Dual-porosity reservoir modeling of the fractured Hanifa reservoir, Abqaiq Field, Saudi Arabia

Luthy, S T

Title: Dual-porosity reservoir modeling of the fractured Hanifa reservoir, Abqaiq Field, Saudi Arabia

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Abstract

Fractures play a significant role in the transmissibility of the Hanifa reservoir at Abqaiq Field. The Hanifa is a Type 2 fractured reservoir characterized by a finely-crystalline carbonate matrix which contains most of the reservoir storage porosity, and a stylolitic fracture system which provides essential permeability. Comparisons of over 5000 fractures identified from core and borehole image data with open-hole log data showed that porosity is negatively correlated with fracture density and mechanical rock strength. From these relationships, it was possible to utilize additional wells where porosity log data was available to calculate fracture densities. These wells were used to generate matrix porosity and permeability as well as fracture density attributes in a 12-sequence, 29-layer geocellular model. The effect of structural curvature on fracture intensity in the reservoir was estimated by mapping the derivative of structural dip. Incorporation of structural curvature explained variations in well test behavior not predicted by initial estimates of fracture density from porosity alone. Resultant fracture permeabilities compared favorably with well-test derived productivity indices. Three-dimensional visualization of model attributes showed that a monotonous and low (<10 md) distribution of matrix-related permeability contrasts sharply with highly variable and relatively high (>50 md) permeabilities of the fracture system.more »« less

Authors:

Luthy, S T ^[1]

Saudi Aramco, Dhahran (Saudi Arabia)

Publication Date:: Tue Dec 31 00:00:00 EST 1996

OSTI Identifier:: 425702

Report Number(s):: CONF-960527-
TRN: 96:004994-0340

Resource Type:: Conference

Resource Relation:: Conference: Annual convention of the American Association of Petroleum Geologists, Inc. and the Society for Sedimentary Geology: global exploration and geotechnology, San Diego, CA (United States), 19-22 May 1996; Other Information: PBD: 1996; Related Information: Is Part Of 1996 AAPG annual convention. Volume 5; PB: 231 p.

Country of Publication:: United States

Language:: English

Subject:: 02 PETROLEUM; SAUDI ARABIA; OIL FIELDS; RESERVOIR ROCK; POROSITY; PETROLEUM; EXPLORATION; PRODUCTION; RESERVOIR ENGINEERING

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                    Luthy, S T. Dual-porosity reservoir modeling of the fractured Hanifa reservoir, Abqaiq Field, Saudi Arabia.  United States: N. p., 1996. 
        Web.

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                    Luthy, S T. Dual-porosity reservoir modeling of the fractured Hanifa reservoir, Abqaiq Field, Saudi Arabia.  United States.

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                    Luthy, S T. 1996.  
        "Dual-porosity reservoir modeling of the fractured Hanifa reservoir, Abqaiq Field, Saudi Arabia".  United States.

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@article{osti_425702,

  title        = {Dual-porosity reservoir modeling of the fractured Hanifa reservoir, Abqaiq Field, Saudi Arabia},

  author       = {Luthy, S T},

  abstractNote = {Fractures play a significant role in the transmissibility of the Hanifa reservoir at Abqaiq Field. The Hanifa is a Type 2 fractured reservoir characterized by a finely-crystalline carbonate matrix which contains most of the reservoir storage porosity, and a stylolitic fracture system which provides essential permeability. Comparisons of over 5000 fractures identified from core and borehole image data with open-hole log data showed that porosity is negatively correlated with fracture density and mechanical rock strength. From these relationships, it was possible to utilize additional wells where porosity log data was available to calculate fracture densities. These wells were used to generate matrix porosity and permeability as well as fracture density attributes in a 12-sequence, 29-layer geocellular model. The effect of structural curvature on fracture intensity in the reservoir was estimated by mapping the derivative of structural dip. Incorporation of structural curvature explained variations in well test behavior not predicted by initial estimates of fracture density from porosity alone. Resultant fracture permeabilities compared favorably with well-test derived productivity indices. Three-dimensional visualization of model attributes showed that a monotonous and low (<10 md) distribution of matrix-related permeability contrasts sharply with highly variable and relatively high (>50 md) permeabilities of the fracture system. Reliability of the geocellular model to predict fracture densities and associated permeabilities has been confirmed by subsequent drilling of high cost horizontal wells, and is being used in reservoir engineering and development drilling planning efforts.},

  doi          = {},

  url          = {https://www.osti.gov/biblio/425702},
  journal      = {},
number       = ,

  volume       = ,

  place        = {United States},

  year         = {Tue Dec 31 00:00:00 EST 1996},

  month        = {Tue Dec 31 00:00:00 EST 1996}

}

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Dual-porosity reservoir modeling of the fractured Hanifa reservoir, Abqaiq Field, Saudi Arabia

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Fractures play a significant role in the transmissibility of the Hanifa reservoir at Abqaiq Field. The Hanifa is a Type 2 fractured reservoir characterized by a finely-crystalline carbonate matrix which contains most of the reservoir storage porosity, and a stylolitic fracture system which provides essential permeability. Comparisons of over 5000 fractures identified from core and borehole image data with open-hole log data showed that porosity is negatively correlated with fracture density and mechanical rock strength. From these relationships, it was possible to utilize additional wells where porosity log data was available to calculate fracture densities. These wells were used tomore »« less
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The Hanifa reservoir at Abqaiq Field, eastern Saudi Arabia, consists of microporous (up to 30% porosity) lime mudstones with low matrix permeability (< 10 md). SEM imagery reveals a crystal framework texture of micro-rhombic calcite crystals with 2-5 {mu}m-sized intercrystalline pore spaces. Fluid transmissibility was preliminarily identified as via fractures as indicated by no stratigraphic predictability to fluid flow, high flow over thin stratigraphic intervals, little relationship between high flow and high porosity intervals, large disparity between core Kh and well-test Kh, and observation offractures in cores and borehole imaging logs front horizontal Hanifa wells. Integration of descriptions from overmore »« less
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