SPE-IADC 130324-PP-Multiphase Flow Modeling for N2 Concentric Nitrogen Injection

7/24/2019 SPE-IADC 130324-PP-Multiphase Flow Modeling for N2 Concentric Nitrogen Injection

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SPE/IADC 130324SPE/IADC 130324SPE/IADC 130324SPE/IADC 130324----PPPPPPPPUnderstanding Multiphase FlowUnderstanding Multiphase FlowUnderstanding Multiphase FlowUnderstanding Multiphase Flow

Modeling for NModeling for NModeling for NModeling for N2222Concentric NitrogenConcentric NitrogenConcentric NitrogenConcentric Nitrogen

Injection Through Downhole PressureInjection Through Downhole PressureInjection Through Downhole PressureInjection Through Downhole Pressure

Sensor Data Measurements WhileSensor Data Measurements WhileSensor Data Measurements WhileSensor Data Measurements While

Drilling MPD WellsDrilling MPD WellsDrilling MPD WellsDrilling MPD Wells

Juan C. Beltran, SPE, Corrado Lupo, SPE, Leiro Medina, SPE,

Hermogenes Duno, SPE, Fernando Gallo, SPE, Jose Tang, SPE,

Jimmy Rojas, SPE, Schlumberger-Optimal Pressure Drilling; Efran

Rodrguez, Schlumberger-IPM; Hernn Melgares, Schlumberger-

D&M; Jorge Bedoya, SPE, Gustavo Puerto, SPE, Blade Energy

Partners

SPE/IADC Managed Pressure Drilling and UnderbalancedOperations Conference and Exhibition

Kuala Lumpur, Malaysia2010


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Outline

Reservoir Information

Concentric Annular Injection

Design Considerations & Methodology

Execution

Conclusions


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Reservoir Information

Fractured carbonates and dolomites from

Lower Cretaceous

Common reservoir depths are in the 5550-

5600 meters TVD range

Current Formation pressure = 0.37 g/cc,

3.06 ppg

Original Formation pressure = 0.73 g/cc,6.12 ppg


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Concentric Annular Injection

Rotating FlowHead - RFH Return Line (Inverse Emulsion+ N2 + Cuttings)

Injection Ports ~ 30 m Above 7 " Liner Hanger

Inverse Emulsion + N2 + Cuttings

Nitrogen Injection N2

4 3/4" BHA & 5 7/8" Bit

9"5/8 casing

7 5/8" casing (Tie Back)

N2N2

N2N2

Inverse Emulsion

7" linerLegend

InverseEmulsion

N2

Inverse Emulsion+ Cuttings


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Methodology

Feasibility to reach target pressure.

Optimize injection rate and pressure.

Establish operation parameters.

Ensure adequate hole cleaning and motor or

RSS performance. Identify fluids flow rates required to achieve

the target pressure.

Define the operating envelope for theApplication.

Monitor drilling to determine changes to

operation parameters.


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Planned Vs. Real Data

/"

"

. .


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Operational Window Proposed


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ECD Measured by

Bottomhole Sensor VPWD


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Premises Considered for

Planned Simulator Runs The fluid system was characterized as

inverse emulsion, specifying the density ofthe oil to standard conditions and modified

density.

The model used was OLGAS 1992.

The temperature profile was calculated with

the initial circulation parameters.


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Adjustments Made at

Rigsite in the simulation The modified density of mud was varied and

adjusted manually in the simulator in orderto meet the real density of the mud at

entrance of the system and calibrating the

same value of mud density at the returns.

The real temperature profile provided by

VPWD tool was used to re-input this data tothe simulator.


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Adjustments Made at

Rigsite in the simulation In the BHA section, the real pressure losses

for the downhole tools at different flowvolumes were specified.

The outflow points were specific ascirculation losses points once they

appeared.


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ECD VPWD vs. Wellflo

Simulated ECD


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Conclusions MWD/LWD/VPWD information was received

all the time at surface allowing keepingdirectional control and adjusted the

multiphase simulator runs and calibrations.

Detailed design, modeling and simulations

are keys for success in the application of

concentric casing injection techniques.


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Conclusions VPWD tool allows real-time downhole reading

like internal and annular pressures, on this

way it was possible to perform a comparisonwith the results delivered by the simulator and

adjust and calibrate the model to the real well

conditions.

Continue investigating the best option to

obtain a greater integrity of theMPD/LWD/VPWD signal for low liquid

injection volumes in order to be able to reduce

more the equivalent circulation density (ECD).


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Conclusions Use smaller internal diameter drillpipe, a

different combination of drillstring signalboosters or inclusive the use of small

nitrogen injection volume through the

drillstring, keeping the percentage of gasinto the drillstring as low as possible and

without exceed the limits which can

debilitated or attenuated the MWD/LWD/VPWD signal.


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Thank You

Questions?

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SPE-IADC 130324-PP-Multiphase Flow Modeling for N2 Concentric Nitrogen Injection