Engineer Your Gas/Condensate Systems, Reservoir to Sales Meter
39
SPE DISTINGUISHED LECTURER SERIES is funded principally through a grant of the SPE FOUNDATION The Society gratefully acknowledges those companies that support the program by allowing their professionals to participate as Lecturers. And special thanks to The American Institute of Mining, Metallurgical, and Petroleum Engineers (AIME) for their contribution to the program.
Transcript of Engineer Your Gas/Condensate Systems, Reservoir to Sales Meter
Microsoft PowerPoint - SPE_DL_Kabir.pptthrough a grant of the
SPE FOUNDATION The Society gratefully acknowledges
those companies that support the program by allowing their professionals
to participate as Lecturers.
And special thanks to The American Institute of Mining, Metallurgical, and Petroleum Engineers (AIME) for their contribution to the program.
Engineer Your Gas-Condensate Systems, Reservoir to Sales Meter
Shah Kabir Chevron Energy Technology Company
SPE 95531, 95528, 89753, 89754, 100384
Presentation Outline
• Reserves & Consumption of Natural Gas • Useful Correlations for RF and Gas Cycling • Simple Simulator: Well Count • Coupled Modeling w/Economics: Pipe Size • Real-Time Reservoir Management • Concluding Remarks
Distribution of Proved Natural Gas Reserves (%) in 2004 NA
ME Russia
Natural Gas Production (billion cubic metres ), 1970-2004 Source: UNCTAD based, June 2005
NA
Russia
> 2 1.5- 2 1- 1.5
0.5 - 1 0 – 0.5
100
75
Dry Gas
krg
Gas RF: Low-Perm, Low-Yield Scenario Effect of Perforated Length
10 md, 45 STB/MMscf
R 2 = 0.941
Observed Gas RF, %
Correlation Gas RF, %
RF = 46.682 + 0.585*Perm - 0.091*Yield - 1.448*Skin + 42.51*Perf Int
- 0.00135*Perm2 + 0.003772*Perm*Skin...
(after SPE 95531, 2005)
0
4
8
12
16
to Dry Gas (%)
RF = 57.605 + 0.16*Perm - 0.014*Yield – 0.00014*Perm2 - 0.000146*Yield2
178
110
45
(after SPE 95531, 2005)
Recovery Factor Correlation to Evaluate Potential Cycling Candidates
RF = 0.459 – 0.00067*Yield – 0.00004*Perm - 0.355*VRR – 0.028*PID + 0.277*VRR*PID
Observed Cond. RF
Predicted Cond. RF
0
10
20
30
40
Producer-Injector Distance (km)
Incr. Cond. RF (%)
Inc. RF (%) = 8.532 - 0.0057*Perm - 37.14*VRR - 3.44*PID + 28.52*VRR*PID
F-02 J-02
• Impairment Severe for Low-Perm, High-Yield Systems • Completion Issues Important in Low-Perm Systems
Summary
• PID > 2.5 km
Gas Supply Network for an LNG Plant
• Well Count
• Pipe Dia
W -10
0
3,000
6,000
9,000
12,000
Measured p wf , psig
R2 = 0.9936
Homogeneous Model’s Performance in Gas/Condensate Wells
167 Tests
Comparison of MB & FD Solutions
0
2,000
4,000
6,000
8,000
Date
0
25
50
75
100
5,115 67 187 0.097
2,770 30 30 0.0112
OGIP Ratio
Performance Comparison of Completion Scenarios
0
150
300
450
Cum Gas Bscf
Discounted Income Comparison
Specific PerforationIntelligent Commingled
Discounted Gas Income
Intelligent SPC Conventional
Essence of a Simple Simulator
Single-Reservoir, Single-Well, Spreadsheet-Based Simulator • Gas Properties Correlations: Gas Viscosity, Bg, Z-factor, etc • Material-Balance Model • Wellbore Model for Homogeneous Flow
Fluid Properties Reservoir Properties Completion Details
Production Constraints Economic Scenario
Material Balance Wellbore Model
(after SPE 95528, 2005; SPEREE, June 2007)
Reservoir/Fluid Variables OGIP (Bscf) 306 238 586 Initial Pressure (psia) 5,800 5,800 5,800 Reservoir Temperature (F) 241 241 241 Gas Gravity (-) 0.68 0.68 0.68 Reservoir Permeability (md) 6,646 2,894 151 Net Pay (ft) 150 150 200
Reservoir Geometry/ Wellbore Area (acres) 930 930 1,620 Shape factor 30.88 30.88 30.88 Skin 20 20 20 Non-Darcy Coefficient (D/Mscf) 0.00097 0.00097 0.00047 Wellbore Radius (ft) 0.25 0.25 0.25
Production Constraints Imposed Constant Rate (MMscf/D) 140 140 145 No. of wells 1 1 1
Wellbore Model Variables Tubing Inside Diameter (in) 4.95 4.95 4.95 Wellhead Pressure (psig) 1,000 1,000 1,000 Wellhead Temperature (F) 80 80 80 Well depth (ft) 10,000 12,000 10,000 Pipe roughness ratio 0.0018 0.0018 0.0018
Template for a Deterministic Run M-6 M-7 R-1
Deterministic Cumulative Production
28 0
83 0
1,3 80
Cum Production
M-6
M-7
(after SPE 95528, 2005; SPEREE, June 2007)
Well Velocity-Model-derived
Realizations of Depth Surface
100 Depth Surfaces of Manu-6 Top
Small Variation
Large Variation
BscfOGIP, Bscf (after SPE 95528, 2005; SPEREE, June 2007)
CDF
0.0
0.1
0.3
0.5
0.8
1.0
Cum Probability fraction
W -10
Production Profile
$NPV
DPI
(after SPE 95528, 2005; SPEREE, June 2007)
Cum Gas Shows Delivery Certainty
Cum Gas
Cum Liquid Shows Uncertainty Spread
Cum Condensate
0
200
400
600
800
1,000
CDF’s of Various Pipe Combinations 500 LH Sampling
Diff DPI
5
13
21
29
7
15
23
31
9
17
25
33
11
19
27
35
-0.01 0 0.01 -0.01 0 0.01 -0.01 0 0.01 -0.01 0 0.01
CDF
5
1513
1197
1917
27252321
Assessing Reservoir Compartmentalization Issue
Shale-filled channel
This fault probably seals, but only to this point?? #4
#1
(after SPE 100384, 2006)
q g , MMscf/D
(after SPE 100384, 2006)
• CRWS Modeling When Combined w/Economics Allows > Handling Uncertainty in Many Variables
> Understanding Importance of Decision Variable
• Reservoir Compartmentalization Question Answered by Monitoring Pressure and Rate
• Commingled Completion Feasible When Res Volumes Similar
SPE FOUNDATION The Society gratefully acknowledges
those companies that support the program by allowing their professionals
to participate as Lecturers.
And special thanks to The American Institute of Mining, Metallurgical, and Petroleum Engineers (AIME) for their contribution to the program.
Engineer Your Gas-Condensate Systems, Reservoir to Sales Meter
Shah Kabir Chevron Energy Technology Company
SPE 95531, 95528, 89753, 89754, 100384
Presentation Outline
• Reserves & Consumption of Natural Gas • Useful Correlations for RF and Gas Cycling • Simple Simulator: Well Count • Coupled Modeling w/Economics: Pipe Size • Real-Time Reservoir Management • Concluding Remarks
Distribution of Proved Natural Gas Reserves (%) in 2004 NA
ME Russia
Natural Gas Production (billion cubic metres ), 1970-2004 Source: UNCTAD based, June 2005
NA
Russia
> 2 1.5- 2 1- 1.5
0.5 - 1 0 – 0.5
100
75
Dry Gas
krg
Gas RF: Low-Perm, Low-Yield Scenario Effect of Perforated Length
10 md, 45 STB/MMscf
R 2 = 0.941
Observed Gas RF, %
Correlation Gas RF, %
RF = 46.682 + 0.585*Perm - 0.091*Yield - 1.448*Skin + 42.51*Perf Int
- 0.00135*Perm2 + 0.003772*Perm*Skin...
(after SPE 95531, 2005)
0
4
8
12
16
to Dry Gas (%)
RF = 57.605 + 0.16*Perm - 0.014*Yield – 0.00014*Perm2 - 0.000146*Yield2
178
110
45
(after SPE 95531, 2005)
Recovery Factor Correlation to Evaluate Potential Cycling Candidates
RF = 0.459 – 0.00067*Yield – 0.00004*Perm - 0.355*VRR – 0.028*PID + 0.277*VRR*PID
Observed Cond. RF
Predicted Cond. RF
0
10
20
30
40
Producer-Injector Distance (km)
Incr. Cond. RF (%)
Inc. RF (%) = 8.532 - 0.0057*Perm - 37.14*VRR - 3.44*PID + 28.52*VRR*PID
F-02 J-02
• Impairment Severe for Low-Perm, High-Yield Systems • Completion Issues Important in Low-Perm Systems
Summary
• PID > 2.5 km
Gas Supply Network for an LNG Plant
• Well Count
• Pipe Dia
W -10
0
3,000
6,000
9,000
12,000
Measured p wf , psig
R2 = 0.9936
Homogeneous Model’s Performance in Gas/Condensate Wells
167 Tests
Comparison of MB & FD Solutions
0
2,000
4,000
6,000
8,000
Date
0
25
50
75
100
5,115 67 187 0.097
2,770 30 30 0.0112
OGIP Ratio
Performance Comparison of Completion Scenarios
0
150
300
450
Cum Gas Bscf
Discounted Income Comparison
Specific PerforationIntelligent Commingled
Discounted Gas Income
Intelligent SPC Conventional
Essence of a Simple Simulator
Single-Reservoir, Single-Well, Spreadsheet-Based Simulator • Gas Properties Correlations: Gas Viscosity, Bg, Z-factor, etc • Material-Balance Model • Wellbore Model for Homogeneous Flow
Fluid Properties Reservoir Properties Completion Details
Production Constraints Economic Scenario
Material Balance Wellbore Model
(after SPE 95528, 2005; SPEREE, June 2007)
Reservoir/Fluid Variables OGIP (Bscf) 306 238 586 Initial Pressure (psia) 5,800 5,800 5,800 Reservoir Temperature (F) 241 241 241 Gas Gravity (-) 0.68 0.68 0.68 Reservoir Permeability (md) 6,646 2,894 151 Net Pay (ft) 150 150 200
Reservoir Geometry/ Wellbore Area (acres) 930 930 1,620 Shape factor 30.88 30.88 30.88 Skin 20 20 20 Non-Darcy Coefficient (D/Mscf) 0.00097 0.00097 0.00047 Wellbore Radius (ft) 0.25 0.25 0.25
Production Constraints Imposed Constant Rate (MMscf/D) 140 140 145 No. of wells 1 1 1
Wellbore Model Variables Tubing Inside Diameter (in) 4.95 4.95 4.95 Wellhead Pressure (psig) 1,000 1,000 1,000 Wellhead Temperature (F) 80 80 80 Well depth (ft) 10,000 12,000 10,000 Pipe roughness ratio 0.0018 0.0018 0.0018
Template for a Deterministic Run M-6 M-7 R-1
Deterministic Cumulative Production
28 0
83 0
1,3 80
Cum Production
M-6
M-7
(after SPE 95528, 2005; SPEREE, June 2007)
Well Velocity-Model-derived
Realizations of Depth Surface
100 Depth Surfaces of Manu-6 Top
Small Variation
Large Variation
BscfOGIP, Bscf (after SPE 95528, 2005; SPEREE, June 2007)
CDF
0.0
0.1
0.3
0.5
0.8
1.0
Cum Probability fraction
W -10
Production Profile
$NPV
DPI
(after SPE 95528, 2005; SPEREE, June 2007)
Cum Gas Shows Delivery Certainty
Cum Gas
Cum Liquid Shows Uncertainty Spread
Cum Condensate
0
200
400
600
800
1,000
CDF’s of Various Pipe Combinations 500 LH Sampling
Diff DPI
5
13
21
29
7
15
23
31
9
17
25
33
11
19
27
35
-0.01 0 0.01 -0.01 0 0.01 -0.01 0 0.01 -0.01 0 0.01
CDF
5
1513
1197
1917
27252321
Assessing Reservoir Compartmentalization Issue
Shale-filled channel
This fault probably seals, but only to this point?? #4
#1
(after SPE 100384, 2006)
q g , MMscf/D
(after SPE 100384, 2006)
• CRWS Modeling When Combined w/Economics Allows > Handling Uncertainty in Many Variables
> Understanding Importance of Decision Variable
• Reservoir Compartmentalization Question Answered by Monitoring Pressure and Rate
• Commingled Completion Feasible When Res Volumes Similar
