CMG WinProp Tutorial.pdf

7/16/2019 CMG WinProp Tutorial.pdf

http://slidepdf.com/reader/full/cmg-winprop-tutorialpdf 1/21

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Building, Running and Analyzing

Different Types of Fluid Models

(Dry Gas, Wet Gas, Gas Condensate)

(Volatile Oil, Black Oil, Heavy Oil)

Using

WinProp



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Exercise 1 (Required File: Five Fluid Types Data.xls)

Objective: Modelling of five fluid type i.e. Dry gas, wet gas, Gas condensate, volatile oil

and Black oil.

1. Double click on the WinProp icon in the Launcher and open the WinProp

interface.

2. Double click on “Titles/EOS/Units” and write “Dry gas/Wet gas/Gas

condensate/Volatile oil/Black oil” in the comments and the Title1 section

depending on the case you are modelling. Select PR 1978 and the equation of state to be used in characterizing the fluid model, select “Psia & deg F” as the

units and Feed as mole. Click “OK”.

3. Open “component selection” form and insert the library components in the

following order: CO2, N2, C1, C2, C3, IC4, NC4, IC5, NC5, and FC6. (The order

of selection in important!).

4. In all cases except “Dry Gas” also, characterize the C7+

fraction with a single

pseudocomponent by inserting a user defined component. Click on “options” button in the “component definition form” and select “insert own component”

based on specific gravity (SG), boiling point (TB) and molecular weight (MW).

Use the properties given in the file: “Five Fluid Types Data.xls”. Your component definition form should look like Figure1 for Dry gas and Figure 2 in

case of other fluid types.

Figure1: Component definition for case of Dry Gas



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5. Open the "composition form" and input the mole fractions of the primary

composition as mentioned in the file: “Five Fluid Types Data.xls”. The“secondary” corresponds to the injection fluid (if applicable).

6. Insert “two phase flash calculation form" into the WinProp interface. Open this

form by double clicking on it and under the comments section type “Standardcondition flash”. We are planning to perform a flash at 14.7 Psia and 60 deg.F.

Leave other calculation options as default. The feed composition is subjected to

mixed i.e. primary and secondary composition. The “two-phase flash calculationform should look like as shown in Figure 3.

7. Insert “Saturation pressure calculation Form" into the WinProp Interface to perform a saturation pressure calculation at the reservoir temperature.

8. Double click and open the saturation pressure calculation form. Under the commentstype “Psat at reservoir temperature”. Also, input the reservoir temperature and

saturation pressure estimate as 180 ºF and 1000 Psia respectively. The input valueof “saturation pressure estimate” is used as an initial guess by WinProp during the

iteration processes for calculating the actual saturation pressure.

9. We would also like to generate a pressure-temperature phase diagram. Insert a

“two-phase Envelope” form in the Main WinProp interface. Open the form bydouble clicking on it and type in “P-T envelope” under the comments section.

Input the data as shown in Figure 4.

Figure 2: Component definition for other fluid types



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Figure 3: Two phase flash calculation at standard condition.

Figure 4: Input data for two-phase envelop calculation.



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10. Create plots of phase properties vs. pressure at the reservoir temperature using the

2-phase flash calculation. Examples of properties which may be plotted are: Z-factors, phase fractions, densities, molecular weights, K-values, etc. This can be

done by adding another Two-phase Flash calculation from. Type in comments as

“Phase properties as function of pressure”. Input the reservoir temperature as 180

deg F, temperature step as 0 and No. of temperature step as 1. Input the reservoir pressure as 250 Psia, pressure step of 250 Psia and No. of pressure steps as 12 for

dry and wet gas case whereas 24 for gas condensate, volatile oil and black oil.

The reservoir temperature would also change depending on the case you aremodelling as mentioned in the file: “Five Fluid Types Data.xls”

11. In the plot control tab of “two-phase calculation” form select the properties

depending on the case as follows:

No. Case Plot Property1 Dry Gas Z compressibility factor 2 Wet gas

Z compressibility factor 3 Gas Condensate, Volatile Oil & Black oil Phase volume fraction,

Z factor, K-values (y/x)

12. For all the oil cases, add a single-stage separator calculation with separator pressure of 100 psia and separator temperature of 75 F.

13. The final WinProp interface should look like Figure 5.

Figure 5: WinProp interface for modeling Dry Gas case.



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14. Save the WinProp file as ‘drygas.dat’ and run it

15. Repeat Items 1 to 14 and build a dat file for other types of fluid and save them as

‘wetgas.dat’, ‘gascondensate.dat’, ‘volatileoil.dat’, ‘blackoil.dat’ files

respectively and then run.

Note: You are now able to analyze the results in terms of the criteria for definition of

each of the fluid types. The plots for different cases are shown in Figures 6 to 14.

Dry Gas

P-T envelope : P-T Diagram

0

200

400

600

800

1000

1200

1400

-100.0 -80.0 -60.0 -40.0 -20.0 0.0 20.0

Temper ature (deg F)

P r e s s u r e ( p s i a )

2-Phase boundary Critical

Figure 6: 2-Phase P-T diagram for Dry Gas case.

Dry Gas

Phase proper ties as fn(P) : Phase Properties (Solvent

Mole Fraction = 0.0000)

0.84

0.86

0.88

0.90

0.92

0.94

0.96

0.98

0 500 1000 1500 2000 2500 3000 3500

Pressure (psia)

V a p o r Z - F a c t o r

180.00 deg F

Figure 7: Vapor Z factor for Dry gas case.



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Wet gas


0

500

1000

1500

2000

2500

3000

-100 -50 0 50 100 150 200 250



2-Phase boundary

Figure 8: 2-Phase P-T diagram for Wet Gas case.

Wet gas



0.90

0.92

0.94

0.96

0.98

0 500 1000 1500 2000 2500 3000 3500

Pressure (psia)

V a p o r Z - F

a c t o r

220.00 deg F

Figure 9: Vapor Z factor for wet gas case



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Gas condensate


0

2,000

4,000

6,000

8,000

10,000

12,000

-100 0 100 200 300 400 500 600




Figure 10: 2-Phase P-T diagram for Gas condensate case.

Gas condensate

Phase properties as fn(P) : Phase Properties (Solvent


0.0

5.0

10.0

15.0

20.0

25.0

30.0

35.0

0 1000 2000 3000 4000 5000 6000 7000

Pressure (psia)

L i q u i d P h a s e V o l u m e %

280.00 deg F

Gas condensate



65

70

75

80

85

90

95

100

105

0 1000 2000 3000 4000 5000 6000 7000

Pressure (psia)

V a p o r P h a s e V o l u m e %

280.00 deg F

Gas condensate



0.00

0.20

0.40

0.60

0.80

1.00

1.20

0 1000 2000 3000 4000 5000 6000 7000

Pressure (psia)

L i q u i d Z - F a c t o r

280.00 deg F

Gas condensate



0.90

0.95

1.00

1.05

1.10

1.15

0 1000 2000 3000 4000 5000 6000 7000

Pressure (psia)

V a p o r Z - F a c t o r

280.00 deg F

Figure 11: Phase volume fractions and Z factors for gas condensate



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Gas condensate



1.00E-03

1.00E-02

1.00E-01

1.00E+00

1.00E+01

1.00E+02

0 1000 2000 3000 4000 5000 6000 7000

Pressure (psia)

K v a l . ( v a p o r / l

i q . )

( T e m p e r a t u r e = 2 8

0 . 0

0

d e g F )

CO2 N2 C1 C2 C3 IC4 NC4

IC5 NC5 FC6 C7+

Figure 12: K value for gas condensate case.

Volatile oil


0

5,000

10,000

15,000

20,000

-200 0 200 400 600 800




Figure 13: 2-Phase P-T diagram for Volatile oil case.



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Black oil


0

500

1000

1500

2000

2500

3000

-200 0 200 400 600 800 1000 1200




.

Figure 14: 2-Phase P-T diagram for Black oil case.

Additional Practice:

For the black oil data case, investigate the effect on the simulated separator calculation induced by changing the following parameters:

• Apply the volume shift correlations

• Set the hydrocarbon binary interaction parameters to zero

• Reduce the C7+ Pc by 20%

16. To set volume shift to correlations, double click ‘Component

Selection/Properties’ and click on ‘VolumeShift’ tab, choose ‘Reset to

correlation values’ then save as 'blackoil1_volshift correlation value.dat' file. Go

back to the VolumeShift tab again and click on "Reset to Zero's" and save as

'blackoil1_volshift set to zer.dat' file. Run both data files and compare the resultson Separator calculation. It should look like to the following outputs:

Separator output with Volshift set to zero:

Oil FVF = vol of saturated oil at 2877.86 psia and 170.0 deg F per vol of stock

tank oil at STC(4) = 1.111 API gravity of stock tank oil at STC(4) = 58.10

Separator output with Volshift set to correlation value:

Oil FVF = vol of saturated oil at 2877.86 psia and 170.0 deg F per vol of stock tank oil at STC(4) = 1.137

API gravity of stock tank oil at STC(4) = 32.77



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17. Open ‘blackoil.dat’ again and set hydrocarbon binary interaction parameter to

zero, by double clicking at ‘Component Selection/Properties’ . Click on ‘Int.

Coef.’ tab and click on ‘HC-HC Group / Apply value to multiple non HC-HC

pair…’ Check on 'HC-HC' and change Exponent value to zero and press 'OK'

twice. Save as a new name and see the result at Separator calculation. It should be

like following:

Oil FVF = vol of saturated oil at 2027.10 psia and 170.0 deg F per vol of stock

tank oil at STC(4)= 1.115 API gravity of stock tank oil at STC(4) = 58.15.

18. To reduce the C7+ Pc by 20%, double click ‘Component Selection/Properties’

and change the Pc value of C7+ to 12.36 and see the result again it should be

like:( make sure to save the file in new name).

Oil FVF = vol of saturated oil at 2142.23 psia and 170.0 deg F per vol of stock tank oil at STC(4) = 1.100

API gravity of stock tank oil at STC(4) =104.78



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WinProp Exercise 2

Objective: To determine the MMP and MME for a rich gas injection flood into the

reservoir (Like CO2 Flooding)

Starting with the black oil data set from Exercise 1, create P-X phase diagrams at the

reservoir temperature for the following injection fluids:

1. Addition of secondary stream with the following compositions:

• Pure N2

• Pure CO2

• Dry gas (from Exercise 1)

• A rich gas stream with the composition (in mole %):

CO2 1.4 N2 1.0

C1 33.2C2 23.3

C3 25.3

IC4 3.8 NC4 9.6

IC5 2.1

NC5 0.3

The required forms and their arrangement of the calculation options in WinProp interface

should look like as shown in Figure 15 for this case. Save this file as

‘blackoil_richgas_MMP_MME.dat’

Figure 15: Addition of solvents in black oil and calculation of MMP and MME



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2. Run a multi-contact miscibility calculation to determine the MMP for pure richgas injection. Insert a Multiple-contact miscibility calculation form and input the

data shown in Figures 16 and 17 presented below.

Figure 16: Input data for calculation of MMP.

Figure 17: Rich gas (make-up gas) composition for calculation of MMP .



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Analyze the output file for results of single contact miscibility and multi-contact

miscibility pressures and mole fraction of make-up gas.

SUMMARY OF MULTI PLE CONTACT MI SCI BI LI TY i n *. OUT f i l e

CALCULATI ONS AT TEMPERATURE = 170. 000 deg F

______________________________________________

FI RST CONTACT MI SCI BI LI TY ACHI EVEDAT PRESSURE 0. 49800E+04 Psi aMAKE UP GAS MOLE FRACTI ON = 0. 10000E+01

MULTI PLE CONTACT MI SCI BI LI TY ACHI EVEDAT PRESSURE = 0. 38400E+04 Psi aMAKE UP GAS MOLE FRACTI ON = 0. 10000E+01BY BACKWARD CONTACTS - CONDENSI NG GAS DRI VE

3. Run a multi-contact miscibility calculation to determine the minimum amount of richgas necessary to add to the dry gas to achieve miscibility at 4500 psi (MME calculation).

For this insert the “Multiple-contact miscibility calculation” form and input the following parameters. Notice that in this case only one pressure value is used at which themiscibility is desired. In the composition form the starting point for the make-up gas

fraction is from 50%.

Figure 18: Input data for calculation of MME calculation.



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Figure 19: Rich gas (make-up gas) composition for calculation of MME .

Analyze the output file for results of single contact miscibility and multi-contact

miscibility pressures and mole fraction of make-up gas.

SUMMARY OF RI CH GAS MME CALCULATI ONS AT TEMPERATURE = 170. 000 deg F

FI RST CONTACT MI SCI BI LI TY PRESSURE( FCM) I S GREATER THAN 0. 45000E+04 psi a

MULTI PLE CONTACT MI SCI BI LI TY ACHI EVEDAT PRESSURE = 0. 45000E+04 psi aMAKE UP GAS MOLE FRACTI ON = 0. 92000E+00BY BACKWARD CONTACTS - CONDENSI NG GAS DRI VE



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Exercise 3: Raleigh Oil(Required File: Raleigh black oil-data.xls)

Objective: Plus fraction splitting, matching experimental constant compositionexpansion, separator test and differential liberation tests.

1. Initialize WinProp through CMG launcher.

2. Insert a title: “plus fraction characterization” and select PR (1978), Psia & deg

F, feed as moles in the “specify titles, EOS and unit system” form.

3. In the component selection/Properties form add the following library

components and compositions as given in the file: “Raleigh black oil-data.xls”.

Figure 20: black oil composition for Raleigh oil.

4. To split the C7+ fraction into pseudocomponents; double click on “Plus fraction

Splitting" form. on "General" Tab; Specify Gamma distribution function, 4 pseudocomponents, The first single carbon number in plus fraction as7 and leave

others as default Go to "Sample 1" Tab.



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Figure 21: Plus fraction splitting for Raleigh Oil.

5. Input the MW+ as 190, SG+ as 0.8150 and Z+ (mole fraction of C7+ fraction)

as 0.2891. Make sure alpha is equal to 1.

6. Save the dataset as ‘raleigh oil.dat’ and run it. After running the data set, use the

“Update component properties” in the File menu. And save the data set as

‘raleigh oil_plus fraction splitting.dat’. You will now notice that 4 hypothetical

pseudo components have been added in the components form.

7. In order to match the CCE, Differential liberation and separator test, use the datagiven in the file “Raleigh black oil-data1.xls”. then open "Saturation Pressure",

"constant composition expansion", "separator" "differential liberation" forms in sequence. Input the experimental data given in the file “Raleigh black

oil-data1.xls”.( you can also input all above forms, from another WinPropdataset).

8. On the “Component Selection/properties” form, set the volume shifts to thecorrelation values. Save your model as ‘raleigh oil_experimental data.dat’ and run

it once to validate your model and check for errors in the input data.



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9. Click on Regression /start on top menu and open Open "Regression

Parameters" form before "Saturation Pressure" form( before any regressioncalculation) and insert " End Regression " form at end(after all forms that are

supposed to be included in regression process, i.e. CCE, Saturation Pressure,

Differential Liberation and Separator ). This defines the “Regression Block.”

10. Select the heaviest pseudocomponent’s Pc and Tc, volume shifts of all C7+

pseudocomponents and C1, and the hydrocarbon interaction coefficient exponent

as regression variables. Set the convergence tolerance to 1.0E-06 in "RegressionControls" tab and then save and run the data set.

Figure 22: Regression control for experimental data matching.

11. Adjust the weight of some key experimental data points. Try setting the weight

for separator API gravity to 5.0, saturation pressure to 10.0, and differentialliberation API gravity at std conditions to 0.0. Re-run the regression.

12. In some cases, you may have to change the lower and upper bounds of theregression parameters depending on whether these bounds are reached during the

regression. In this case the following bounds were used:



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Figure 23: Variable bounds used during the regression.

13. Analyze the *.out file and refer to the summary of Regression Results for

comparison of the experimental versus calculated values.

14. After completing the match to the PVT data, update the component properties andagain save the file under a new name as ‘raleigh oil_experimental data_vis.dat’ in

preparation for viscosity matching.

15. For viscosity matching, temporarily exclude the saturation pressure, constantcomposition expansion and separator calculations from the data set by right-

clicking on each option and selecting “Exclude” from the pop-up menu.

16. In the "Differential Liberation" form, set the weight for the viscosity data to

1.0, and all other weights to 0.0.

17. On the viscosity parameters tab of the "Regression Parameters" form, remove

all previously selected parameters, and then select “Vc, vis(l/mol)” for C1 and the

C7+ pseudo components as regression variables. Run the data set.

18. After completing the match to the viscosity data, update the component propertiesand save the file under a new name ‘raleigh oil_Blackoil PVT.dat’ in preparationfor generating the IMEX PVT table.

19. Remove the regression forms and include any options that had previously beenexcluded. Add a “Black Oil PVT Data” option at the end of the data set.



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20. On the ‘Black Oil PVT Data’ form, enter the saturation pressure data, desired

pressure levels and the separator data. Enter mole fractions of 0.1, 0.2 and 0.3 for the swelling data.

Figure 24: Black oil PVT export for IMEX.

Figure 25: Pressure levels for back oil PVT



Figure 26: Water properties for back oil PVT

21. Leave the “Oil Properties” controls at the defaults, and then select “Use solutiongas composition…” for the swelling fluid specification on the “gas properties”

tab. Run the data set.

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CMG WinProp Tutorial.pdf