pre-injection reservoir modeling and uncertainty study … · 2011-12-13 · pre-injection...

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  • Pre-Injection Reservoir Modeling and Uncertainty Study for Illinois Basin-Decatur Project Ozgur Senel (Schlumberger Carbon Services) Nikita Chugunov (Schlumberger - Doll Research)

  • 2011 Schlumberger. All rights reserved. An asterisk is used throughout this presentation to denote a mark of Schlumberger. Other company, product, and service names are the properties of their respective owners.

  • Outline

    Introduction Reservoir Model Workflow Upscaling Reservoir Model Calibration Base Case

    Uncertainty Analysis Wellbore Pressures and CO2 Mass Partitioning Reservoir Scale: Plume and Pressure Pulse Extent Verification Well: Westbay* multilevel groundwater characterization

    and monitoring system responses

  • Introduction

    2800 ft

    STRAT COLUMN OF THE ILLINOIS BASIN

    2800 ft

    Injector

    Verification

  • Workflow

    Seismic Data

    Seismic Data Attribute Analysis

    Petrophysics

    Geological Model

    Facies Model

    Porosity Model

    Permeability Model

    Upscaling

    Predictive Reservoir Simulations

    Uncertainty Analysis

  • Upscaling

    Geological Model:

    1298 1308 534 ~ 906M Cells

    150 150 ft cells Reservoir Model:

    20 20 mile 143 143 148

    ~ 3M Cells

    50ft to 1500ft lateral cells

    Static Model Upscaled Model

    Eau Claire

    Mount Simon

  • Water Injection/Fall Off Test Reservoir Model Calibration

    Reservoir Model calibrated on skin and global permeability

    multiplier.

    Time, days

    0 1 2 3 4 5

    Pres

    sure

    , psi

    3000

    32

    00

    3400

    36

    00

    3800

    40

    00

    4200

    44

    00

    4600

  • Base Case - Simulation Results

  • Injection Rate & Pressure Profiles

    Injection Ramp-Up Time

    7 Days

    Time, years

    0 1 2 3 4 5

    Pres

    sure

    , psi

    C

    O2 Flow

    Rate, M

    t/d

    Injection Pressure & Rate Profile 80

    0 12

    00

    1600

    20

    00

    2400

    28

    00

    3200

    36

    00

    4000

    Wellhead Pressure

    Bottomhole Pressure

    Injection Rate

    Fracturing Pressure ~ 5025 psig at 7025 ft

    0 500

    1000

  • CO2 Mass Partitioning

    0

    10

    20

    30

    40

    50

    60

    70

    80

    90

    100

    0 10 20 30 40 50 60 70 80 90 100

    Mas

    s Fr

    actio

    n, %

    Time, years

    CO2 Mass Partitioning

    Unbounded, %

    Trapped, %

    Dissolved, %

  • IBDP - CO2 Plume & Pressure Pulse Evolution

    50 Years

  • Pressure - Saturation Plume Evolution

    0

    100

    200

    300

    400

    500

    600

    700

    0 1 2 3 4

    Rad

    ius,

    ft

    Time, Years

    Equivalent Radius of 184 psi Pulse

    Pressure Pulse Radius

    0

    75

    150

    225

    300

    0 10 20 30 40 50 60 70 80 90 100

    Are

    a, a

    cres

    Time, Years

    CO2 Plume Area

    IBDP

  • Uncertainty Analysis

  • Input Parameters

    Parameter Distribution-Range

    Number of Realizations 128

    Residual H2O Saturation (Swr) Uniform(0.15, 0.55)

    Residual CO2 Saturation (Sgr) Uniform(0.05, 0.30)

    CO2 Relative Permeability @ Swr Uniform(0.30, 0.70)

    kv/kh Reservoir Unit Uniform(0.20, 0.70)

    kv/kh Non-Reservoir Unit Uniform(0.01, 0.05)

    Upper Perforation Skin Uniform(-0.7, 0)

    Lower Perforation Skin Uniform(-0.7, -1.4)

  • Output Parameters

    Injection Ramp-Up Time Injector & Verification Well Bottomhole Pressures Injector Tubing Head Pressure CO2 Mass Partitioning CO2 Saturation Plume & Pressure Pulse Development Westbay Saturation & Pressure Profiles

  • 0

    0.1

    0.2

    0.3

    0.4

    0.5

    0.6

    0.7

    0.8

    0.9

    1

    0 50 100 150 200 250 300 350

    2nd Analysis

    Time, Days

    Injection Rate Ramp-Up Time

    Cum

    ulat

    ive

    Prob

    abili

    ty

    CDF

    Injection Ramp-Up Time

    P10: 10 days P50: 22 days P90: 80 days

    Best Case: 5 days

    Worst Case: 307 days

  • 1600

    1700

    1800

    1900

    0 1 2 3 4 5

    Pres

    sure

    , psi

    a

    Time, years

    Base

    P10

    P50

    P90

    3000

    3200

    3400

    3600

    3800

    4000

    0 1 2 3 4 5

    Pres

    sure

    , psi

    Time, Years

    Base Case

    P10

    P50

    P90

    Pressure Profiles

    Injector Wellhead Pressure (120F)

    Injector Bottomhole Pressure

    Compression capacity is 2000psi

    Verification Bottomhole Pressure

    Max injection bottomhole pressure is 80% of fracturing pressure

    3200

    3250

    3300

    3350

    3400

    0 1 2 3 4 5

    Pres

    sure

    , psi

    Time, years

    Base Case

    P10

    P50

    P90

    1600

    1700

    1800

    1900

    0 1 2 3 4 5

    Pres

    sure

    , psi

    a

    Time, years

    Base

    P10

    P50

    P90

    1550

    1350

    1450

    1250

    Injector Wellhead Pressure (90F)

  • 0

    0.2

    0.4

    0.6

    0.8

    1

    0 10 20 30 40 50

    Mas

    s, F

    ract

    ion

    Time, Years

    Trapped CO2 P10

    P50

    P90

    Base

    0

    0.1

    0.2

    0.3

    0.4

    0.5

    0.6

    0 10 20 30 40 50

    Mas

    s, F

    ract

    ion

    Time, Years

    Dissolved CO2

    P10

    P50

    P90

    Base

    CO2 Mass Partitioning

    0

    0.2

    0.4

    0.6

    0.8

    1

    0 10 20 30 40 50

    Mas

    s, F

    ract

    ion

    Time, Years

    Unbounded CO2 P10

    P50

    P90

    Base

  • Pressure Profile at Verification Well

    Color-profile indicates the probability of P at a given depth along verification well.

  • Pressure Profile at Verification Well

    Color-profile indicates the probability of P at a given depth along verification well.

  • CO2 Saturation Profile at Verification Well

    Color-profile indicates the probability of CO2 saturation at a given depth along verification well.

  • Concluding Remarks

    Reservoir model consistent with all available data Injection rate ramp-up time (P10-P90): 10 - 80 days CO2 mass partitioning (P10-P90): 15 - 25% CO2 dissolved by 2062 40 - 65% CO2 residually trapped by 2062

    Plume containment and Area of Review (AOR): No vertical migration above 6,350 ft Spatial extent (P10-P90): 134.5 - 254 Acres by 2062 (N-NW) AOR (P10-P90): 450 - 630 ft radius during injection (P = 184psi)

    Verification well: probability estimates for Westbay responses

  • CO2 Injection in a Saline Formation: Pre-Injection Reservoir Modeling and Uncertainty Study for Illinois Basin-Decatur Project

    Ozgur Senel (Schlumberger Carbon Services)

    Nikita Chugunov (Schlumberger - Doll Research)