POTENTIAL for COALBED METHANE (CBM) and ENHANCED …€¦ · • Enhanced coal bed methane recovery is a method of producing additional coalbed methane from a source rock (coal bed),

POTENTIAL for COALBED METHANE (CBM) and ENHANCED COALBED METHANE

RECOVERY (ECBM) in INDIANA

Maria Mastalerz , Indiana Geological Survey,

Indiana University , Bloomington

CBM is unconventional gas

U.S. Unconventional Natural Gas Production 1990-2030 (trillion cubic feet)

0

1

2

3

4

5

6

7

1990 1995 2000 2005 2010 2015 2020 2025 2030

Tight Sands

Coalbed Methane

Gas Shales

History Projections

Annual Energy Outlook 2007

CBM in USA

Source, EIA, 2009

0

500

1000

1500

2000

2500

1989 1990 1991 1992 1993 1994 1995 1996 1997 1998 1999 2000 2001 2002 2003 2004 2005 2006 2007 2008 2009

Billio

n c

ub

ic f

eet

(Bcf)

Year

Illinois Basin among the CBM basins in US

0.6 trillion m3

21 trillion m3

Illinois Basin – shallow low maturity (high volatile bituminous) coals

~21 TCF of CBM

Coal in Indiana

producing area

1.5 Tcf – Seelyville alone, ~5 Tcf - total

Mo

re m

icro

bia

l C

H4

Distribution of coal gas compositional and isotopic fingerprints

~ 3 cm3/g (100 scf/ton), ~ 99% of microbial origin Strąpoć et al., 2008, IJCG

-90 to -45 - biogenic

-30 to -50 - thermogenic <20 - thermogenic

Geochemical and isotopic signatures of coal gas: CH4 generated microbially via CO2-reduction

Strąpoć et al., 2007, OG

Basin history and multi-parameter model for microbial methanogenesis

60 C

MESO- ZOIC

Microbial

Early T-genic gas

Temperature o.k.

Slow colonization and onset of methanogenesis

Brine dilution

Meteoric water access

Microbial colonization and onset of methanogenesis

• Inter and post glacial colonization and onset of CH4-generation in the Illinois Basin (similarly to the New Albany Shale and Antrim Shale in Michigan Basin (McIntosh, 2003)

• Initiated by brine dilution with ice sheet melt-waters

• Similar activation of methanogenesis in coal beds observed in other basins: Black Warrior, San Juan, Alberta

Epifluorescence of F420 coenzyme

Microscopic features of methanogenic enrichments of the CBM co-produced water suggest presence

of methanogenic Archaea

Very small cell size typical of Archaea

1 μm x400

Renewable resource??

16S rRNA study of coal water and methanogenic enrichment: dominant methanogen - CO2/H2 utilizing Methanocorpusculum

SEM image of the CO2-reduction methanogenic enrichment

(Methanocorpusculum)

Strąpoć et al., 2008, AEM

Cell membrane intact polar lipids (IPLs)

n-C15

n-C16

n-C17

n-C18 n-C19

n-C20

me-C23

me-C24

me-C25

me-C26

me-C27

hopane

norhopane

pristane

phytane

biphytane

monomethylalkanes:

found in modern and

paleo microbial mats

signatures (Kenig, 2000)

alkyl cyclohexanes:

coal wax (Dong et al.,

1993) and in microbes

n-alkanes, coal bitumen:

trace amounts (similar

to biomarkers e.g. hopanes),

only C15 – C25 present

isoprenoids: hard to biodegrade, Pri and Phy ~ ½ of C17 and C18 ?

hopanes (biomarkers,

hard to biodegrade)

C17

C16

C15

How much coalbed gas do we have?

• CBM in the Illinois Basin:

- 21 Tcf (GRI)

- 7.8 Tcf (DOE) – recoverable

• CBM in Indiana

- 1.1 Tcf - Seelyville Coal in Indiana

(Drobniak et al., 2004)

- 5 Tcf in Indiana?

17.5 billion tons available 39.2 billion tons restricted

How much gas do we produce?

• Enhanced coal bed methane recovery is a method of producing additional coalbed methane from a source rock (coal bed), similar to enhanced oil recovery applied to oil fields;

• If the gas is injected into a coal bed, then methane could be

liberated and extracted. Typical injection gases include nitrogen and carbon dioxide;

• Growing interest in carbon sequestration brought considerable

interest into integrated ECBM recovery/carbon sequestration projects.

Enhanced Coal Bed Methane Recovery (ECBM)

Power generation, CO2 sequestration & ECBM

Power plant

CO2

CH4

CH4

CH4

Coal-burning electric power plants

71.62%

Major coal-burning industrial and

institutional plants 2.66%

Natural-gas industrial generators

24.29%

Oil-burning industries 1.19%

Wood-burning industries

0.24%

Emission sources (2009 data) CO2 emissions

(metric tons/year) Coal-burning electric power plants 117,736,810

Major coal-burning industrial and institutional plants 4,378,999

Natural gas-burning industrial generators 39,925,000

Oil-burning industries 1,954,741

Wood-burning industries 399,672

TOTAL emissions from point sources 164,395,222

CO2 emissions from stationary sources in Indiana

Total Indiana CO2 emissions: 250 mln tons a year

Gas storage in coal

• Dual-porosity system: matrix and cleats

• Gas stored by adsorption on coal surfaces within the matrix

• 1 lb of coal (15 in3) contains 100,000 – 1,000,000 ft2 of surface area

• Gas production by desorption, diffusion and Darcy flow

Matrix: Gas Desorption, Diffusion, Darcy-flow

Fracture: Darcy-Flow

Gas Transport Mechanisms

Microporosity Mesoporosity Macroporosity (fracture flow) (matrix flow)

CH4 adsorption: corresponding CH4 adsorption capacities range from approximately

1.6 to 6.3 m3/t (50 to 200 scf/ton).

Adsorption capacities of Indiana coals

CO2 adsorption: for reservoir conditions, the range of CO2 adsorption capacities (daf

basis) ranges from close to 6.2 m3/t (200 scf/ton) for the lowest pressure to almost

22.0m3/t (700 scf/ton) for the highest pressures.

Adsorption capacities of Indiana coals

The ratio of CO2 to CH4 adsorption capacities varies with pressure. At 2.07MPa (300

psi), the CO2/CH4 ratio ranges from 3.7 to 5.7 for the coals studied.

Objective: to assess the potential of

deep, uneconomic coalbeds located

within the Illinois Basin to (1) sequester

CO2 and (2) produce methane from the

coals as a by-product of the

sequestration process (enhanced

coalbed methane [ECBM] recovery).

Methods:

- We reviewed physical and chemical attributes of the coals that are important in assessing their ability to adsorb and retain CO2. - The depth and thickness of the coalbeds, as well as selected coal quality parameters (e.g., ash, moisture), were analyzed and interpreted in terms of the availability of the coal for CO2 storage. - The criteria for minability were reviewed and applied to the set of seven major coalbeds in the Illinois Basin.

- Coals were also assessed relative to their adsorption capacities and their response to CO2 flooding experiments. - Storage capacities were modeled. - Final estimates of ECBM and CO2 storage volumes were made using GIS-generated map layers.

CO2 sequestration screening criteria for designating areas not desirable for mining (unminable) 1) 91-152 m (300-500 ft) deep: No CO2 sequestration, coalbed methane (CBM) target only.

2) 152-305 m (500-1,000 ft) deep: Sequestration or ECBM target in coals between 0.46 and 1.1 m (1.5 and 3.5 ft) thick. Coals greater than 1.1 m (3.5 ft) thick are considered minable. 3) Greater than 305 m (1,000 ft) deep: Sequestration target in coals greater than 0.46 m (1.5 ft) thick (all coals assumed to be unminable at this depth). While establishing these criteria for CO2 sequestration and ECBM production potential, these assumptions, among others, were considered: 1) the minimum thickness for identifying, perforating, and producing CH4 from a coal seam is 0.46 m (1.5 ft), regardless of depth, and 2) the current minimum minable thickness by underground coal equipment is 1.1 m (3.5 ft).

The depth and thickness of coal beds were the basis for the calculating CO2

volumes that could be potentially injected.

Thickness and depth maps were used to separate minable from unminable (potentially suitable for CO2 sequestration) areas within each coal bed.

The depth and thickness of coalbeds were the basis for calculating CO2 volumes that could be potentially injected.

1) 91-152 m (300-500 ft) deep:

No CO2 sequestration, coalbed methane

(CBM) target only.

2) 152-305 m (500-1,000 ft) deep:

Sequestration or ECBM target in coals

between 0.46 and 1.1 m (1.5 and 3.5 ft)

thick. Coals greater than 1.1 m (3.5 ft) thick

are considered minable.

3) Greater than 305 m (1,000 ft) deep:

Sequestration target in coals greater than

0.46 m (1.5 ft) thick (all coals assumed to

be unminable at this depth).

The remaining coal resource in the Illinois Basin: 413 billion tonnes (455 billion tons). 142 billion tonnes (157 billion tons) (or 34.5%) meets the “minable” criteria of being less than 305 m (1000 ft) deep and greater than 1.1 m (3.5 ft) thick. 271 billion tonnes (298 billion tons) are potentially available as a CO2

sequestration reservoirs.

CO2 storage from 1.6 to 4.6 billion t (1.8 to 5.1 billion tons) in Illinois Basin coals

- 164 mln tons a year from stationary sources in Indiana - Gibson Station emits ~ 22 mln CO2 a year (3100 MW capacity) – 660 mln for 30 years - Edwardsport Gasification – 4.5 mln a year (630 MW capacity) – 150 mln for 30 years

90 mln tons of CO2 storage in Indiana (~3%)

COMET 2 software

70-280 billion m3 (2.4-9.8 tcf) of CH4 is potentially recoverable as a result of CO2 ECBM practices

in the Illinois Basin Total recoverable ECBM and CO2 storage per acre of the coal increases towards the deeper areas of the basin, where there are more coal seams and the total coal thickness is largest

~0.15 tcf of CH4 in Indiana

Illinois Basin coal beds have reservoir temperatures ranging from less than 12ºC (55ºF) to a little more than 26ºC (80ºF) in isolated areas in Illinois, where geothermal anomalies are present with temperature gradients up to 2.4 ºF/100 ft. This temperature range indicates a gaseous phase of CO2 upon injection into reservoir conditions.

A hydrostatic pressure map, generated from the depth of the Springfield Coal, assuming totally saturated conditions with freshwater hydrostatic gradient of 0.43, shows that the pressure ranges from less than 689 kPa (100 psi) close to the margin of the Basin to more than 3,792 kPa (550 psi) in tectonically engaged areas in western Kentucky. Such a pressure range is far below the critical point, placing the coals studied in the gas state with regard to phase characteristics of CO2.

Oil and Gas Field Distribution In Indiana

Oil Production

Gas Production

A'ANW SE

LIMA-INDIANA TREND

GR

Nipsco #3 Berger

P # 24272

Sec. 18-34N-3E

Marshall County, Indiana

N

IGS # SDH-323 Williams

P # 116607

Sec. 20-25N-12E

Wells County, Indiana

GR N

(Trempealeau)

Premier Oil #1 Breymier

P # 65

Sec. 5, Jackson Twp.

Drake County, Ohio

GR FDC

800

900

1000

1100

1200

800

900

1000

1100

1200

1300

1400

1500

1200

1300

1400

1500

1600

1700

1800

Structural Cross Section - Indiana/OhioDatum: Sea Level

00

300 feet

15 miles

marker

Royal

Center

Fault

Keith and Wickstrom (1992)

50 Miles

30 Km

0

0

UPPER ORDOVICIAN PRODUCTION

Oil Gas

MICHIGAN

INDIANAOHIO

Bowling

Green

Fault

Zone

D U

TRENTON STRUCTURE

B'

B

A'

A

Keith (1986, 1989)

Trenton Field Summary

• 1890: production began

• 1915: production essentially over

• Cumulative oil > 105 MMBO million barrels of oil

• Cumulative gas > 980 BCFG billion cubic feet of gas

• Covers 17% of Indiana land (43,000 mi2)

• 36,259 wells by end of 1916 (Barrett, 1907)

• 24,103 wells accounted for in PDMS

• Depth of Trenton/Black River pay: 800-1,300 ft

Trenton Field Reservoir Characteristics

• Reservoir pressure compromised, highly depleted Porosity generally in upper 100 ft of Trenton

• Reservoir Rock: Dolostone

• Typical porosity range: 0.3-10%, < 1% common

• Typical permeability range: 0.3-100 md, < 10 md common

• Both porosity and permeability are highly variable

• Recoverable hydrocarbons left in place: ??

Enhanced Oil Recovery Perspective

Depths 800 – 1300 feet Pressures 384 – 559 psi Temperature No organic matter to adsorb gas Variable permeability and porosity Unknown recoverable hydrocarbon resources Past completion practices Potential for enhanced oil recovery????

Field scale CO2 injection

- Tanquary Site

Injection

well (I-1B)

Monitoring

well (M-3)

Monitoring

well (M-2A) Monitoring

well (M-1)

Ground water

Monitoring well

Ground water

Monitoring well

Ground water

Monitoring well

Ground water

Monitoring well CO2

storage tank

booster pump

tool trailer

portable

generator

office trailer

pump skid heater

engineer

Butt

cleat

Face cleat

148’-5

”

98’-5

”

104’-11”

52’-4”

Tanquary FieldECBM Site Plan and Equipment LayoutUpdated 07.22.2008

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