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Title: Numerical simulations of depressurization-induced gas production from an interbedded turbidite gas hydrate-bearing sedimentary section in the offshore India: Site NGHP-02-16 (Area-B)

Abstract

The recent National Gas Hydrate Program Expedition 02 (NGHP-02) identified the existence of gas hydrate-bearing sand reservoirs at a number of sites in the offshore of India including Site NGHP-02-16 in Area-B of the Krishna-Godavari Basin. The architecture of that gas hydrate accumulation is characterized by thin, gas hydrate-bearing, high quality sand layers interbedded with mud layers within a turbidite sedimentary interval. The lowest gas hydrate-bearing layer contacting a thinly-interbedded saline aquifer designates the base of the gas hydrate stability zone (BGHSZ). The proximity of the BGHSZ and the average temperature around 20 °C make the reservoir a favorable target for hydrate destabilization by means of the depressurization method. The results of the reservoir simulations indicate high gas production potential from this marine gas hydrate deposit with manageable concomitant water production using a well completion design that hydraulically isolates layers with water-saturated sands. Using a detailed geological input model, the predicted cumulative gas rates reach ~3.1 × 104 m3/day (~1.1 MMscf/day) after 90 days of continuous depressurization and demonstrate sustained production rates ~3.0 × 104 m3/day (~1.0 MMscf/day) after 5 years of production. The interbedded nature of this gas hydrate occurrence promotes the development of horizontal dissociation interfaces between gasmore » hydrate-bearing sand and mud layers. As a result, non-uniform gas production along the horizontal interfaces becomes a primary determinant of reservoir performance. Simulation cases have been executed to determine the impact of the uncertainty in in situ reservoir permeability and the manner in which intrinsic permeability dynamically changes during dissociation in response to the imposed effective stress increase. Here, the cases based on low initial effective permeability and high sensitivity of compaction to stress result in the least favorable production predictions.« less

Authors:
ORCiD logo [1];  [2]; ORCiD logo [3]; ORCiD logo [4];  [5]; ORCiD logo [2]
  1. National Energy Technology Lab. (NETL), Pittsburgh, PA (United States); AECOM, Pittsburgh, PA (United States)
  2. National Energy Technology Lab. (NETL), Pittsburgh, PA (United States)
  3. National Energy Technology Lab. (NETL), Pittsburgh, PA (United States); Univ. of Pittsburgh, PA (United States)
  4. National Energy Technology Lab. (NETL), Pittsburgh, PA (United States); Rensselaer Polytechnic Inst., Troy, NY (United States)
  5. U.S. Geological Survey, Denver, CO (United States)
Publication Date:
Research Org.:
National Energy Technology Laboratory (NETL), Pittsburgh, PA, Morgantown, WV, and Albany, OR (United States)
Sponsoring Org.:
USDOE
OSTI Identifier:
1607771
Grant/Contract Number:  
FE0004000
Resource Type:
Accepted Manuscript
Journal Name:
Marine and Petroleum Geology
Additional Journal Information:
Journal Volume: 108; Journal Issue: C; Journal ID: ISSN 0264-8172
Publisher:
Elsevier
Country of Publication:
United States
Language:
English
Subject:
58 GEOSCIENCES; gas hydrates; reservoir simulations; marine gas hydrate deposits; India national gas hydrate program

Citation Formats

Myshakin, Evgeniy M., Seol, Yongkoo, Lin, Jeen-Shang, Uchida, Shun, Collett, Timothy S., and Boswell, Ray. Numerical simulations of depressurization-induced gas production from an interbedded turbidite gas hydrate-bearing sedimentary section in the offshore India: Site NGHP-02-16 (Area-B). United States: N. p., 2018. Web. https://doi.org/10.1016/j.marpetgeo.2018.10.047.
Myshakin, Evgeniy M., Seol, Yongkoo, Lin, Jeen-Shang, Uchida, Shun, Collett, Timothy S., & Boswell, Ray. Numerical simulations of depressurization-induced gas production from an interbedded turbidite gas hydrate-bearing sedimentary section in the offshore India: Site NGHP-02-16 (Area-B). United States. https://doi.org/10.1016/j.marpetgeo.2018.10.047
Myshakin, Evgeniy M., Seol, Yongkoo, Lin, Jeen-Shang, Uchida, Shun, Collett, Timothy S., and Boswell, Ray. Mon . "Numerical simulations of depressurization-induced gas production from an interbedded turbidite gas hydrate-bearing sedimentary section in the offshore India: Site NGHP-02-16 (Area-B)". United States. https://doi.org/10.1016/j.marpetgeo.2018.10.047. https://www.osti.gov/servlets/purl/1607771.
@article{osti_1607771,
title = {Numerical simulations of depressurization-induced gas production from an interbedded turbidite gas hydrate-bearing sedimentary section in the offshore India: Site NGHP-02-16 (Area-B)},
author = {Myshakin, Evgeniy M. and Seol, Yongkoo and Lin, Jeen-Shang and Uchida, Shun and Collett, Timothy S. and Boswell, Ray},
abstractNote = {The recent National Gas Hydrate Program Expedition 02 (NGHP-02) identified the existence of gas hydrate-bearing sand reservoirs at a number of sites in the offshore of India including Site NGHP-02-16 in Area-B of the Krishna-Godavari Basin. The architecture of that gas hydrate accumulation is characterized by thin, gas hydrate-bearing, high quality sand layers interbedded with mud layers within a turbidite sedimentary interval. The lowest gas hydrate-bearing layer contacting a thinly-interbedded saline aquifer designates the base of the gas hydrate stability zone (BGHSZ). The proximity of the BGHSZ and the average temperature around 20 °C make the reservoir a favorable target for hydrate destabilization by means of the depressurization method. The results of the reservoir simulations indicate high gas production potential from this marine gas hydrate deposit with manageable concomitant water production using a well completion design that hydraulically isolates layers with water-saturated sands. Using a detailed geological input model, the predicted cumulative gas rates reach ~3.1 × 104 m3/day (~1.1 MMscf/day) after 90 days of continuous depressurization and demonstrate sustained production rates ~3.0 × 104 m3/day (~1.0 MMscf/day) after 5 years of production. The interbedded nature of this gas hydrate occurrence promotes the development of horizontal dissociation interfaces between gas hydrate-bearing sand and mud layers. As a result, non-uniform gas production along the horizontal interfaces becomes a primary determinant of reservoir performance. Simulation cases have been executed to determine the impact of the uncertainty in in situ reservoir permeability and the manner in which intrinsic permeability dynamically changes during dissociation in response to the imposed effective stress increase. Here, the cases based on low initial effective permeability and high sensitivity of compaction to stress result in the least favorable production predictions.},
doi = {10.1016/j.marpetgeo.2018.10.047},
journal = {Marine and Petroleum Geology},
number = C,
volume = 108,
place = {United States},
year = {2018},
month = {10}
}

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