3- ProCADE Overview

8/9/2019 3- ProCADE Overview

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Copyright 2007, , All rights reserved


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Why use ProCADE?

Determine reservoir properties

Predict future production

Determine economic viability of treatment


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ProCADE

Modules

Water Control Diagnostics

Material Balance / Empirical Decline

Graphical Decline Curve Analysis Multi-Layer Forecasting

Single Layer Forecasting

Economics


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Differential Technology

Multiphase Flow Analysis

Multi and Single-Layer Forecast and Economics

Extensive Well Model Catalog

Complete PVT PackageLogical Analysis Procedure


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Water Control Diagnostics

Qualitative Indication of Water Control Problems

6 JGC


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Material Balance

Sensitivities to Determine:

Initial Reservoir Pressure

Drainage Area / Initial Fluids in

Place

Final Aquifer Influx Rate

Extrapolate Production to Time

or Pressure


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Graphical Decline Analysis

Graphical matching to determine reservoir properties


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Material Balance

Results

Average Reservoir Pressure

Drainage Area

Drive Mechanism Aquifer Influx

Average Reservoir Fluid Saturations


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Models

Unfractured Vertical Well

Blasingame and Fetkovitch Decline Curves

Infinite and Finite Conductivity FracturesAnalysis Options

Manual and Automatic Matching

Decline Curve Forecast


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Outer Boundary Conditions

Vertical Wells

No Flow (Closed Boundary)

Constant Pressure (Aquifer Influx)

Step and Ramp Rate (Water Flood)

Fractured Wells

No Flow Constant Pressure


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Results

Permeability, Mobility, and Skin

Drainage Area and Apparent WB Radius

Initial Fluids in Place Fracture Properties

Half Length

Conductivity


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Production Forecasting

Extensive Catalog of Analytic Reservoir Solutions

Commingled Multi-Layer Forecast

Multiple Time Step Analysis

Variable Inner Boundary Conditions Changing well model with time

Option to Include or Ignore Prod. History


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Forecast Validation


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Economics

Comparative Economic Analysis


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Economics

Comparative Economic Analysis Base Case Vs. Stimulated Case

Multi-Layer Forecasting

Accounts for Price Escalation/De-escalation

Oil and Gas Production

Water Disposal CostsBuilt In Tax Help for 50 States


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Who should use ProCADE?

Internal

DESC / HRT

Candidate Recognition

Special Projects

Sales / DESC / Field Engineers

Use in Conjunction with FracCADE for Design, Forecasting,and Economics


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Who should use ProCADE?

External

Production Engineers

Reservoir Engineers


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The following slides contain

information about the inputs on

the Zone Screen in the General

Inputs Module.


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Partial Completion Pressure Losses

Skin due to partial completion of pay zone

Main pressure losses occurs due to convergence flow

The effect is significant when flow rate is high


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Perforation Pressure Losses

Open Perf Model (McLeod-Brown)

Perforations modeled as small wellbore at a 90o

angle to thecased wellbore

Crushed zone permeability, kp, is a function of reservoir

permeability Underbalanced: kp = 0.6 k

Overbalanced: kp = 0.2 k

Crushed zone thickness is ~0.5 in thick

Phasing not considered in calculation

Gives lowest perforation pressure loss


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McLeod-Brown Model


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Stable Perf Model (Karakas and Tariq)

Developed from finite element modeling of fluid flow to holesin casing

Calculates the apparent radial flow steady state skin effect

due to: Horizontal flow (phasing)

Vertical converging flow

Wellbore configuration Crushed zone

Underbalance/Overbalance setting does not affect

calculation


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Stable Perf Model (Karakas and Tariq)

- User is allowed to specify damaged zone radius and

permeability

- Damaged zone radius can be less or higher than perforation

tunnel length

Gives higher pressure drop than Open Perforation Model


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Collapsed Perf Model

Calculates skin due to perforation being full of formation

sand

Produces highest pressure drop

Neither Phasing nor Underbalance/Overbalance settings

affect calculations


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Vertical Permeability

Vertical or Z-Direction Permeability affects:

Partial Completion Loss calculation

Horizontal Well Performance

Rule of thumb is that vertical permeability is 0.1 to 0.2 timeshorizontal permeability


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Gravel Pack Completion Losses

Correlations are different methods of estimating the inertial flow

coefficient,

McLeod and Saucier were developed specifically for gravel

packing

Cooke was originally developed for non-darcy flow in afracture

Firoozabadi-Katz was originally developed for non-darcy

radial flow Tenneco/Resin Pack is specifically for resin coated

applications


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Gravel Pack Completion Losses

Flow length in gravel is given by:

(Casing ID - Screen OD) / 2

McLeods correlation is a good place to start


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The following slides contain

information about the inputs on

the Reservoir Screen in the

General Inputs Module.


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Oil PVT Correlations

Many choices for Black Oil Reservoirs

Regional Defaults

Mix and match

Optimized settings for Volatile Oil Reservoirs


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Pb - Rsob

Solution Gas-Oil Ratio - Amount of gas that will dissolve in 1

stb of oil when both are at reservoir conditions. (scf/stb) Constant above Pb

Decreases with pressure below Pb

Correlation for Bubble Point and Solution Gas-Oil Ratio at the

Bubble Point

Equation can be re-arranged to solve for Bubble Point orSolution Gas-Oil Ratio at the Bubble Point


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Comparison of Pb - Rsob CorrelationsProCADE Rso Corrleations - Oil

0

50

100

150

200

250

300

350

400

450

0 500 1000 1500 2000 2500 3000 3500 4000 4500

Pressure (psia)

Rso

(scf/bbl)

Glaso

Standing

Petrosky-Farshad

Kartoatmodjo-Schmidt

Bubble Point

Pi=3000 psi

Pb=2000psi

T=180 F

=35 deg API

Tsep=80 F

Psep=100 psi


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Comparison of Bo Correlations

ProCADE FVF Correlations - Oil

1.00

1.05

1.10

1.15

1.20

1.25

1.30

0 500 1000 1500 2000 2500 3000 3500 4000 4500

Pressure (psia)

Bo

(rb/stb)

GlasoStanding

Petrosky-Farshad

Kartoatmodjo-Schmidt

Bubble Point

Pi=3000 psi

Pb=2000psi

T=180 F

=35 deg API

Tsep=80 F

Pse =100 si


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o Correlations

Dead Oil (gas-free) Viscosity is used by all the correlations

except Khan to calculate the viscosity at the Bubble PointThe viscosity at the Bubble Point is used as a reference to

calculate the saturated (PrPb) oil

viscosity


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Comparison of o Correlations

ProCADE Viscosity Correlations - Oil

0.0

0.5

1.0

1.5

2.0

2.5

0 500 1000 1500 2000 2500 3000 3500 4000 4500 5000

Pressure (psia)

Visco

sity(cp)

od = Beal

os = Chew-Connely

=

od = Beggs-Robinson

os = Beggs-Robinson

= -

od = Glaso

os = Kahn

=

Pi=3000 psi

Pb=2000psi

T=180 F=35 deg API

Tsep=80 F

Psep=100 psi

Pi=3000 psi

Pb=2000psi

T=180 F

=35 deg API

Tsep=80 FPsep=100 psi


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Acid Gas Correction

Accounts for the presence of N2, CO2, or H2S in the oil.

Affects calculation of Pb or Rsob

Indirectly affects calculation of Bo

Practical upper limit of ~12% for each component

Referred to as Acid Gas Components because:

H2S Sulfuric Acid

CO2 Carbonic Acid N2 Nitric Acid


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Acid Gas Correction Comparison

ProCADE Acid Gas Correction Correlations

1700

1800

1900

2000

2100

2200

2300

2400

0 2 4 6 8 10 12

% Composition

Press

ure,psia

Original Bubble Point

Jacobson & Glaso (N2)

Glaso (CO2)

Glaso (H2S)


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Canadian Formation

Formation specific correlations

Cardium/Viking

D2-Nisku

D3-LeducAffects calculation of Pb, Rsob, Bo, and Co

C C l ti


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Co Correlations

39 JGC

ProCADE Compressibility Corrleations - Oil

1.0E-06

1.0E-05

1.0E-04

1.0E-03

1.0E-02

1.0E-01

0 500 1000 1500 2000 2500 3000 3500 4000 4500 5000

Pressure (psia)

Co

(1/psi)

Vasquez-Beggs

Calhoun

Trube

Petrosky-Frashad

Bubble Point

Pi=3000 psi

Pb=2000psi

T=180 F

=35 deg API

Tsep=80 F

Psep=100 psi

R i l D f lt


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Regional Defaults

Automatic settings for:

U.S. Gulf Coast Alaska

California

Mid-Con U.S. North Sea

Saudi Arabia

Western Canada UAE

Nigeria

Colombia General

G PVT C l ti


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Gas PVT Correlations

Required Properties

Reservoir Gas Specific Gravity

Pseudocritical Temperature, TPC

Pseudocritical Pressure, PPC Ideal Gas Law Deviation Factor (Z-Factor)

Bg, g, and Cg

T d P


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TPC and PPC

Natural gas mixture physical properties are correlated using

van der Wals principle of corresponding states.This states that two substances at corresponding conditions,

such as critical temperature and pressure should have similar

physical properties.Research by Kay extended its use to multi-component mixtures

using pseudo critical temperature and pressure.

TPC and PPC have no physical meaning

42 JGC

Z Factor Comparison


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Z-Factor Comparison

ProCADE Z-Factor Comparision

0.5

0.6

0.7

0.8

0.9

1

1.1

0 500 1000 1500 2000 2500 3000 3500 4000 4500

Pressure, psia

Z-F

actor

s.g. = 0.65

s.g. = 0.9s.g. = 1.15

s.g. = 1.4

B Comparison


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Bg Comparison

ProCADE Gas Formation Volume Factor Comparison

0.0001

0.001

0.01

0.1

1

0 500 1000 1500 2000 2500 3000 3500 4000 4500 5000

Pressure, psia

Bg,

rb/scf

s.g. = 0.65

s.g. = 0.9

s.g. = 1.15

s.g. = 1.4

Comparison


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g Comparison

ProCADE Gas Viscosity Comparision

0

0.005

0.01

0.015

0.02

0.025

0.03

0.035

0.04

0.045

0 500 1000 1500 2000 2500 3000 3500 4000 4500 5000

Pressure, psia

Visc

osity,cp

s.g. = 0.65

s.g. = 0.9

s.g. = 1.15

s.g. = 1.4

C Comparison


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Cg Comparison

ProCADE Gas Compressibility Comparision

1.0E-05

1.0E-04

1.0E-03

1.0E-02

1.0E-01

0 500 1000 1500 2000 2500 3000 3500 4000 4500 5000

Pressure, psia

Cg,

1/psia

s.g. = 0.65

s.g. = 0.9

s.g. = 1.15

s.g. = 1.4

Formation Pore Compressibility


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Formation Pore Compressibility

Depends on Porosity and correlation selection

Consolidated Sandstone

Carbonate (Limestone/Dolomite)

Unconsolidated Sandstone

Will be the same for Consolidated and UnconsolidatedSandstone below 20% Porosity

For multiple zones, this is calculated, but not displayed,

based on the porosity in each zone

Can also be user input

One value applies to all zones

Separator Configuration


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Separator Configuration


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The following slides containinformation about the inputs on

the ProdData Screen in the

General Inputs Module.

Wellbore Outflow Correlations


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Used to estimate pressure losses due to fluid flow in the

wellbore (i.e. convert wellhead pressure, Pwh, to bottomholeflowing pressure, Pwf)

Necessary because all reservoir solution procedures in

ProCADE use sandface flowing pressure, Pwfs Pwfs = Pwf+ Completion Losses

Most field production data does not include Pwf, but does

include Pwh



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Multiphase Liquid Flow

Duns and Ros

Orkiszewski

Beggs and Brill

Use when fluid is mostly liquid (oil with some gas)



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Dry Gas Flow

Cullender and Smith

Can handle small amount of liquid (up to 10 bpd)

Multiphase Gas Flow

Hagedorn and Brown

Can also be used as a liquid flow correlation



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When in doubt, try Hagedorn-Brown first

Be sure to check that calculated Pwfdoes not exceed reservoirpressure (Injection!)

Correlations are valid for vertical and deviated wellbores

Beggs and Brill is the most rigorous for deviated wells

Outflow Gas-Liquid Ratio


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Outflow Gas Liquid Ratio

Used for gas lift wells

If non-zero, use total GLR (injected + naturally produced)If set to zero, producing GLR is automatically calculated from

production data

Interpolation Setting


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te po at o Sett g

This setting is not used in the general inputs. It is used by the

forecasting engine in the Super-Position-In-Time calculationswhich account for prior production.

Documents

3- ProCADE Overview