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SOLVIER
CASE STUDY SOLUTION
submitted by :-
Jash PATEL
Vishal Vyas
 Sand Production in Well
 Liquid Loading
 What is liquid loading?
 Liquid loading occurs when the gas velocity is insufficient to carry the produced liquid to surface facilities.
 Liquid loading cause the slug flow which cease the production of gas.
 Difficult to identify.
 Identification of Liquid loading in Gas wells
 Turner, Hubbard and Dukler & Coleman find the liquid transport model in vertical gas
flow.
 Model is known as “minimum critical flow rate” or “critical velocity”-
 If Vg(Gas Velocity) < (Vgc) Critical Velocity , Cause liquid loading.
where,
Vgc: Critical gas velocity (ft/s)
K Constant : 1.92 ( Turner ),1.59 (Coleman)
σ :Surface tension liquid to gas ( dyne/cm)
ρg: Density of gas ( lb/ft3)
ρl: Density of liquid ( lb/ft3)
Qgc: Critical gas rate (MMscf/d)
Vgc: Critical gas velocity (ft/S)
A: Cross sectional area (ft2)
T: Temperature (F)
P: Pressure (psi)
Z: Compressibility factor
𝑄𝑔𝑐 =
3.06 ∗ 𝑃 ∗ 𝐴 ∗ 𝑉𝑔𝑐
𝑇 + 460 ∗ 𝑧
For Well Y
Reservoir Parameters Completion Parameters
Perf Depth (m) 858-860.5 Tubing Size * 2 7/8” or 2
Reservoir Pr(KSc): 79 Casing Size 5 ½”
FBHP (KSc): 77 Production Casing Shoe
927
Production Details:
Last gas flow rate recorded (m3
/d):15850
Last liquid rate recorded (m3
/d): 9
Water cut (%): 100
Expected THP(KSc): 25
Given Data
 Now calculating the critical velocity by assuming the following data:
Density of gas (ρg): 0.0401 lb/ft3
Compressibility factor Z: 0.85
Surface Tension: 60 dyne/cm
Reservoir temp.: 114.8 F
Density of water(ρL): 67 lb/ft3
Calculating the critical velocity
Vgc = 63.2271 ft/s
Qgc = 211701.86 m3/d
Here Qgc > Qg
Note: assumed data is same for both the Well Y & Z.
For Well Z
Reservoir Parameters Completion Parameters
Perf Depth (m): 790-795 Tubing Size: 2 7/8” or 2 3/8”
Reservoir Pr (KSc): 76 Production Casing size: 5 ½”
Flowing Bottom Hole Pressure Production casing shoe (m): 798
(KSc): 71
Production Details
Last gas flow rate recorded
(m3/d): 16000
Last liquid rate recorded (m3
/d): 7.604
Water cut (%): 100
Expected THP (KSc): 25
From the values we have we got the value of critical velocity & critical flow rate as following:
Vgc = 63.2271 ft/s
Qgc = 195205.61 m3/d
Here Qgc>Qgz
In Both Well, Liquid Loading.
Using SRP, We keep it Below Perforation.
Gas Comes out from annulus.
 Economic Analysis
• CAPEX
• SRP :- Rs 30 lakhs
• Tubing cost :-
Y :- 800 x 900= Rs 7.2 lakhs
Z :- 800 x 796= Rs 6.36lakhs
• Workover cost :-
Rig Operating Day Rate (RODR) :- 22.5 lakhs
Inter location move Charges (ILMC ):- 6.5 lakhs
Rig Transportation Cost :- 5.1 lakhs
GST :- +12%
Total :- 38.192 lakhs
• Sand screen :- 1 lakhs
 Total CAPEX
Y :- Rs 82.752 lakhs
Z :- Rs 84.75 lakhs (Assume Separator Cost 2 lakhs)
 Revenue
Y :- Rs 2.92 lakhs / Day
Z :- Rs 2.95 lakhs / Day
 Payback period
Y :- 28.3 Days
Z :- 29 Days

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Case study pptx

  • 1. SOLVIER CASE STUDY SOLUTION submitted by :- Jash PATEL Vishal Vyas
  • 2.  Sand Production in Well  Liquid Loading  What is liquid loading?  Liquid loading occurs when the gas velocity is insufficient to carry the produced liquid to surface facilities.
  • 3.  Liquid loading cause the slug flow which cease the production of gas.  Difficult to identify.  Identification of Liquid loading in Gas wells  Turner, Hubbard and Dukler & Coleman find the liquid transport model in vertical gas flow.  Model is known as “minimum critical flow rate” or “critical velocity”-  If Vg(Gas Velocity) < (Vgc) Critical Velocity , Cause liquid loading.
  • 4. where, Vgc: Critical gas velocity (ft/s) K Constant : 1.92 ( Turner ),1.59 (Coleman) σ :Surface tension liquid to gas ( dyne/cm) ρg: Density of gas ( lb/ft3) ρl: Density of liquid ( lb/ft3) Qgc: Critical gas rate (MMscf/d) Vgc: Critical gas velocity (ft/S) A: Cross sectional area (ft2) T: Temperature (F) P: Pressure (psi) Z: Compressibility factor 𝑄𝑔𝑐 = 3.06 ∗ 𝑃 ∗ 𝐴 ∗ 𝑉𝑔𝑐 𝑇 + 460 ∗ 𝑧
  • 5. For Well Y Reservoir Parameters Completion Parameters Perf Depth (m) 858-860.5 Tubing Size * 2 7/8” or 2 Reservoir Pr(KSc): 79 Casing Size 5 ½” FBHP (KSc): 77 Production Casing Shoe 927 Production Details: Last gas flow rate recorded (m3 /d):15850 Last liquid rate recorded (m3 /d): 9 Water cut (%): 100 Expected THP(KSc): 25 Given Data
  • 6.  Now calculating the critical velocity by assuming the following data: Density of gas (ρg): 0.0401 lb/ft3 Compressibility factor Z: 0.85 Surface Tension: 60 dyne/cm Reservoir temp.: 114.8 F Density of water(ρL): 67 lb/ft3 Calculating the critical velocity Vgc = 63.2271 ft/s Qgc = 211701.86 m3/d Here Qgc > Qg Note: assumed data is same for both the Well Y & Z.
  • 7. For Well Z Reservoir Parameters Completion Parameters Perf Depth (m): 790-795 Tubing Size: 2 7/8” or 2 3/8” Reservoir Pr (KSc): 76 Production Casing size: 5 ½” Flowing Bottom Hole Pressure Production casing shoe (m): 798 (KSc): 71 Production Details Last gas flow rate recorded (m3/d): 16000 Last liquid rate recorded (m3 /d): 7.604 Water cut (%): 100 Expected THP (KSc): 25
  • 8. From the values we have we got the value of critical velocity & critical flow rate as following: Vgc = 63.2271 ft/s Qgc = 195205.61 m3/d Here Qgc>Qgz
  • 9. In Both Well, Liquid Loading. Using SRP, We keep it Below Perforation. Gas Comes out from annulus.
  • 10.  Economic Analysis • CAPEX • SRP :- Rs 30 lakhs • Tubing cost :- Y :- 800 x 900= Rs 7.2 lakhs Z :- 800 x 796= Rs 6.36lakhs • Workover cost :- Rig Operating Day Rate (RODR) :- 22.5 lakhs Inter location move Charges (ILMC ):- 6.5 lakhs Rig Transportation Cost :- 5.1 lakhs GST :- +12% Total :- 38.192 lakhs • Sand screen :- 1 lakhs
  • 11.  Total CAPEX Y :- Rs 82.752 lakhs Z :- Rs 84.75 lakhs (Assume Separator Cost 2 lakhs)  Revenue Y :- Rs 2.92 lakhs / Day Z :- Rs 2.95 lakhs / Day  Payback period Y :- 28.3 Days Z :- 29 Days