TUTORIAL IPM 9 P-05

Selecting and matching a multiphase flow correlation for an oil well model

OBJECTIVES

DATA

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- Demonstrate the procedure to calibrate a multiphase flow correlation for an oil well model- Use the calibrated model to obtain production rate

Create an oil well model in PROSPER, match the well model with measure data available. Using the calibrated model estimate the water cut at which the naturally flowing well can no longer flow.

This tutorial starts from Tutorial IPM 9 P-04, or use the attached PROSPER file.

PB: (Bubble point)

PVT DATA (Tutorial 04 explains this section)

Variable Value Units

Solution GOR

Oil density

Gas specific gravity

Water Salinity

430

34

0.73

85000

Scf/stb

API

ppm

PVT LAB DATA

Temperature°F

163

163

163

Pressurepsig

2571

2235 *PB

1522

GORScf/Stb

430

430

281

BoRb/stb

1.204

1.209

1.139

μoilCp

0.87

0.84

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IPR DATA

DOWN-HOLE EQUIPMENT DATA

“U” (Overall heat transfer coefficient): 8 BTU/h/ft2/F

Variable Value Units

Reservoir pressure

Reservoir temperature

Water cut

PI (Productivity index)

2405

163

15

4.8

psig

F

%

Stb/day/psi

Measure depthm

Deviation survey Geothermal gradient

True vertical depthm

Temperature°F

0

452

489

665

2885

2902

0

443.4

475.7

601.2

1706.4

1713

80

163

Description

Down-hole equipment

Depthm

IDinch

Xmas tree

Tubing

Restriction

Tubing

Restriction

Tubing

Casing

0

1000

1000

2700

2700

2850

2902

2.992

2.75

2.992

2.441

2.992

6.366

WELL TEST DATA

WELL MATCHING CALIBRATION RESULTS

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The field is under water flooding operation, it is planned to maintain the reservoir actual reservoir pressure, and it is expected and increased water cut production in the near future for this well. Using the calibrated well model and the test well head pressure determine at which water cut the well will not be able to flow naturally.

Variable Value Units

Selected multiphase correlation

Matching Parameter 1

Matching Parameter 2

Flowing bottom hole pressure

Calibrated Productivity indexpsig

stb/d/psi

Date

01/10/09 395 110

WHPPsig

WHT°F

15

Water cut%

2100

Liquid ratestb/day

2700

Gauge depthm

1796

Gauge pressure psig

2405

Reservoir pressurepsig

250

GORscf/stb

Variable Value Units

Water cut %