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Coupled Hydromechanical Modeling and Assessment of Induced Seismicity at FWU: Utilizing Time-Lapse VSP and Microseismic Data

Author

Listed:
  • Samuel Appiah Acheampong

    (New Mexico Tech-PRRC, 801 Leroy Place, Socorro, NM 87801, USA)

  • William Ampomah

    (New Mexico Tech-PRRC, 801 Leroy Place, Socorro, NM 87801, USA)

  • Don Lee

    (New Mexico Tech-PRRC, 801 Leroy Place, Socorro, NM 87801, USA)

  • Angus Eastwood-Anaba

    (New Mexico Tech-PRRC, 801 Leroy Place, Socorro, NM 87801, USA)

Abstract

The objective of this work is to utilize integrated geomechanics, field vertical seismic profile (VSP) and microseismic data to characterize the complex subsurface stress conditions at the Farnsworth Unit (FWU). The model is based on a five-spot sector model extracted from a primary geomechanical model. The five-spot well injection pattern is characterized by extensive reservoir characterization data, such well logs, extracted cores and borehole geophone data, to facilitate the detailed examination of stress changes and microseismic event occurrences. The study utilizes field vertical seismic volumes acquired from the injection well 13-10A. The seismic volumes successfully provided snapshots of the behavior of the reservoir at distinct times. The use of VSP and microseismic data provided direct and indirect estimates of the dynamic stress changes occurring in the overburden, reservoir and underburden rock formations. In order to illuminate the stress regions and identify rocks that have undergone inelastic failure, microseismic event occurrences were utilized. Microseismic activity has been detected at the FWU; further study of its locations, timing, and magnitude was needed to deduce the nature of the changing stress state. The results of the study revealed that microseismic events were successfully modeled within the Morrow B formation. Moment magnitudes of seismic events were within the same magnitudes for events in the reservoir, suggesting the suitability of the model. The results of the study showed that the computed moment magnitudes for seismic events were insignificant to warrant safety concerns. The study findings showed the usefulness of coupled hydromechanical models in predicting the subsurface stress changes associated with CO 2 injection. The knowledge gained from this study will serve as a guideline for industries planning to undertake underground CO 2 storage, and characterize the subsurface stress changes.

Suggested Citation

  • Samuel Appiah Acheampong & William Ampomah & Don Lee & Angus Eastwood-Anaba, 2023. "Coupled Hydromechanical Modeling and Assessment of Induced Seismicity at FWU: Utilizing Time-Lapse VSP and Microseismic Data," Energies, MDPI, vol. 16(10), pages 1-24, May.
    • Handle: RePEc:gam:jeners:v:16:y:2023:i:10:p:4163-:d:1149798
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    References listed on IDEAS

    as
    1. Martha Cather & Dylan Rose-Coss & Sara Gallagher & Natasha Trujillo & Steven Cather & Robert Spencer Hollingworth & Peter Mozley & Ryan J. Leary, 2021. "Deposition, Diagenesis, and Sequence Stratigraphy of the Pennsylvanian Morrowan and Atokan Intervals at Farnsworth Unit," Energies, MDPI, vol. 14(4), pages 1-26, February.
    2. Jonathan Asante & William Ampomah & Dylan Rose-Coss & Martha Cather & Robert Balch, 2021. "Probabilistic Assessment and Uncertainty Analysis of CO 2 Storage Capacity of the Morrow B Sandstone—Farnsworth Field Unit," Energies, MDPI, vol. 14(22), pages 1-19, November.
    3. Robert Will & Tom Bratton & William Ampomah & Samuel Acheampong & Martha Cather & Robert Balch, 2021. "Time-Lapse Integration at FWU: Fluids, Rock Physics, Numerical Model Integration, and Field Data Comparison," Energies, MDPI, vol. 14(17), pages 1-24, September.
    4. Nathan Moodie & William Ampomah & Wei Jia & Brian McPherson, 2021. "Relative Permeability: A Critical Parameter in Numerical Simulations of Multiphase Flow in Porous Media," Energies, MDPI, vol. 14(9), pages 1-14, April.
    5. Lindsey Rasmussen & Tianguang Fan & Alex Rinehart & Andrew Luhmann & William Ampomah & Thomas Dewers & Jason Heath & Martha Cather & Reid Grigg, 2019. "Carbon Storage and Enhanced Oil Recovery in Pennsylvanian Morrow Formation Clastic Reservoirs: Controls on Oil–Brine and Oil–CO 2 Relative Permeability from Diagenetic Heterogeneity and Evolving Wetta," Energies, MDPI, vol. 12(19), pages 1-33, September.
    6. Ting Xiao & Brian McPherson & Richard Esser & Wei Jia & Zhenxue Dai & Shaoping Chu & Feng Pan & Hari Viswanathan, 2020. "Chemical Impacts of Potential CO 2 and Brine Leakage on Groundwater Quality with Quantitative Risk Assessment: A Case Study of the Farnsworth Unit," Energies, MDPI, vol. 13(24), pages 1-14, December.
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    Cited by:

    1. Xiao, Ting & Chen, Ting & Ma, Zhiwei & Tian, Hailong & Meguerdijian, Saro & Chen, Bailian & Pawar, Rajesh & Huang, Lianjie & Xu, Tianfu & Cather, Martha & McPherson, Brian, 2024. "A review of risk and uncertainty assessment for geologic carbon storage," Renewable and Sustainable Energy Reviews, Elsevier, vol. 189(PB).

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