unconventional (coal/organic shale) reservoir small … · virginia tech virginia coal and energy...

Unconventional (Coal/Organic Shale)

Reservoir Small-Scale CO2 Injection Tests in

the Central Appalachian Basin

Nino Ripepi

Department of Mining & Minerals Engineering

Virginia Center for Coal & Energy Research

Virginia Tech

Virginia Coal and Energy Alliance Annual Meeting

Kingsport, TN

May 19, 2015

Project Overview: Goals and Objectives

Objectives:

Inject up to 20,000 metric tons of CO2 into 3 vertical CBM

wells over a one-year period in Central Appalachia

Perform a small (approximately 400-500 metric tons) Huff

and Puff test in a horizontal shale gas well

Duration: 4 years, October 1, 2011–September 30, 2016

Funding: U.S. DOE / NETL: $11,499,265

Non-DOE: $2,874,825 / Total Project Value: $14,374,090

Goals

Test the storage potential of unmineable coal seams and

shale reservoirs

Learn about adsorption and swelling behaviors of coal and

shale (methane vs. CO2)

Test the potential for enhanced coalbed methane (ECBM)

and enhanced gas (EGR) production and recovery

3

Research Partners

• Virginia Center for Coal and Energy Research (Virginia Tech)1,2,3,4,5

• Cardno2,3

• Gerald Hill, Ph.D.1,4

• Southern States Energy Board1,5

• Virginia Dept. of Mines, Minerals and Energy3

• Geological Survey of Alabama3

• Sandia Technologies3

• Det Norske Veritas (DNV)4

• Consol Energy (Research Group)2,3

Industrial Partners

• Consol Energy (CNX Gas)

• Harrison-Wyatt, LLC

• Emory River, LLC

• Dominion Energy

• Alpha Natural Resources

• Flo-CO2

Collaborators• Schlumberger

• Global Geophysical Services

• Oak Ridge National Laboratory

• University of Tennessee

• University of Virginia

• Southern Illinois University

• Oklahoma State University

1 Project management2 Operations3 Research4 Risk management5 Outreach

– Selected Three Wells for

Injection: September, 2012

– Access Agreements: Jan.

2013

– Class II UIC Permit: Dec.

2013

– Drilling Permits Received

– Corehole: July 2014

– Monitoring Wells: March 2015

– Converted Injection Wells:

April 2015

– CO2 Injection: May/June 2015

– Post-Injection Monitoring:

June 2016

Small Scale Injection of CO2 in Buchanan County, VA (20,000 tons)

Boissevain

7 R

IGH

T

10

/31/9

9

11

/16/9

9

2/2

9/0

0

3/1

3/0

07

/8/0

0

6/3

0/0

0

11

/17/0

0

10

/31/0

0

4224

'42

37'

4475

'44

75'

3491

'34

95'

2904

'28

97'

SECARB PilotInjection Well

RU-84

Honaker

Raven

Vansant

CBM Injection Candidates

CNX GAS CBM WELL

EQT CBM WELL

RANGE RESOURCES CBM WELL

POCAHONTAS NO. 3 DEEP MINE

SURFACE FAULTS

QUADRANGLE BOUNDARIES

TOWNS

0 5,000 10,000

SCALE IN FEET

DICKENSON CO.

RUSSELL CO.

BUCHANANCO.

Buffalo M

ountain Fault

Keen M

tn F

ault

UD

Russell Fork Fault

Little

Paw

Paw

Fault

Fault

TestSite

– Selected Three Wells for

Injection: September, 2012

– Access Agreements: Jan.

2013

– Class II UIC Permit: Dec.

2013

– Drilling Permits Received

– Corehole: July 2014

– Monitoring Wells: March 2015

– Converted Injection Wells:

April 2015

– CO2 Injection: May/June 2015

– Post-Injection Monitoring:

June 2016

Small Scale Injection of CO2 in Buchanan County, VA (20,000 tons)

1,000 Ton ECBM Huff-n-Puff in VA25% CO2 produced in 5 years

Shut-in Period with CO2 Injection

mid November ‘08 – mid May ‘09

Pre CO2 Injection EUR = 319 MMcf

Post CO2 Injection EUR = 471 MMcf

Gas P

rod

ucti

on

, M

cf/

mo

nth

7

CBM CO2 Injection Test in Buchanan County, VirginiaMonitoring, Verification, and Accounting (MVA)

Oakwood Field Demonstration Site

MVA Focus Area

• Injection wells

• CBM production wells

• MVA boundaries

• Roads

• Monitoring and

characterization wells

• Microseismic array (28 stns)

• GPS array (20 monuments)

DD-7 DD-8

DD-7A

½-mile

boundary¼-mile

boundary

8



MVA Focus Area

• Injection wells


• MVA boundaries

• Roads

• Monitoring and




DD-7 DD-8

DD-7A

M1

M2

C1

9



MVA Focus Area

• Injection wells


• MVA boundaries

• Roads

• Monitoring and




DD-7 DD-8

DD-7A

10



MVA Focus Area

• Injection wells


• MVA boundaries

• Roads

• Monitoring and




DD-7 DD-8

DD-7A

GC 74.02 204.3 36.23

LS 20 47.7 409.12 11.66

UH 10 40.21 350.93 11.46

Poc 11 69.5 323.41 21.49

Poc 10 73.28 464.73 15.77

Poc 9 30.89 207.67 14.87

Poc 7 48.15 340.54 14.14

Poc 5-10 41.05 385.25 10.66

Poc 5-20 47.95 379.22 12.64

Poc 4 33.21 216.34 24.77

Poc 3-10 33.69 108.12 31.16

Poc 3-20 37.91 106.57 35.57

Poc 2 52.88 217.76 24.28

average: 20.36

Carb. shale 56.74 75.88 74.78

Percent residual

gas (%)

Total gas

(scf/t)Coal name

Residual gas

(scf/t)

CBM Test: Laboratory Results

Gas Content for Coal and Shale in Buchanan CountyFrom Characterization well, C-1

X-ray CT scan of

Buchanan County

coal where blue

indicates porosity

(cleats)

CBM Test: Laboratory Results

X-ray CT scan of

Buchanan County

coal where red

indicates filled cleats

13

Shale CO2 Injection Test (510 tons)

Morgan County, Tennessee

• Horizontal well in Chattanooga Shale

formation, drilled in 2009

• Legacy producing gas well permitted under

TDEC

• 510 tons for “huff and puff” injection test

• Injection period: March 18-31, 2014 (14 days)

• Shut-in period: March 31- July 29, 2014

(~4 months)

• Flowback period: July 29, 2014- present

(~9 months)

• Current status: post-injection monitoring

Reservoir

Modeling

15

Shale CO2 Injection Test in Morgan County, TennesseeOperations Overview

Storage

Vessel Injection

Skid

Propane Heater

HW-1003

16

Shale CO2 Injection Test in Morgan County, TennesseeOperations Overview

Storage

Vessel Injection

Skid

Propane Heater

HW-1003

Check valve

Tracer Injection

Tee

Ball valve

Check valve

Gate

valve

CO2

Inlet

17

• Sulfur Hexafluoride (SF6)

– 0.574 kg at 50-ton mark

– Booster Pump and Air Compressor

• Perfluoromethylcyclopentane (PMCP)


– Syringe Pump

• Perfluoromethylcyclohexane (PMCH)


– Syringe Pump

Shale CO2 Injection Test in Morgan County, TennesseeMonitoring, Verification, and Accounting (MVA)

Perfluorocarbon TracersInjected with CO2 stream

18

Shale CO2 Injection Test in Morgan County, TennesseeInjection Summary

• 510 tons CO2 injected

• Avg. Flow Rate: 40 tons/day

(predicted: 50 tons/day)

• Avg. Wellhead Temp: 50º F

• Max Wellhead Pressure: ~500 psi (Gas Phase)

(predicted: ~800 psi) – (Liquid Phase)

FLOWBACK RESULTS

FLOWBACK RESULTS -

TRACERS

Crecovered < Cinjected

FLOWBACK RESULTS

• 35% of CO2 recovered - 0.11 tons/day (> 8 years to recover CO2)

• @ $3.74 per Mcf and $45 per BBL of NGL:

– EGR = $30K or $60 per ton

One Successful and Safe

Injection, One to Go!

Questions?

[email protected]

mailto:[email protected]

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