key technologies and solutions in providing reliable and ... · key technologies and solutions in...

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Key technologies and solutions in providing reliable and efficient CO2 geological storage services

Geneva, 27th of November, 2007Presenter Hanspeter RohnerVice President Schlumberger Carbon Services, Europe & Australia

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Schlumberger Carbon Services

CO2 Streams• Coal and Gas Power Plants• Associated gas production• LNG process• Gas-to-Liquid process• Heavy Oil production• Coal-to-Liquid process• Hydrogen• Refineries• Heavy industry

• Steel mills• Cement factories• Aluminum mills

Saline Aquifers

CO2 Capture and Geological Storage

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The CCS Cost (or Value!) Chain

$20 - 50/t CO2 $1 - 10/t CO2 $2 - 10/t CO2 $0.1 - 0.3/t CO2

Capture MonitoringStorageTransport

IPCC Estimations:NGCC $44/t CO2PC $29/t CO2IGCC $20/t CO2

Sensitive

to Energy prices

IPCC:(500km)Ships $10/t CO2

Hydro:(250km)Pipeline: 230M$

University of NewcastlePipeline 570M$/y

Distance

dependant

IPCC: Aquifer$0.5 - 8/t CO2

Pöyry: Aquifer$2/t CO2Gas or oil field$9.5/t CO2

Sensitive to

Reservoir quality

IPCC:$0.1 - 0.3/t CO2

Benson et Al 2006$0.16/t CO2

Remediation

not included

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An Integrated Solution to CO2 Storage

Site Selection Site Characterization (SCP) Field Design

/ Site PreparationSite Construction Injection

Per

form

ance

& R

isk

M

anag

emen

t Sys

tem

(P

RM

ST

M)

Com

mun

icat

ion

and

Pub

lic A

ccep

tanc

e

SE

VE

RIT

Y

-11L

-21S

-41 C

-31M

-51M C

- 22 L

- 41S

- 62 M

- 82C

- 1 02 M C

-33L

-63 S

-93M

- 1 23 C

- 1 53M C

-44L

- 55 L

-84S

-1 24 M

-1 64 C

-2 04 MC

- 1 05 S

- 1 55M

- 2 05C

- 2 55M C

- 1L ig h t

- 2

- 3

- 4

- 5

S e rio u s

M a jo r

C a ta s tro p h ic

M u l ti- Ca ta s tro p h i c

321

Po

ssible

Un

likely

Imp

rob

able

5

Prob

able

4

Like

ly

L IK EL IH O O D

W h i te a rr o w i n d ic a te s d e c re a s in g r is k

P RE V E N TIO N

M I TIG A TIO N

C o n tr o lM e a su r e s

R E D

BL U E

Y E LL O W

G RE E N

IN T O LE R A B LE : D o no t t ak e th is ris k

UN D E S IR A B L E : D em ons t ra te A L A R P be fo re p roc eed ing

A C C E P T A B LE : P roce ed c a re fu lly , w ith c on t inuous im prov em ent

NE G LIG IB LE : S a fe to p r oce ed

-1 6 to -10

- 9 to -5

- 4 to -2

-1

B LAC K N O N -O P ER AB L E : E va c ua t e th e zo n e a n d o r a re a/ co u nt ry-2 5 to -20

Pre-Operation

Phase

~ 10-50 years

~ 2-5 year

Operation

Phase

~50-100+years

Post-Injection

PhaseSite Retirement Programme

(SRP)

Monitoring (M&V)• Operation

• Verification

• Environmental

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ModelingMeasurement forCharacterization

Construction Technologies& Interventions

Monitoring Measurements

Performance & Risk Management System

Performance & Risk Assessment

• Capacity• Injectivity• Containment

• Cost• Environment• Heath & Security• Image

Functions / Stakes

Risk Treatment

PreventionRemediation

RegulatoryFramework

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Initial Assessment – Site Characterization

Data Collection & QC

Sequence, Stratigraphy & Property ModelDynamic Modeling

(flow, geomechanics, geochemistry)

CapacityInjectivity

– Geophysics / Geology

– Petrophysics / Mineralogy

– Geomechanics

– Fluid Properties

– Well Integrity

From CO2CRC – Latrobe Valley Study

Containment

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Building a Static Model – Structure & Properties

Geophysics

Geology Geomechanics

PetrophysicsMineralogy

Flow / TransportSeismic

Well Correlation

Fault Modeling

Zonation and Layering

Facies Modeling

Petrophysical Modeling

Model needs to include overburden

PETREL

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CO2 Injection Dynamic Modeling

CO2 Concentration in Water

Thermodynamics Geochemistry

Thermal Modeling

Monitoring Data

Geomechanics Simulator

Upscaling

3D Full CompositionalFlow Simulator

ECLIPSE – E300

Calibration on monitoring measurements(History match)

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Capacity – MeasurementsStructure

�High-Resolution Seismic, VSP’s and Sonic

Properties

�Borehole imagers �Formation Evaluation

Gamma Ray (GR)0 (GAPI) 200

Micronormal (HMNO)20 0Microinverse (HMIN)

20 0

Caliper6 (IN) 16

SP-100 (MV) 0

Pad1:200M

RSOZDSOZ

RT

HALS Deep Resistivity (HLLD)1 (OHMM)100

0

1 (OHMM)1000

1 (OHMM) 10001 (OHMM)1000

HALS Shallow Resistivity (HLLS)MCFL Rxo (RX18)

High Resolution Density (RHOZ)1.95 (G/C3) 2.95Neutron Porosity

(NPOR)Crossplot Porosity

(PXND)PEF

45 (PU) -15

45 (PU) -15

0 10

1500

1475

�Mineralogy

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Injectivity

� Permeability– Core– Logs– Formation testers– Well tests

� Injection induced near-wellbore effects– Dry-out– Salt precipitation – Carbonate dissolution

� Optimization – Injection well design, placement and number– Hydraulic fracturing

The Reservoir Dry-out Simulation near the Wellbore is crucial

for Injectivity Prediction

Dry-out Zone

CO2 Reactive Transport Fluid Phases Equilibration

0 10.5Gas Saturation

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Injectivity - Measurements

� Permeability from Wireline Logging � Permeability from Well Testing

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Containment

(from Damen et al, 2003)

� Caprock & Overburden– Hydrostratigraphy– Composition– Mechanical properties– Flow properties

� Faults– Transmissibility– Mechanical Properties

�Wells– Completions state– Isolation issues– Degradation mechanisms

(from Latrobe Valley study, CO2CRC, 2005)

Importance of reservoir geomechanicsand evaluation of wells

Modeling to Surface

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Containment – Measurements for Geomechanics

Along the wellbore trajectory:

Strength

UCS Φ

20 400

0 70

UCS

Friction Angle

Earth Stress & Pore Pressure

Pp S h S H S V

MPa0 200Stress W N E

Stress Direction Sh

fault ?

Regional Trend

PR Ε

1Poisson’sRatio

Young’s Modulus 100

Elastic

0

10

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Containment – Integrity of Wells (1)

CharacterisationCement logsDrilling reports

Well geometry

Cement degradationCasing corrosionCO2 migrationLimit conditions

1

23

4

56

7

8

9

1 0

1 1

1 2

1

23

4

56

7

8

9

1 0

1 1

1 2

1

23

4

56

7

8

9

1 0

1 1

1 2

1

23

4

56

7

8

9

1 0

1 1

1 2

1

23

4

56

7

8

9

1 0

1 1

1 2

1

23

4

56

7

8

9

1 0

1 1

1 2

Data & input

K(t)

1

1110

9

8

7

6

5

4

3

2

CO2(t)

H2O(t)Dynamic model

Leak amount & probability

>20 M€

<20 M€

<5 M€

<1 M€

<0,2 M€

F

Financial

Envir.3rd-PPeople

C

SAFETY

6 : Catastr.

5 : Critical

4 : Major

3 : Serious

2 : Marginal

1 : Minor

…B

Asset

A

Reliability &availability.

Stakes

Level

>20 M€

<20 M€

<5 M€

<1 M€

<0,2 M€

F

Financial

Envir.3rd-PPeople

C

SAFETY

6 : Catastr.

5 : Critical

4 : Major

3 : Serious

2 : Marginal

1 : Minor

…B

Asset

A

Reliability &availability.

Stakes

Level

Consequence grid & transfert fonction

Static model

666564636261656555453525154645444342414363534333231326252423222121615141312111654321

DetectionEvolution

Conclusions

811

13

5

00

5

10

15

20

minor weak middle high critical

B = 50

Sensitivity analysisRisk mitigation optionsCost / Benefits ranking

Can we re-use existing wells ?More data needed ?Probability of leakage

Type of leakage to expect X

=

An Integrated Solution to:

• Leakage and Degradation Modeling• Leakage scenarios• Risk criticality estimation

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Prevention Evaluation� Sonic Scanner� Isolation Scanner

� Good drilling practices

� Cement job planning

Geo

Ste

erin

gS

tone

fish

Materials

2 days 6 weeks1 week

� Metallurgy� CO2-Resistant cement

+ +

Wel

lCLE

AN

� Optimal Well Placement

Containment – Integrity of Wells (2)

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Monitoring and Verification during CO2 Injection

Geophysical techniques: Seismic, VSP’s, EM techniques, microseismicityLogging: Saturation (Resistivity, Sigma), Well integrity (Casing corrosion, cement bond)Sampling: Pressure, Fluid properties, CO2 concentrationPermanent sensors: Pressure, Temperature

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CO2 Displacement from Seismic - Sleipner

1994

1999 2001 2002

Baseline Survey

CO2 Injection Start: Sept 19964D Seismic Survey

CO2 Injector Well CO2 below shale layers

� Interpretation of flow patterns (CO2 displacement and trapping)

� Verification of cap rock integrity

Courtesy of Statoil

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Well Logging for CO2 Breakthrough – Frio

(*) Sakurai et al. , SPWLA 46th – June 26-29th - 2005

CO2 saturation measurement along a monitoring well

Frio brine experiment in Texas: Changes of Σ from time lapse logs

Injection start: Oct 4th,

Injection duration: 10 days

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Cap Rock & Fault Integrity

Microseismicity events are micro cracks occurring in the formation due to pressure increase

Listening to these cracks is a powerful monitoring technique

� Detection, Location in 3D and Classification of Microseismicity Events

� Control of Pumping Rate to Avoid Fracturing the Cap Rock

� Detection of Fault Reactivation

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Schlumberger involved CO2 Storage Projects

IdF

CCP2

MGSC

Mountaineer

PCORMRSCP

Frio

Weyburn II

Gorgon

OtwayCO2CRC

Callide

COACH

InSalahHassi Touareg

Karniow

KetzinSleipner

MOVECBM

PETRONAS

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Conclusions

• The Technology is ready !

• But continuous investment in Engineering and Learning While Doing

• Key Technologies focus on:

• Capacity-Injectivity-Containment

• Long term storage integrity

• Key Technologies are

• Measurement (surface and downhole in wells)

• Modeling (static-dynamic-predictive)

• Well Construction (drilling, cementing, completions, remediation)

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Thank You !

key technologies and solutions in providing reliable and ... · key technologies and solutions in...

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