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Question 1 - PVT Tests

Oil Composition

Component

Mol %

r (g/cm3)

MW

Nitrogen

0.49

0.8086

28.013

Methane

21.01

0.2997

16.043

Ethane

2.50

0.3562

30.070

Propane

1.67

0.5070

44.097

Iso-Butane

0.98

0.5629

58.123

N-Butane

1.20

0.5840

58.123

Iso-Pentane

0.67

0.6244

72.150

N-Pentane

1.14

0.6311

72.150

Hexanes

2.91

0.6850

84.000

Heptanes +

67.42

 

 

Heptanes Plus+ Composition

Component

Mol %

r (g/cm3)

MW

Heptanes

4.500

0.7220

96

Octanes

5.710

0.7450

107

Nonanes

5.390

0.7640

121

Decanes

5.740

0.7780

134

Undecanes

5.940

0.7890

156

Heptadecanes

5.010

0.8470

237

Octadecanes

4.750

0.8520

251

Eicosanes Plus

30.380

0.8380

408

Total

67.420

 

 

SEPARATOR FLASH ANALYSIS

Flash Conditions

Gas/Oil

Gas/Oil

Stock Tank

Formation

Separator

Specific

Oil Phase

 

 

Ratio

Ratio

Oil Gravity

Volume

Volume

Gravity of

Density

P

T

scf/bbl

scf/STbbl

at 60 oF

Factor

factor

Flashed Gas

(gm/cc)

psig

oF

(A)

(B)

 

Bofb(C)

(D)

(Air=1)

 

945

266

 

 

 

 

 

 

 

0.7133

200

158

97

 

106

 

 

1.091

0.6682

0.7668

0

122

52

 

54

40.2

1.196

1.032

1.0512

0.7978

 

 

 

Rsfb =

159

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

945

266

 

 

 

 

 

 

 

0.7136

150

158

105

 

114

 

 

1.084

0.6825

0.7693

0

122

42

 

44

40.3

1.194

1.032

1.0833

0.7973

 

 

 

Rsfb =

158

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

945

266

 

 

 

 

 

 

 

0.7137

100

158

114

 

123

 

 

1.076

0.7083

0.7725

0

122

32

 

33

40.4

1.193

1.032

1.0936

0.7969

 

 

 

Rsfb =

156

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

945

266

 

 

 

 

 

 

 

0.7135

50

158

130

 

139

 

 

1.068

0.7672

0.7766

0

122

21

 

21

40.1

1.197

1.032

1.0457

0.7985

 

 

 

Rsfb =

160

 

 

 

 

 

DIFFERENTIAL   VAPORISATION

@ 266 oF

 

 

Solution

Relative

Relative

Oil

Pressure

Gas/Oil

Oil

Total Oil

Density

psig

Ratio

Volume

Volume

gm/cc

 

RsD (A)

BoD (B)

BtD (C)

 

945

167

1.213

1.213

0.7138

400

82

1.174

1.911

0.7259

300

66

1.167

2.319

0.7282

200

50

1.158

3.130

0.7310

100

33

1.147

5.393

0.7350

0

0

1.116

 

0.7447

 

@ 60 oF =

1.000

 

 

a) Find the heptanes + molecular weight and density using a simple ideal mixing rule.

b) Estimate the specific gravity of the gas at standard conditions.

c) Estimate the bubble point pressure given a GOR = 77 scf/stb and Treservoir = 122 oF.

d) Explain the difference between constant volume depletion and differential liberation tests.

e) Estimate the oil and total formation volume factor when the reservoir falls to 500 psi below the bubble point?

f) Physically, what does the Y-factor mean? Why do we use it? Explain its significance with respect to the relative volume? When is the Y-factor = 1?

g) Estimate the oil density at 13.79 bar using correlations.

h) Explain the difference between the results using correlations vs constant volume depletion tests vs separator tests (with details).

Question 2 - Thermodynamics

a) Justify the following equations:

i) (∂lnΦi/∂P) = V¯iR/RT

ii) (∂lnΦ^i/∂T) = -H¯iR/RT2

iii) GR/RT = ΣixilnΦ^i

iv) Σixid lnΦ^i = 0 (at const T, P)

b) Fugacity and fugacity coefficients

For a natural gas, three component system at T = 203oF and P = 5000 psi, estimate the solution fugacities ( f^i ) and fugacity coefficients (Φ^i ) for each component assuming;

component yi 
a) Methane 0.6
b) Ethane 0.22
c) Propane 0.18

i) Estimate the solution fugacities ( f^i ) and fugacity coefficients ( Φ^i ) for each component using the general equation for the fugacity coefficient from the virial equation of state:

1823_Figure1.jpg

ii) Is the above estimation reliable? Why or why not? How do we prove it.

iii) Explain why assuming an ideal solution will give different results.

iv) What is the overall fugacity coefficient and fugacity of the solution?

Bonus: How would you find the virial coefficients (B values) experimentally?

c) The fugacity of pure component can be related rigorously to measurable properties using thermodynamic relations (hint: prove both equalities):

RTlnΦ = v [∂P/∂n - RT/v]dV - RTlnZ + RT(Z-1)(Prausnitz, 1969)

Using the real gas law as PV = ZnRT, prove that the fugacity for a pure compound is

ln Φ = 0P Z-1/P. dP = 1/RT v (RT/v - P) dv + (Z-1) -lnZ

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