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Update on Results of SECARB Test of Update on Results of SECARB Test of M it i L V l I j ti tM it i L V l I j ti t C fi ldC fi ldMonitoring Large Volume Injection at Monitoring Large Volume Injection at CranfieldCranfield

Mississippi River

Natchez Mississippi

pp

3,000 m depthGas cap, oil ring, downdip water legSh t i i 1965Shut in since 1965Strong water driveReturned to near initial pressure

Illustration by Tip Meckel

Cranfield “Early” Field Cranfield “Early” Field Test CollaborationTest Collaboration

Gulf Coast Gulf Coast Carbon Center Carbon Center Industrial AssociatesIndustrial Associates

Denbury Onshore LLCDenbury Onshore LLC

LBNLLLBL

USGS Gulf Coast Carbon USGSORNLNETL

Schlumberger

Center StaffSusan HovorkaRamon TrevinoTip MeckelChangbing YangCarbon Services

QEABP

U MississippiMi St t

Changbing YangJiemin LiuKatherine RomanakRebecca SmythSigrid CliftMasoumeh Kordi

Miss StateUTPGEUT DoG

University TennesseeP i t

Stuart ColemanYihua CaiHamid Lashgari

BEG staffPrincetonStanford

University Edinburgh

Tongwei ZhangJeff PaineBob ReedyRobert Reed Kitty Millikan

Overview – Cranfield• 1 million tonne/year rate achieved Dec 20, 2009

• 2 Million tonnes monitored since July 2008

• Rate to be maintained >15 months

• Monitored with standard and novel approaches• Monitored with standard and novel approaches– History match pressure response– Fluid flow measured/monitored – multiple tools / complex flow field

Fi t US f El t i l R i t T h (ERT) f– First US use of Electrical Resistance Tomography (ERT) for sequestration (deepest to-date worldwide)

– Quantification of CO2 dissolution

• Export to commercial EOR/sequestration projects

Cranfield ProgressRepeat geophysical monitoring 10/10

2007

n

2008 2009

Firstcored ell se

line

2006 2010 2011 2012

NE

PA Drill Phase III3 DAS wells

ion sel

ectio

n cored well,brine samples

baseline i i oi

l gas

bas

Pha

se II

I

Phase III injection

Ear

ly

Monitoring

e II

Site

op

men

t

ract

eriz

ati

ase

II Si

te seismic So

Phase II injection

EC

AR

B E

Phas

ede

velo

Cha

r

Pha

Phase II Phase III

End

S

May 1 million tonnes injectedP II + III

1 million tonnesPhase III injection 8/10

December 20, 2009Achieved 1 milliontonnes/year rate

5km

HiVIT

Psite Five Study Areas

Phase II

Psite Five Study Areas

Injector

Producer

DASGMTPipeline head&Separation facility Producer

(monitoring point)Observation Well

p y

GIS base Tip MeckelGIS base Tip Meckel

Reservoir Heterogeneity from Surface 3D SeismicSurface 3D Seismic

• Stratal slicing for facies

90 d h• 90-degree phase

• AVF for thickness/fluid

• AVO for fluid/OWC

ChanChannelnel

ChannelChannelerosionerosion

ChannelChannelerosionerosion

ChannelChannelerosionerosion

erosierosionon

erosionerosion

Point Point barbar

Point barPoint bar

Denbury 3-D survey interpretation Hongliu Zeng, BEG

A BReservoir Characterization

Fm Tuscaloosa confining system

calo

osa

F Tuscaloosa confining system

Phase II

DAS

Tusc

Tuscaloosa D-E reservoir

Oil-water contact Based on:•Well logs and •Side-wall cores

3D Denbury - interpretation Tip Meckel BEG

Upward fining fluvial sandstone and conglomerates of the l T l Flower Tuscaloosa Fm

Confining zone Reservoir

Jiemin Lu BEG

Baseline Cross Well tomogramBaseline Cross Well tomogramF1F2F3

West East

112 m

Z-Seis & Tom Daley Jonathan Franklin in review at LBNL

Probabilistic Realization P biliPermeability

Jong-Won Choi and J.P. Nicot BEG

First Breakthrough (time) Predictions F2 Well (for each of 10 permeability fields)

Breakthrough time at F20.4

Set #1 at Ly14 (12/16/2009)

Set #2 at Ly17(12/20/2009)

Set #3 at Ly17(12/8/2009)

Set #4 at Ly10(12/15/2009)

0.2

0.3

atur

atio

n

y ( )

Set #5 at Ly19(12/29/2009)

Set #6 at Ly10(12/23/2009)

Set #7 at Ly10(12/23/2009)

Set #8 at Ly10(12/7/2009)

0.1

Gas

sa y ( )

Set #9 at Ly7(12/7/2009)

Set #10 at Ly10(12/11/2009)

0

12/1/09

12/3/09

12/5/09

12/7/09

12/9/09

12/11/09

12/13/09

12/15/09

12/17/09

12/19/09

12/21/09

12/23/09

12/25/09

12/27/09

12/29/09

12/31/09

1/2/10

1/4/10

1/6/10

Date

Jong-won Choi and JP Nicot BEG

Start injection at DAS Dec 1, 2009175 kg/min step up to 520 kg/min175 kg/min step up to 520 kg/min

I j t BHP Ob ti

e

bar psi

Injector BHP Observation well BHP

e pr

essu

re 400

otto

m h

ole

340Bo

Dec 1

340

It’s all about pressure

Elapsed time

DAS MonitoringgInjectorCFU 31F1

Obs CFU 31 F2

Obs CFU 31 F3

Above-zonemonitoringF1 F2 F3Closely spaced well

array to examine Above Zone Monitoring

10,500 feet BSL

flow in complex reservoir

Injection Zone

68m

112 mPetrel model Tip Meckel

Phase III Research Ob ti W ll ’ C t ti2 7/8” tubing Observation Wells’ Construction

U-tube sampler1/4 “SS

2 7/8” tubing

Cross well array in two wellsHigh injection volumes

Seismic sources/receivers

High injection volumesFar-field monitoring microseismic, P&T, chemistry, surface seismic

Casing-conveyed pressure sensor

BHP+ T

Fiberglass non-conductive casing

ERT – 14 & 7 electrodes200’

Tuscaloosa DE

100’

Distributed temperatureand heater loop

100

BEG, LBNL, LLNL, USGS, ORNL, Sandia Technologies LLC

Measuring CO2 Distribution in R iReservoir

• Well-based methodsWell based methods– Wireline logs in time lapse – RST (Schlumberger)

Temperature– Temperature

C ll th d• Cross well methods– Time – lapse ERT– Time – lapse acoustic (seismic)

Wireline Formation Evaluation (ELAN – RST) CFU 31 – F3

GRWashouts

ResistivityOHPorosity Sigma

RSTPorosity

CO2 Volume

CO2Saturation

RST RST RSTResistivity Porosity Sigma

Perm

CO2 Volume 12/12/09 12/15/09 12/31/09

Bob Butch

What happened at the wells?

packer

F2

packer

1 F3orm

atio

n packer

D 1

vatio

n w

ell

on W

ell F

1

vatio

n w

ell

ows

into

fo Dec 1pressure changes right away, but no

Obs

erv

Inje

ctio

Obs

erv

c 1

CO

2 fl y,

CO2

Dec

Day 9

packer

F2

packer

1 F3orm

atio

n packer

Dec 9CO2 detected in

vatio

n w

ell

on W

ell F

1

vatio

n w

ell

ows

into

fo 2 top of well interval

Obs

erv

Inje

ctio

Obs

erv

c 1

CO

2 fl

Dec

Day 13

packer

F2

packer

1

orm

atio

n packer

Dec 13 still minor amounts of Dec 13

vatio

n w

ell

on W

ell F

1

F3

ows

into

fo CO2 detected in top of well interval and maybe some thin

ec 3CO2 detected in top of well interval and maybe some thin

Obs

erv

Inje

ctio

tion

wel

l F

c 1

CO

2 fl maybe some thin

zonesmaybe some thinzones

Obs

ervaDec

Day 31

packerpacker

1 n lo

g packer

Dec 30 large amounts of Dec 31 large

on W

ell F

1

ay in

ject

ion

ge fl

ow in

pe

r par

t CO2 detected in well interval and some thick zones in lower part of

ec 3 a geamounts ofCO2 detected in well interval upper part of

Inje

ctio

ma

larg

upp in lower part of

formationupper part of formation

ell F

2

ell F

3

we

we

Cross Well ERT tells us how flow doccurred

sx ec

trode

s

elec

trode

Secondx

x

x

wel

l F3

ele

on w

ell F

2 Resistive plume out of section migration

Direction of CO2 plume x

x serv

atio

n w

Obs

erva

tio

migration

Injectorx 50ft

ObsO

Resistive plume = CO2 in reservoir

Charles Carrigan, LLNL Conductive plume= workover fluids?

Resistive plume = CO2 in reservoir

High frequency fluid sampling via U-tube

100%

via U tubeyields data on flow processes

70%

80%

90%

100%TI

ON

CH4

CO2Breakthrough of of CO2

Additi l fl

Double injection

Originallybrine

30%

40%

50%

60%

CO

NC

ENTR

AT Additional flow

paths – more methane extracted

injection rate

brine methane saturated

0%

10%

20%

11/29/09 0:00 12/4/09 0:00 12/9/09 0:00 12/14/09 0:00 12/19/09 0:00 12/24/09 0:00 12/29/09 0:00 1/3/10 0:00

SAMPLING TIME

Small diameter sampler with N2 drive brings fluids quickly tosurface with tracers intactCO di l i i b i lib di l d CH

BEG, LBNL, USGS, ORNL, UTDoG, data compiled by Changbing Yang BEG

CO2 dissolution into brine liberates dissolved CH4

5km

HiVIT

P Sit

Is it possible to find leakage at

P Site

Phase II

surface? P-Site tests

Injector

Producer

GMTPipeline head&Separation facility

DAS

Producer (monitoring point)Observation Well

p y

road

Assessment of near surface techniques“P Site”

Trans 4

roadS te

Pit1‐BG

1‐00

4‐02

1‐011‐02

Trans 1

AW

PitPadPlantsP&A well

1‐03

1‐041‐05

3‐02

3‐01

4‐011950’ it 2‐01

2‐02

1950’s pit

Trans 2Trans 3

Phase III Current StatusPhase III Current Status• Injection since April, 2009

I j i h h 23 ll l i• Injection through 23 wells cumulative volume of 1,067,339 metric tonnes

• Rates 0.8 to 1 million tonnes/yeary

• Currently Task 11: Repeat Geophysics• Currently Task 11: Repeat Geophysics– cross well seismic

VSP AIT ti l i RST– VSP, AIT, acoustic logging, RST– repeat surface 3-D seismic

Interim Conclusions (Cranfield)Interim Conclusions (Cranfield)

• Phase III 1 million tonne/year rate achieved Dec 20, y2009, 2 Million tonnes monitored since July 2008

• Rate to be maintained >15 months• Monitored with standard and novel approaches• Monitored with standard and novel approaches

– History match pressure response– Fluid flow measured/monitored with multiple tools in complex

flow fieldflow field– First US use of Electrical Resistance Tomography (ERT) for

sequestration– Quantification of CO2 dissolutionQuantification of CO2 dissolution

• Export to commercial EOR/sequestration projects