secarb peters 3-9-11 · schlumberger petrel model. ccs full system integration capture plant plot s...
Post on 19-Mar-2020
11 Views
Preview:
TRANSCRIPT
Commercial SequestrationCommercial Sequestration
Dwight PetersDwight PetersNorth America Business Manager
Mar 9, 2011
Acknowledgements
Some graphics in this material is based upon work supported by the U.S. g p p pp yDepartment of Energy (DOE) National Energy Technology Laboratory (NETL). This work is managed and administered by the Regional Carbon Sequestration Partnerships and funded by DOE/NETL and Carbon Sequestration Partnerships and funded by DOE/NETL and cost-sharing partners.
2
The Commercial CO2 Storage WorkflowPost-Operation Phase20+ years
Operation Phase10-50 years
PrePre--Operation PhaseOperation Phase2-5 years
MonitoringConstruction Preparation
Certification at start
Monitoring
CO2 InjectionDesign
Performance Management & Risk Control
DecommissioningTransfer of
Liability
Characterization
Risk Control
SurveillanceSite Selection
Current Knowledge
• Scientific work has identified many potential storage sites in the US and rest of world• Only some of these sites can provide low risk, low cost commercial storagey p g• Injection pilots build acceptance but leave many unknowns about commerciality• Today’ s best practices manuals have been derived from small scale experiences • Many important pilot project experiences are not completely understood• Many important pilot project experiences are not completely understood• Scale-up will require commercial processes adapted from the oil and gas industry.
Important Variables
Construction Injection Equalization ClosurePossible site Probable site Appoved site
?$500M – $1B
Cume Cost
ton)
ate)
monitor
models
Property rights?
es
(pen
nies p
er
ost ?
( su
cces
s ra
gatherdata
updatemodelswells and seismic
Ownership,Liability ?
$50M
$150M
Design andPermit UncertaintyDe
sktop
Stud
ie
Explo
ratio
n Co
EnvironmentalMonitoring
( pennies / ton )
Operate Site3 Mton/yr( dollars / ton )
Collect DataBuild Models BuildPermit
(<10 cents / ton)
Risk Control & Performance Assessment5 yrs 100+0 30 yrs 35 yrs
Uncertainty$1M
Build Models(~50 cents / ton)
Build(~$1 / ton)
* Per ton estimates and total costs (in current day $USD) are based on 100 Mton lifetime storage volume
An Oil and Gas Analogy
Decades ago, potential oil & gas fields were mapped i i il th t t ti l t it b i in a similar way that potential storage sites are being mapped today
Scale Up Challenges for CO2 Storage
• Data integrationg• Risk management• Monitoring and validation• Operational challenges and HSE
Data Integration
• Pilot projects have followed hypothesis driven scientific experimentation• Subsurface models should represent a range of possibilities not a best estimate.• Integration enables us to continually restrict possible scenarios and lessen risk• Multiple disciplines must converge on a shared earth modelMultiple disciplines must converge on a shared earth model• New information must be rapidly added into the decision process
Schlumberger Petrel Model
CCS Full System Integration
Capture plant plot sCapture plant plot s
Capture Island
Transport
CO2 Source
• CO2 quality matched to reservoir • Fluid behavior through network• Operational integration
• alarming• shut downs• back up• back up Storage
CO2 Injection – Simple Schematic
Pipeline Inlet
From Oxy-fuel Combustion Plant - Purified CO2
Compressor Aftercooler
Injection Well y miles
Pipeline Outlet
Geologic Formation
x miles
y miles
z miles
Surface Pipeline
CO2
Surface Pipeline – Effect of Pipeline Diameter200 miles long, 10 miles elevated, 190 miles buried. Inlet temperature 100 °F, inlet pressure 1200 psia, ambient temperature 60 °F, pure carbon dioxide, one million tonnes per year, 18” pipeline
100 100
80 80
60 60
40 40
or F
ract
ion,
%
100
90°F
35
°C
20 20
0 0
Vapo
OLGA S, 2000, V5.3
ΔP 4.1%90
80
70
60
Tem
pera
ture
,
30
25
20 Tem
pera
ture
,
Lower Heat Transfer Coefficient
ΔP 4.1%
1200
1190
1180
1170
ress
ure,
psi
a 8.2
8.1
8 0 ress
ure,
MP
a
OLGA S, 2000, V 5.3
Beggs and Brill
60
300250200150100500
Pipeline length, km
1160Pr 8.0 Pr
Surface Pipeline – Effect of Pipeline Size200 miles long, 10 miles elevated, 190 miles buried. Inlet temperature 100 °F, inlet pressure 1200 psia, ambient temperature 60 °F, pure carbon dioxide, one million tonnes per year, 12” pipeline
100
80
60
40
or F
ract
ion,
%
100
80
60
40
Beggs and Brill
100
90°F
35
°C
20
0
Vapo
20OLGA S, 2000, V5.3
ΔP 26.3%80
70
60
Tem
pera
ture
,
30
25
20 Tem
pera
ture
,
Beggs and Brill
OLGA S, 2000, V5.3
ΔP 26.3%
1200
1100
1000
ress
ure,
psi
a 8.0
7.5
7.0
6
ress
ure,
MP
a
Beggs and Brill
OLGA S, 2000, V5.3
300250200150100500
Pipeline length, km
900
P 6.5 P
Surface Pipeline – Effect of Temperature200 miles long, 10 miles elevated, 190 miles buried. Inlet temperature 100 °F, inlet pressure 1200 psia, ambient temperature 75 °F, pure carbon dioxide, one million tonnes per year, 12” pipeline
100 100
80 80
60 60
40 40
or F
ract
ion,
%
100
90°F
35
30
°C
20 20
0 0
Vap
o
ΔP 42.5%80
70
60
Tem
pera
ture
, 30
25
20
15
Tem
pera
ture
, ΔP 42.5%
1200
1100
1000
900
800ress
ure,
psi
a
8
7
6
ress
ure,
MP
a
Beggs and Brill
300250200150100500
Pipeline length, km
800
700
Pr
5
Pr
Surface Pipeline – Effect of 4 mole% Argon Addition
200 miles long, 10 miles elevated, 190 miles buried. Inlet temperature 100 °F, inlet pressure 1211 psia, ambient temperature 60 °F, one million tonnes per year, 12” pipeline
1.0
0.8
0.6
0 4apor
Fra
ctio
n
0.4
0.2
Va
300x103250200150100500Distance, m
3020C
100
80
eg. F ΔP 82.2%20
100
-10-20-30Te
mpe
ratu
re, d
eg. 60
40
20
0
-20
Tem
pera
ture
, de ΔP 82.2%
300x103250200150100500Distance, m 1200
1000
800
600 ssur
e, p
sia
87654su
re, M
Pa
600
400 Pres
300x103250200150100500Distance, m
432
Pre
s
Full Integration
Economics Model Petrel
Integrated Asset ModelGeologic Model
gFacilities Model
Pipeline Model
Wellbore Model
GeoChemicalModel
Reservoir Simulators
GeoMechanicsModel
W ll d tE i t d t
Seismic data (characterization)
Well dataEnvironment data
Monitoring data (all types)
HSE risk evaluation
Monitoring data (all types)
Leakage risk evaluation
The Risk Management Matrix
ResponsesRED
YELLOWINTOLERABLE: Do not take this risk
UNDESIRABLE: Demonstrate ALARP before proceeding
-16 to -10
-9 to -5
BLACK NON-OPERABLE: Evacuate the zone and or area/country-25 to -20
p• reduce likelihood (PREVENT)• reduce severity (MITIGATE).P
ossible
Unlikely
Improbab
Probable
Likely
MITIGATION
ControlM
BLUEGREEN ACCEPTABLE: Proceed carefully, with continuous improvement
NEGLIGIBLE: Safe to proceed
-4 to -2
-1
Tasks:• Intelligently construct “Scenarios”
that can be modeled.Effi i tl l i l ti
-11L
-22L
-33L
-44L
-55L
-1Light
321
ble
54
LIKELIHOODPREVENTION
Measures
• Efficiently apply simulation resources.SEVER
I
-21S
-31M
-41S
-62M
-63S
-93M
-84S
-124M
-105S
-155M
-2
-3
Serious
Major
Hazard Analysis and Risk ControlSt d d SLB QHSE S020
ITY
-41C
-51MC
-82C
-102MC
-123C
-153MC
-164C
-204MC
-205C
-255MC
-4
-5
Catastrophic
Multi-Catastrophic
Standard SLB-QHSE-S020White arrow indicates decreasing risk
CO2 Monitoring – 3 objectives
#3 M it th i t
ContainmentContainment #2: Watch possible leakage paths
#3: Monitor the environmentWell Integrity
S l d f lt
Freshwateraquifer
BoundariesBoundaries#1: Watch stored CO2
Sealed fault
Monitoringwell
Abandonedwell
Monitoringwell
CO2injectionwell
Operational Challenges and HSE
• The ability to execute a plan in real-time is as important as the plan itself• A proven methodology for decision making, in a dynamic environment, is critical.• When we drill and inject into the subsurface we create:
• predictable events that we can validate• Indicators for unpredicted events that could lead toward negative consequences
• Our ability to anticipate scenarios and respond, prior to incident, is crucial• Response capability is the key ingredient in overall cost minimizationp p y y g• All of the above impact HSE
What is Needed for Project Success
CO2 Technology
People + TechnologyPeoplePeople CO2 Technology
All Seismic ServicesWellbore Integrity EvaluationD illi & C l ti&
p
Geology Geophysics
Reservoir Engineer Drilling Engineer
p
Geology Geophysics
Reservoir Engineer Drilling Engineer Drilling & CompletionCementing Logging, Testing & SamplingL b A l i
&g g g
Petrophysics Completion Engineer
Geomechanics Geochemistry
g g g
Petrophysics Completion Engineer
Geomechanics GeochemistryLab AnalysisData ProcessingModeling & Plume PredictionD t M t
y
Hydrogeology Economics
HSE Injection
y
Hydrogeology Economics
HSE InjectionData ManagementOperational MonitoringVerification MonitoringC li M it i
Project ManagementProject Management
Tools for Team IntegrationCompliance Monitoring
The Operational Team Needs:
Significant commercial e perience ith field operations and asset de elopment• Significant, commercial experience with field operations and asset development• CO2 specific experience• Organizational alignment and motivation – culture, training, HSE• Understanding of and access to key technologies and tools• Support infrastructure, HSE
Lessons Learned Through Demonstrations
● Geologic uncertainty is scary to some (esp. engineers)g y y ( p g )● CO2 moves farther, faster, and with fingering● CO2 stands out from brine on most monitoring techniques―No chance of 100% accounting
● Old wells will need special focusL bl i d l t d il fi ld―Large problem in depleted oil fields
● Need to consider the entire system or suffer the consequences
top related