Well integrity for CO2 injection from ships: Simulation of the effect of flow and material parameters on thermal stresses

Aursand, Peder; Hammer, Morten; Lavrov, Alexandre; Lund, Halvor; Munkejord, Svend Tollak; Torsæter, Malin

doi:10.1016/j.ijggc.2017.04.007

Cited by 26 publications

(17 citation statements)

References 49 publications

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“…It is undoubtedly important to investigate how the economic performance of CCS power stations can be improved by exploiting the flexible capabilities of the capture unit. The techno-economic literature on flexible operation of CCS power plants is, however, generally separate from studies investigating the effect of this flexible operation on the downstream CO 2 transport and storage system (IEAGHG 2016, Jensen et al 2014, Roy et al 2016, Aursand et al 2017. Recently a study by Spitz et al (2018) found that regular bypass operation has the potential to further increase the variability of CO 2 flows in the transport and storage system, particularly at low carbon prices (i.e.…”

Section: Introductionmentioning

confidence: 99%

Operating flexibility of natural gas combined cycle power plant integrated with post-combustion capture

Spitz

González-Díaz

Chalmers

et al. 2019

International Journal of Greenhouse Gas Control

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Highly flexible, low-carbon electricity generation with gas-fired power stations with CO 2 capture addresses the challenges of balancing variable renewable electricity supply in low carbon electricity systems. This detailed technical assessment of flexible CO 2 capture plant operation at natural gas combined cycle power stations with post-combustion CO 2 capture examines the operating strategies of capture plant bypass and interim solvent storage. We show that solvent storage allows expanding the operating envelope of gas fired CCS power stations by +/-10%. Further we demonstrate that electricity and CO 2 output can be decoupled for up to 3 hours with approx. 6000 m 3 of additional solvent inventory for the purpose of reducing the CO 2 flow variability in downstream transportation and storage systems, mitigating potentially deleterious injection well effects. 1hr of solvent storage operation at full load can be regenerated in as fast as 2.1hrs during continuous operation of the CCS power plant by choosing a controlled steam extraction strategy from the combined cycle and thus throttling the low pressure turbine. The electricity output penalty associated with the delayed regeneration of solvent ranges from 420-450kWh/tCO 2 with this strategy, which compares to 380kWh/tCO 2 for immediate regeneration at full load design conditions. By deploying a novel variable speed drive integrally geared compressor model, we find that, unlike previously thought, an uncontrolled steam extraction strategy, referred as a floating steam extraction strategy, can lead to choking of the CO 2 compressor during additional solvent regeneration. A pre-compression stage would be necessary under this extraction strategy to restore feasible operation of the main CO 2 compressor, and makes this strategy more complex to implement. When decreasing the desorber pressure at part-load care must, therefore, be taken to respect the operating limits of the compressor. To assist with the use of rigorous plant performance data in wider electricity system models, correlations for key performance parameters of NGCC-CCS power plants at varying load, with capture bypass and additional solvent regeneration are provided.

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Section: Introductionmentioning

confidence: 99%

Operating flexibility of natural gas combined cycle power plant integrated with post-combustion capture

Spitz

González-Díaz

Chalmers

et al. 2019

International Journal of Greenhouse Gas Control

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“…The reservoir is connected to the center of the bottom cell in the well, and the main well parameters are summarized in Table 2. This is comparable to the setup of Aursand et al, 4 except that we here employ a full near-well reservoir model instead of a simplified downhole boundary condition in the well.…”

Section: Case Descriptionmentioning

confidence: 86%

“…In our previous work, 4 we employed a robust method (see, e.g., Munkejord and Hammer 31 and Munkejord et al 32 ) able to accurately capture the pressure waves inherent in the flow model. Thus, the time-step length of that method was limited by the Courant-Friedrichs-Lewy (CFL) stability criterion based on the speed of sound, that is, giving short time-step sizes.…”

Section: Numerical Solutionmentioning

confidence: 99%

“…In our previous work (Aursand et al 4 and Linga and Lund 24 ), CO 2 injection into the surrounding reservoir was modeled by a constant injectivity index, but flow in the reservoir itself was not considered. In this paper, we extend the previous approach by computing the varying reservoir pressure and fluid mobility by solving a near-well flow model, which is bidirectionally and dynamically coupled to the flow model of the well.…”

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confidence: 99%

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Coupled CO2‐well‐reservoir simulation using a partitioned approach: effect of reservoir properties on well dynamics

et al. 2020

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We present a model framework for dynamic simulation of the flow of CO 2 and other components in an injection well coupled with a near-well reservoir. With a partitioned approach, we employ numerical methods adapted to the governing equations in each domain. In both well and reservoir, accurate thermodynamics are used. This model can be used for various design and operational considerations for CO 2-injection wells, that is, the quantification of pressure and temperature transients, and phase composition, including the appearance of a water-rich phase. We study cases where the flow in the well and the near-well reservoir is dynamically coupled. The rock properties are seen to strongly affect the well dynamics, both regarding magnitude and transient evolution of the bottom-hole pressure. We consider a variation of this case where water is co-injected with CO 2 , showing that this is a potential method to mitigate salt precipitation. We also consider intermittent injection, representing the case of direct injection from ships transporting CO 2. Finally, we observe that in the present cases, a coupled model (as opposed to a well-only model) is necessary in order to capture the dynamics in the well during injection.

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“…In [4] we considered single-and two-phase flow during blow-out and shut-in in vertical CO2-injection wells. In [1] we studied the heat transfer through the different materials surrounding the vertical pipe, and the resulting thermal stresses. For intermittent injection scenarios for direct offshore ship offloading, we found that high thermal stresses could occur.…”

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confidence: 99%

Dynamic Simulation of CO2 Injection Wells

et al. 2019

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For CO2 transport, pipelines are often cited as the most efficient alternative. However, CO2 transport by ship is being considered for CO2 sources close to the coast and far from an offshore storage site. In the early phases of CCS deployment, transported CO2 quantities will be small, which makes ships the most cost-efficient means of transport. Ship transport will also be flexible in the sense that new sources can easily be added. Irrespective of means of transport, the CO2 must flow through an injection well before it reaches the geological reservoir. The transport-storage interface constitutes one of the main challenges for transport of CO2. Possible processing at the injection site, well-flow dynamics [2], well integrity [1] and the response of the CO2 storage reservoir need to be described. This requires good knowledge of the relevant CO2-rich fluid properties, as well as the flow in the well and coupling between well and near-well flow, the interaction of brine and CO2, etc. [5].

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Well integrity for CO2 injection from ships: Simulation of the effect of flow and material parameters on thermal stresses

Cited by 26 publications

References 49 publications

Operating flexibility of natural gas combined cycle power plant integrated with post-combustion capture

Operating flexibility of natural gas combined cycle power plant integrated with post-combustion capture

Coupled CO2‐well‐reservoir simulation using a partitioned approach: effect of reservoir properties on well dynamics

Dynamic Simulation of CO2 Injection Wells

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