1) Determine the single-phase productivity index (hand calculations). 2) Determine and plot the OPR and IPR curves assum
Posted: Thu May 05, 2022 9:10 am
1) Determine the single-phase productivity index (hand
calculations).
2) Determine and plot the OPR and IPR curves assuming a
horizontal flowline and a vertical tubing with the “Initial Input
Parameters” listed above. Identify the stable and unstable
operational regions. Determine the operating point for these
conditions.
3) Repeat Question #2 with flowline sizes of 2.5 and 3.5 inch
ID. What is the optimum flowline diameter, determining the cost of
the larger flowline and oil revenue?
4) Using the optimum flowline diameter found in Question #3,
repeat Question #2 with tubing sizes of 2, 3, and 3.5 inch ID. What
is the optimum tubing diameter, again considering cost and
revenue?
5) For the optimum flowline and tubing diameter, document the
observed flow regime changes from the bottomhole condition to the
separator.
6) Using the optimum flowline and tubing diameters from
Questions #2 and #3, consider gas injection into the tubing at a
depth of 4,500 ft, with injection rates of 1,000, 2,000, 3,000,
4,000, and 5,000 scf/stbo. The injected gas gravity is 0.68. Plot
IPR and OPR curves with the varying gas injection rates. What is
the optimal gas injection rate? Ignore the cost associated with gas
injection.
7) For the optimum gas lift injection rate and flowline and
tubing diameter, document the observed flow regime changes from the
bottomhole condition to the separator.
INITIAL INPUT PARAMETERS
Oil Specific Gravity: 45 – 2*(birth month) (API)
Water Specific Gravity:1.01
Gas Specific Gravity:0.65
Reservoir Pressure:2,250 +25*(last 2 digits in student ID)
(psig) 1,250 (psig)
Bubble Point Pressure:1,250 (psig)
Test Bottom Hole Flowing Pressure:850 (psig)
Reservoir Pressure at Test Conditions:2,250 (psig)
Test Oil Flowrate:1,500 (stbo/day)
Formation Gas-Oil Ratio:400 (scf/stbo)
Water Cut:0 (%)
Separator Pressure:450 (psig)
Separator Temperature:80 (deg F)
Well Head Pressure:0 (psig)
Well Head Temperature:160 (deg F)
Bottom hole Temperature:220 (deg F)
Bean Choke Size:64 (1/64 in)
Gas Injection Depth:4,500 (ft)
Injection Gas Specific Gravity:0.68
Injection Gas-Oil Ratio:285 (scf/stbo)
Tubing Depth: 4,500 (ft)
Tubing Inner Diameter:3 (in)
Flowline Length:15,000 (ft)
Flowline Angle: 0(deg)
Flowline Inner Diameter: 3 (in)
Solution Gas & Bubble Point Correlation: Kartoatmodjo
Oil Formation Volume Factor Correlation: Kartoatmodjo
Oil Viscosity Correlation: Kartoatmodjo
Z Factor Correlation: Standing
Tubing Pressure Drop Correlation: Beggs – Brill Model
Flowline Pressure Drop Correlation: Beggs – Brill Model
Price of steel: $5 per linear foot per inch of diameter
Example: 10 foot section of 3 inch diameter pipe = |10 𝑓𝑡|
0$2/450 |3 𝑖𝑛| = $150 67
Price of oil: $60 + API per stbo; exclude gas production
Operating cost: $60 - API per stbo
calculations).
2) Determine and plot the OPR and IPR curves assuming a
horizontal flowline and a vertical tubing with the “Initial Input
Parameters” listed above. Identify the stable and unstable
operational regions. Determine the operating point for these
conditions.
3) Repeat Question #2 with flowline sizes of 2.5 and 3.5 inch
ID. What is the optimum flowline diameter, determining the cost of
the larger flowline and oil revenue?
4) Using the optimum flowline diameter found in Question #3,
repeat Question #2 with tubing sizes of 2, 3, and 3.5 inch ID. What
is the optimum tubing diameter, again considering cost and
revenue?
5) For the optimum flowline and tubing diameter, document the
observed flow regime changes from the bottomhole condition to the
separator.
6) Using the optimum flowline and tubing diameters from
Questions #2 and #3, consider gas injection into the tubing at a
depth of 4,500 ft, with injection rates of 1,000, 2,000, 3,000,
4,000, and 5,000 scf/stbo. The injected gas gravity is 0.68. Plot
IPR and OPR curves with the varying gas injection rates. What is
the optimal gas injection rate? Ignore the cost associated with gas
injection.
7) For the optimum gas lift injection rate and flowline and
tubing diameter, document the observed flow regime changes from the
bottomhole condition to the separator.
INITIAL INPUT PARAMETERS
Oil Specific Gravity: 45 – 2*(birth month) (API)
Water Specific Gravity:1.01
Gas Specific Gravity:0.65
Reservoir Pressure:2,250 +25*(last 2 digits in student ID)
(psig) 1,250 (psig)
Bubble Point Pressure:1,250 (psig)
Test Bottom Hole Flowing Pressure:850 (psig)
Reservoir Pressure at Test Conditions:2,250 (psig)
Test Oil Flowrate:1,500 (stbo/day)
Formation Gas-Oil Ratio:400 (scf/stbo)
Water Cut:0 (%)
Separator Pressure:450 (psig)
Separator Temperature:80 (deg F)
Well Head Pressure:0 (psig)
Well Head Temperature:160 (deg F)
Bottom hole Temperature:220 (deg F)
Bean Choke Size:64 (1/64 in)
Gas Injection Depth:4,500 (ft)
Injection Gas Specific Gravity:0.68
Injection Gas-Oil Ratio:285 (scf/stbo)
Tubing Depth: 4,500 (ft)
Tubing Inner Diameter:3 (in)
Flowline Length:15,000 (ft)
Flowline Angle: 0(deg)
Flowline Inner Diameter: 3 (in)
Solution Gas & Bubble Point Correlation: Kartoatmodjo
Oil Formation Volume Factor Correlation: Kartoatmodjo
Oil Viscosity Correlation: Kartoatmodjo
Z Factor Correlation: Standing
Tubing Pressure Drop Correlation: Beggs – Brill Model
Flowline Pressure Drop Correlation: Beggs – Brill Model
Price of steel: $5 per linear foot per inch of diameter
Example: 10 foot section of 3 inch diameter pipe = |10 𝑓𝑡|
0$2/450 |3 𝑖𝑛| = $150 67
Price of oil: $60 + API per stbo; exclude gas production
Operating cost: $60 - API per stbo