CO 2 STORAGE IN DEPLETED GAS FIELDS Filip Neele, Stefan Belfroid, Aris Twerda
CO2 STORAGE IN DEPLETED GAS FIELDSFilip Neele, Stefan Belfroid, Aris Twerda
STORAGE IN DEPLETED GAS FIELDS
First choice for CO2 storage in The Netherlands~ 1.5 Gt capacity in ~100 offshore fieldsRe-use of pipelines, platforms, wells
Competition with other uses for offshore areaWind farmsEnergy storage or conversion
First gas fields (cluster) under development for CCSPorthos consortium (Rotterdam)
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North Sea Energywww.north-sea-energy.eu
ALIGN - CCUS DEVELOPING CAPACITY
Abundant storage capacity, but how to develop it?
Potential timeline of field developmentRanking of options – unit storage cost, location, capacity, etc.
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P18 cluster35 Mt
P15 cluster35 Mt
Q1 clusterDGF, DSF
K14-K15 clusterSeveral fields
First choice(~25 km dist.)
Second choice?(~20 km)
Re-use oil pipeline?(~75 km)
Several clusters in central DCS
DGF: depleted gas fieldDSF: deep saline formation
T&S SYSTEM
11-12 February 20204th offshore CO2 storage workshop IEAGHG
Compressor
Platform
Riser
Reservoir
Wells
Large pressure drops in system – management of CO2 temperature is
key element of operations
High-pressure pipeline(s)
Low pressure (at start)Well integrity, fault stability, flow rates, intermittency, low-
temperature cycling, …
Pressure and temperature distribution and development in reservoir (injection of cold CO2)
Risk management planMonitoring plan
Site conformanceSite handover
Re-using platforms, wells, pipelines
Network developmentFlexibility, robustness
4
RE-USING DEPLETED FIELDS(AND THE WELLS)
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15 °C
CO2 hydrate
Need water…
Safe storageWell integrity maintained during operations
Injection on – off: temperature cycling in wellWellhead: T > -10 °C (material constraint)
Reservoir and cap rock integrity preservedLarge contrast temperature CO2 - reservoir
Maintain operability of reservoirAvoid salt deposition and hydrate formationHydrates: bottomhole T > 15 °C
Flow rates through well: limits due to erosion, vibration
0 0.5 1 1.5 2 2.5 3 3.5 4 4.5
Distance [km]
-50
-40
-30
-20
-10
0
10
20
30
Tem
pera
ture
[deg
C]
0
0.05
0.1
0.15
0.2
0.25
Dia
met
er [m
]
10
20
40
80
130
170
T=15
D
-10 °C (wellhead)
15 °C (bottom hole)
TVD ~ 3.5 km (deviated well)
At wellhead:Massflow: 10 - 170 kg/sPipeline pressure 100 barWellhead temperature: 10 °C
Near bottom of well:Reservoir pressure: 20 barReservoir temperature: 120 °C
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Minimum safe injection rate
80 kg/s (~2.5 Mtpa)(only for this
particular set-up!)
EXAMPLE: LIQUID, COLD CO2CONDITIONS ALONG WELL
Results depend on well completion, reservoir properties, etc.: system design to take the flow phenomena into account
DYNAMIC OPERATIONS – SHUTINShutin
Reservoir pressure 20 bar Initial mass flow rate 30 kg/sWell shut in
During shutinWellhead pressure decreasesLiquid is formedConditions shift to phase lineResults in temporary low temperatures
Requires detailed heat transfer calculations including heat capacity
Tubing temperaturesAnnulus temperaturesCement bonding
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Total time: 90 minutes
CONFORMANCE MONITORING
Define site conformance indicatorsPressure, temperature in places in system
Compare measured and observed field performance indicators
Measured: noiseModelled: uncertainties, model limitations
What is magnitude of signal in monitoring data from risks that do occur, compared to noise and uncertainties?
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Regulations in place, but not tested yet
EU Storage Directive & ETS: emphasis on monitoring, measuring and verification
How well can we assess conformance?
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EXAMPLE: BHP BASED MONITORING
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Correct assessment depends on (a.o.):Uncertainties in a priorimodel, variations in CO2quality, noise in monitoring data
False negatives, false positives
Improve: decrease uncertainties, add other monitoring
techniques
0 5000 10000 15000
Time (days)
0
0.2
0.4
0.6
0.8
1
Frac
tion
of c
orre
ct a
sses
smen
ts
t = 30 days
BHP = 0.5 bar
BHP = 1.0 bar
BHP = 1.5 bar
BHP = 2.0 bar
BHP = 2.5 bar
BHP = 3.0 bar
CONCLUSIONS
Depleted fields: blessing in disguise?
Abundance of data from production periodWell-defined storage capacityPipelines, platforms and wells to be re-used
Low pressure represents challenge – injection project becomes temperature management projectFor NL fields: size (capacity) of fields requires many fields to be developed
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11 11-12 February 20204th offshore CO2 storage workshop IEAGHG
This work has been produced with support from the ERA-NET ACT Pre-ACT project (Project No. 271497) funded by RCN (Norway), Gassnova (Norway), BEIS (UK), RVO (Netherlands), and BMWi (Germany) and co-funded by the European Commission under the
Horizon 2020 programme, ACT Grant Agreement No 691712. We also acknowledge the following industry partners for their contributions: Total, Equinor, Shell, TAQA.
AcknowledgementsACT ALIGN CCUS Project No 271501
This project has received funding from RVO (NL), FZJ/PtJ (DE), Gassnova (NO), UEFISCDI (RO), BEIS (UK) and is cofunded by the European Commission under the Horizon 2020 programme ACT, Grant Agreement No 691712
www.alignccus.eu
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