the extensive datasets acquired at the field site will be needed to determine the efficiency of simultaneous CO2 storage in the reservoirs.

UiB Laboratory Verification of Technology Field Verification of UiB Technology

< 10 year US $30 mill

slide-95
SLIDE 95

Summary

Department of Physics and Technology

Use of CO2 as a commodity: Business Case for CO2 Storage:

  • CO2 EOR
  • Integrated EOR (IEOR) with Foam: Carbon Negative Oil Production
  • Exploitation of Hydrate Energy: Carbon Neutral Gas Production

New technologies ready for industrial scale implementation:

  • Onshore in Permian Basin, USA (80% CO2EOR, EOR target 137Bbbl)
  • Offshore Opportunities: NCS, Middle East, Asia, Africa and Brazil
  • International Whole Value Chain CCUS Collaboration Offshore

Way Forward

slide-96
SLIDE 96

Thank you!