shell quest ccs project
TRANSCRIPT
QUEST CCS PROJECT
Stephen Harvey– QUEST Geophysicist
5
CO2 Pipeline
2
1
Amine Unit Compressor
1
QUEST - LOCATION
March 19, 2014 Quest Project - MUN 2014, Calgary
Alberta
Canada
Quest Fort Saskatchewan
Fort McMurray
Edmonton
Calgary
! Capture plant located near Fort Saskatchewan, approx 60 km N.E. of Edmonton
2
CCS IN ALBERTA
n CCS is a significant part of GHG mitigation plans for both Canada and Alberta
n Quest Funding
n ~1.3 Bln $ project
n 165 MM$ CND, 700 MM$ AB
Source: Alberta 2008 Climate Change Strategy
GHG emissions profile and mitigation options – Alberta
CCS =70%
Materiality: Quest = 1.1 MT/a of
CO2 ~ 175,000 cars
50Mt
BUSINESS AS USUAL
ALBERTA’S PLAN
First CCS project in Alberta Oil Sands and it has massive scalability.
Cost of Project • ~1.3 Bln $ Quest Funding • 165 MM$ CND, 700
MM$ AB
The Athabasca Oil Sand Project (AOSP)
May 2014 4
Peace River
Calgary
Edmonton
Corridor Pipeline
Fort McMurray
Muskeg River Mine
Bitumen
Scotford Upgrader
Bitumen to Synthetic crude (255,000 bpd)
H2
Scotford Refinery
(Shell only)
AOSP - JV among Shell (60%); Chevron (20%); and Marathon (20%) QUEST Update - Pittsburgh CCUS Conference
QUEST – Overview
SALT SEALS
Cement
SHALE SEALS
TARGET FORMATION
! Capture at the Scotford Upgrader from 3 Hydrogen Manufacturing Units - One million tonnes CO2 per year capacity for 25 years
! CO2 transported by 12 inch pipeline to storage, with 6 inch laterals
! Pipeline to 65 km north of the Upgrader
! Wells : 3 injection wells , 3 Deep Monitoring Wells and 9 Shallow Ground Water monitoring wells
! Execution Phase since Sept 2012
May 2014 5 QUEST Update - Pittsburgh CCUS Conference
INTEGRATED CCS PROJECT �Technical aspects: Capture, Pipeline, Storage & MMV
CO2 Pipeline
2
Pipeline to storage site, 65 km
3 CO2 injectors
1
Amine Unit Compressor
1
Up to 1.2 Mtpa from the Scotford Upgrader
o Commissioning Q1 2015 o Sustained Injection by end 2015 o Measurement, Monitoring &
Verification (MMV) o 25 year field life (27 Mt CO2 ) o 10 year closure period
n BCS Storage Complex n Deep saline aquifer (~2km), porous sandstone (Por~16%, K~ 1D)
n Multiple continuous seals to minimize containment risk
n No significant faulting visible from wells or seismic
n Well below hydrocarbon bearing formations(<1200m) and potable water zones (<200m)
n Few legacy wells, nearest at ~20 km
QUEST Overview - Storage
34m
84m
44m
41m
Ultimate Seal
Secondary Seal
Primary Seal
Injection Target
Ultimate Seal
BC
S St
orag
e C
ompl
ex
Win
nipe
gosi
s C
ompl
ex
Upper Lotsberg
Lower Lotsberg
MCS – Middle Cambrian Shale
LMS – Lower Marine Sand
PreCambrian Basement BCS – Basal Cambrian Sand
85m
May 2014 7 QUEST Update - Pittsburgh CCUS Conference
QUEST - Construction Progress Highlights
8
! All major equipment such as towers and the compressor have been received and on site.
! One HMU set of equipment modules installed.
! Pipeline construction progressing and > 50% welding is complete.
! Wells drilled and 2 injection wells tested in 2013
! Operations readiness activities progressing per plan
! Schedule is tracking on target costs slightly below target
! Public engagement activities continue through start-up.
May 2014 QUEST Update - Pittsburgh CCUS Conference
QUEST - Amine Stripper Vessel lift – March, 2014 �
May 2014 9 QUEST Update - Pittsburgh CCUS Conference
QUEST - 2013 Well Test Results - Injectivity
10
W ell N am e Ra te D elta P In jectiv itym 3 / d k Pa m 3 / d /MPa
Ra dw a y 8 -‐1 9 3 6 0 0 .9 5 3 7 9Redw a ter 1 1 -‐3 2 4 9 2 1 2 .1 3 4 1Tho rh ild 5 -‐3 5 3 4 2 0 .3 3 1 0 3 6Ra dw a y 7 -‐1 1 3 9 6 0 .1 9 2 0 8 5
0
10000
20000
30000
40000
50000
60000
70000
3 Well Avg PI Water Injection Rates
Water Injection Potential
Estimated CO2 Injection Potential
Quest CO2 injection requirement
Injection Ra
te, [reservoir m
3/d]
Water PICO2 UncertaintyQuest Requirement
Linear adjustmentto FBHP of 26 MPa
CO2/waterinjectivityratio of 1.5 -‐ 3
Quest Initial Rate= 900 -‐ 1800 %
May 2014 QUEST Update - Pittsburgh CCUS Conference
Regulatory Constraint Ø 30 Mpa Ø Fracture pressure 40Mpa
WATER INJECTIVITY / TEST RESULTS
CO2 INJECTION CAPABILITY
Pressure and CO2 Plume Propagation
2015 - Start 2015 - Start 2016 – 1 Year Injection 2025 2025 – 10 Year Injeciton 2040 – Shut-in 2045 – Shut-in 5 years
2055 – Shut-in 15 years
MPa
2016 – 1 Year
2025 – 10 Years
2040 – Shut-in 2050 – 10 Years Shut-in 2085 – 45 Years Shut-in
Expectation delta Pressure
Expectation CO2 @ 8-19
Heavy Oil Shell Canada
QUEST - New Well Results - Containment
May 2014 12 QUEST Update - Pittsburgh CCUS Conference
Gen-4- Pressure Distribution after 25 Years of Injection in the Mid Property / Mid Connectivity Case with an analytical aquifer extension
Gen -4- 25 Year FBHP Forecast for the mid property, mid connectivity case with analytic aquifer
n Capacity very large compared to injected volume
n Elevated pressure is very low - no risk of brine leakage n Expected to be considerably less then Gen-4 – mid case
QUEST IN-WELL MONITORING
Lotsberg
LMS
BCS
MCS UMS
Colorado
PreCambrian
Upper
Lower
CKLK
Quest Storage Complex
Freshwater
Geophone array (1 well only)
450m
1750m 5 ½”
8 ¾”
30m DEEP MONITORING WELL (DMW)
40m
180m 5 9/16”
Datalogger (pH, Eh)
GROUNDWATER MONITORING WELL (GWM)
DTS/DAS
13 3/8”
9 5/8”
4 ½
” Tu
bing
7“
Downhole P/T Gauge
450m
2000m
2150m
INJECTION WELL (IW)
QUEST - New Well Results - Injection Performance Modelling
14 May 2014 QUEST Update - Pittsburgh CCUS Conference
5 Generations of Models
Ø Substantial reduction in range of uncertainty after appraisal/injection wells in 2012/13
! !
Identify Risks &
Uncertainties
Appraisal
Strategy
Data Evaluation
Integrated Reservoir Modeling
1)FPP
SDP & MMV Plans
2) Lease App.
3) Reg. Submission
4) SDP n Status n BCS Static model update
complete
n Cooking Lake static modeling ongoing
n Leak path model update ongoing
n Results in Q3 2014 n CO2 plume and pressure
predictions
- Sequestration Lease area
- Timing of VSP vs 4D seismic
- MMV coverage
n Leakage risk
n Pressure Monitoring Thresholds
Iterative Workflow
! 5) MMV
Heavy Oil Shell Canada
MONITORING PLAN OVERVIEW
Atmosphere LightSource CO2 Monitoring
Biosphere Remote Sensing (Brine & NDVI), CO2 Natural and Artificial Tracer Monitoring,
Hydrosphere Private Landowner Groundwater wells (Chemistry and Isotopes on water and wellhead gas
Deep Monitoring
Wells
Down-Hole Pressure & Temperature (DHPT) above Storage Complex Down-Hole Microseismic Monitoring
BCS Observation Well: DHPT
Injection Wells
Injection Rate Metering, PFC Tracer Injection?
Geosphere
InSAR
Time-Lapse 3D VSP Time-Lapse 3D Surface Seismic
DHPT, Distributed Temperature and Acoustic Sensing, Annulus Pressure Monitoring, WHPT, Wellhead CO2 Sensor, Mechanical Well Integrity
Testing, Operational Integrity Assurance
Time (years)
Baseline Injection Closure
CBL, USIT
Shell Groundwater Wells: Continuous EC, pH, T, P & ORP, Discrete Chemical and Isotopic Analysis on water and WHG,
2010 2015 2020 2025 2030 2035 2040 2045 2050
CO2 Flux & Soil Gas
Heavy Oil Shell Canada
MMV baselining Activities – HBMP progress
May 2014 16 QUEST Update - Pittsburgh CCUS Conference
a)Discrete GW well sampling (Landowner & Project Wells)
Sampling event Jan Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec
Q4-‐2012
Q1-‐2013
Q2-‐2013
Q3-‐2013
Q4-‐2013 b)
Continuous GW well sampling (Project Wells only)Sampling event Jan Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec
2013 c)
Soil Gas/Flux Sampling & Remote Sensing Calibration Data AcquisitionSampling event Jan Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec
Q4-‐2012
Q1-‐2013
Q2-‐2013
Q3-‐2013
Q4-‐2013
no soil gas
n Ground Water and Biosphere Baseline Data acquisition progressing as planned n Golder Report at end of 2013 summaries all data to date.
n “Sample Manager” implementation ongoing for Data Management
Heavy Oil Shell Canada
MMV Baselining Activities – Pressure Monitoring
May 2014 17 QUEST Update - Pittsburgh CCUS Conference
n Pressure Monitoring Zone changed to Cooking Lake n Shallowest zone with high enough permeability
n Depleted by production from the Leduc Reef
n Commenced Feasibility Study n Pressure gauges installed in DMW 5-35 and DMW 7-11 to measure pressure variability
n Some fit for purpose dynamic modeling indicates monitoring at Redwater 3-4 would be beneficial
n Planning for gauge installation in Redwater 3-4 and building a more detailed Cooking Lake static model.
MMV baselining – 2014/15 Activities
May 2014
18
QUEST Update - Pittsburgh CCUS Conference
RADAR REMOTE SENSING for Salinity (SAR) & Surface Deformation (INSAR) - Complete SAR Feasibility Study - Q2 2014 - Update INSAR capability Dec 2014
OPTICAL REMOTE SENSING for Plant Health Feasibility Ongoing – Complete in 2014
BCS Formation
Injector Observation Well Geophones
Seismic wave
Microseismic event
Fracture opening or fault slip
BCS Storage Comple
x
Micro Seismic – Installation Q3 2014
Surface Seismic
3D VSP
3D VSP Baseline –Q1 2015
March 19, 2014 Quest Project - MUN 2014, Calgary
BCS Formation
Injector Observation Well Geophones
Seismic wave
Microseismic event
BCS Storage Comple
x
§ Time Lapse 3D Surface Seismic (& Time Lapse 3D VSP) Ex: Sleipner/Norway, CO2 injecMon into saline aquifer (started 1996) (source: Chadwick et al., 2009, Energy Procedia 1, 2103–2110)
§ Micro Seismic Fracture opening or fault slip
19
QUEST - MMV ACTIVITIES: GEOSPHERE § Remote Sensing (InSAR)
Surface displacement
Heavy Oil Shell Canada
MMV Activities - Sensor Hook Up / Data Transmission �
20
Storage �(Well sites)
LOS CO2 DAS …
Continuous MMV data
(WPH, WEC, BHP, DMWP.)
LOS CO2 DAS …
MMV data (MS data, DAS/
DTS Lightsource
LOS CO2 DAS …
Continuous Process Control
(WHPT, WHCO2, APM,DHPT)
Capture (Scotford)
Transport (Pipeline)
Well pads
Private wireless
CO2
ß 67 km pipeline à
P&C Signals, Alarms
MMV Measurements
LBV’s
#1
X
P&C data
Scotford Control Room
Scotford Control Rooms
#2
X #3
X #4
X #5
X
Storage Mgt Team
WRFM TOOLKIT
SHELL NETWOR
K
PI
May 2014 QUEST Update - Pittsburgh CCUS Conference
Heavy Oil Shell Canada
MMV Activities - Technology Development
May 2014 21 QUEST Update - Pittsburgh CCUS Conference
n Tracer Feasibility Studies n PFC Experimental work progressed in 2013 and ongoing until March 2014
n C13 Studies progressing
- CO2 Gas sampling at Scotford
- Research (phases 1 to 3) completed and reports received from the Uni. of Calgary
- C13 Data collection in as part of the HBMP baselining
n Decision on Tracers postponed to June 2014 – AER special report #3
n Lightsource Feasibility n Controlled release test at IW 8-19 in Sept. 2013
n Further work on algorithm development
n New Boreal digital laser tested.
n Agreed workplan with U of Vic & BC on EC for background
n Report Expected May 2nd - Milestone meeting /Decision
Heavy Oil Shell Canada
April 11, 2014 22 Quest CCS Project - 2nd AER Annual Status Report
Stakeholder Engagements n Status
n Local community events in summer 2013 (Thorhild Sunflower Festival)
n Open Houses conducted in October 2013:
n Thorhild, Radway and Bruderheim
n Town, City and Council updates provided annually to:
n Thorhild, Lamont, Bruderheim, Fort Saskatchewan, Strathcona, Lamont, Sturgeon
n Community Advisory Panel (CAP) formed and kicked off in 2012 for MMV program- met 6 times in 2013- including touring the upgrader and pipeline construction
n Community newsletters - 2 in 2013
n HBMP GW sampling brochure for landowners issued in Q1 2014
n Upcoming work in 2014 n Continue CAP meetings (quarterly), annual Council
updates , Open Houses (Oct. 2014) and Newsletters
n Community survey on Quest (completed bi-annually)
n Well Program n Hook up and testing of wellpad MMV
sensors by Q4 2014
n MMV program
n Baseline sampling program complete Q1 2015
n Capture & Pipeline n Module fabrication – Last module
installation targeted for summer 2014
n Pipeline mechanical completion expected fall 2014
n Mechanical completion of capture facility by Q1 2015
n Operations Handover Q3 2015
n Full production Q4 2015
May 2014 23
QUEST - Project Timeline to Operations
QUEST Update - Pittsburgh CCUS Conference
Thank You
QUEST - 2013 Well Test Results - Injectivity
25
W ell N am e Ra te D elta P In jectiv itym 3 / d k Pa m 3 / d /MPa
Ra dw a y 8 -‐1 9 3 6 0 0 .9 5 3 7 9Redw a ter 1 1 -‐3 2 4 9 2 1 2 .1 3 4 1Tho rh ild 5 -‐3 5 3 4 2 0 .3 3 1 0 3 6Ra dw a y 7 -‐1 1 3 9 6 0 .1 9 2 0 8 5
0
10000
20000
30000
40000
50000
60000
70000
3 Well Avg PI Water Injection Rates
Water Injection Potential
Estimated CO2 Injection Potential
Quest CO2 injection requirement
Injection Ra
te, [reservoir m
3/d]
Water PICO2 UncertaintyQuest Requirement
Linear adjustmentto FBHP of 26 MPa
CO2/waterinjectivityratio of 1.5 -‐ 3
Quest Initial Rate= 900 -‐ 1800 %
Well Core Avg k (D)
Core Max k (D)
Test Low Keff (D)
Test Mid
keff (D)2
Test High
keff (D)3 8-‐19 0.5 3.6 0.5 0.8 1.1 5-‐35 0.9 2.2 0.8 1.0 1.3 7-‐11 0.9 2.9 1.2 1.8 2.0
Well FEP FCP
1AA/11-32 45.4 MPa (20.7 kPa/m)
31.7 MPa (14.5 kPa/m)
100/08-19 42.4 MPa (20.6 kPa/m)
34.6 MPa (16.8 kPa/m)
102/05-35 48.1 MPa (23.5 kPa/m)
33 MPa (16.1 kPa/m)
103/07-11 42.5 MPa (21.0 kPa/m)
24.5 MPa (12.1 kPa/m)
May 2014 QUEST Update - Pittsburgh CCUS Conference
Regulatory Constraint Ø 30 Mpa
PERMEABILITY (TEST vs CORE) WATER INJECTIVITY / TEST RESULTS
CO2 INJECTION CAPABILITY FRACTURE EXT. PRESSURE
Heavy Oil Shell Canada
Atmospheric Monitoring
LightSource: CO2 mass flux rate Baseline Injection Closure Baseline Injection Closure
Atmosphere Biosphere
Hydrosphere
Geosphere
BCS Storage Complex