Pipesim 2006[1]. Answers

Answers Schlumberger

Module 7 AnswersIn this module, you can find the answers to the Well Performance Case Studies, Artificial Lift Design and Single Branch Case Studies.

Well Performance Case Studies

Oil Well Performance Analysis Exercise 2 – Pressure / Temperature Profile

Wellhead Pressure 300 psia Production Rate 7454 bbl/d Flowing BHP 2668 psia Flowing WHT 133 oF

Exercise 2 – Nodal Analysis

(Outlet) Wellhead Pressure 300 psia Operating Point Flow rate 7454 bbl/d Operating Point BHP 2668 psia AOFP 28535 bbl/d

Exercise 3 – PVT Analysis

Wellhead Pressure 300 psia Production Rate 6812 bbl/d Flowing BHP 2744 psia Flowing WHT 129 °F

Exercise 4 – Flow Correlation Matching

Wellhead Pressure 300 psia Vertical Correlation Hagedorn Brown Flowing BHP 2522 psia

Exercise 5 – IPR Matching

Wellhead Pressure 300 psia PI 6 AOFP 16000 bbl/d

Exercise 6 – Water Cut Sensitivity

Wellhead Pressure 300 psia Water Cut 64%

Exercise 7 – Gas Lift Water cut = 10% Water cut = 60%

Gas Lift Rate (mmscf/d)

Liq. Prod. Rate (stb/d)

Liq. Prod. Rate (stb/d)

PIPESIM 2006.1 Fundamentals 133


0.5 7227 4755 1 7707 5796 1.5 8048 6443 2 8306 6898



Enhanced Oil W ll ProductionExercise 1 – Well Model

e Using Nodal Analysis

Wellhead Pressure 250 psia Production Rate 775 stb/d Flowing BHP 2417 psia

Exercise 2 – Nodal Analysis – Sensitivity to Stimulation and Gas Lift s-Brill Oil Production Rates (stb/d) – Begg

Gas Lift Rates (mmscf/d)Com 0.5 1.0 2.0 pletion 0.0

ba 8.2 1240.5 se (skin = 3) 779 1097 118

aci ) 1084.5 1535.2 1598.9 dized (skin = 0 1432.1fra 2) 1438.4 1916.8 1981.9 ctured (skin = - 1798.9

Exercise 3 – Nodal Analysis – Sensitivity to Flow Correlation Oil Production Ra Brill tes (stb/d) – Mukherjee and

Gas Lift (mmscf/d)

Completion 0.0 0. 2.05 1.0 base (skin = 3) 697.7 1011 1 1221.3 .5 1125.

acidized (skin = 0) 981 1332.2 1468.6 1578 fracture 1964.5 d (skin = -2) 1325.4 1695.4 1846.2



Gas Well Perfor ce using a Compositional Fluid Model Exercise Well Mod

man 1 – Simple el

Pre 0 psia, Tres = 280os = 4,60 F% H2O @ saturation 1.85%

Po = 800 psia QG 33 mmscf/d Pwf 2160 psia BHT 248 oFWHT 182 oF

Exercise 2 – Calibrate Inflow Model

Back Pressure Equation Parameter C 8*10-7 Parameter n 1

Po = 800 psia QG 15.6 mmscf/d Pwf 1292 psia Tbh (ºF) 227 oF Twh (ºF) 168 oF

Exercise 3 – Perform Nodal Analysis at bottom hole

Po = 800 psia QG 15.7 mmscf/d Pwf 1254 psia BHT 227 oFWHT 165 oF

Well-head, 3.958” tubing Max. Erosional velocity ratio 0.78

Exercise 4 – Flow-line and Choke

Po = 710 psia Choke size 1.5

Exercise 5 – Higher liquid loading / Flow Correlation Matching

Pres = 4300 psia, Tres = 280 °F % H2O @ saturation 1.91

Po = 800 psia Best Correlation Duns-Ros Mean arithmetic difference (%) 0.27



Po = 800 psia Mean absolute difference (%) 0.27

Exercise 6 – Higher liquid loading / Flow Correlation MatchingPo = 710 psia

QG 13.3 mmscf/d Pwf 1361.3 psiaQL @ mid-perfs (act) 2062 bbl/d QL @ outlet (act) 2650 bbl/d

Exercise 7 – Liquid Hold-up fraction and Flow Regime Map

Liquid Volum ction, 710 psie Fra Po = axVL @ bottom-hole 0.07xVL @ WH 0.08xVL @ end flow-line 0.05Flow regime en mitted FL Inter nt

Liquid Hold-up Fraction, Po = 710 psia xHL @ bottom-hole 0.38xHL @ WH 0.08xHL @ end flow-line 0.15

Exercise 8 – mperatu h f serv Pressure / Te re pat rom Re oir

Am m bient Te p = 30 °FHydrate formation? No

Exercise 9 – Pressure Drop due to increase condensate production

Heavier composition �P Reservoir 2803 psia (Pwf = 1497 psia) �P Tubing 630 psia (Pwh = 869 psia) �P Choke 84 psia �P Flow-line 2 psia

Exercise 10 – Rigorous Flashing

Po = 710 psia QG 13.3 mmcfd Pwf 1360.4 psiaQL @ mid-perfs (act) 2094 bbl/d QL @ outlet (act) 2654 bbl/d

Ambient Temp = 30 °F Hydrate formation? No



Artific

ESP Design Exercise 1 – Nodal A

Well will not flow naturally.

Exercise 2 – Pump Selection / Desi

No. of stage 13000) 7

ial Lift Design

nalysis

gn

s (HN 5Motor HP re 316quiredFlowrate ran 0 – 70 Hz. 7606-12830 bbl/d ge for 5Flowrate for Psuction < Pbubblepoint 11926 bbl/d

Exercise 3 – Pump performance with varying well conditions

Prod b/d uction Rate (95% water cut st) 600




Single Bran acilitieExercise 1 – Size Subsea Tieba

ch Pipeline and F sck

Property ValuePipeline and R : iser ID 10’’Max. erosiona ed ID l velocity ratio for select 0.88Min. Separato ted ID r pressure for selec 900 psia Max. separator pressure for selected ID 1234 psia

Exercise 2 – Check for Severe slugging

8000(stb/d)

14000(stb/d)

16000 (stb/d)

PI-SS number at rise 1.3r base 0.99 1.24Flow pattern at riser ent Intermittentbase Intermitt Intermittent

Exercise 3 – Select Tieback Insulation Thickness

Property ValueReq. Insulation thickness 1”

Exercise 5 – Size Slug Catcher

Property 8000 (stb/d)

14000 (stb/d)

16000 (stb/d)

1/1000 slug volume (bbl) 186.7 226.5 166.3 Sphere generated li 48 448.2 435.9 quid volume (bbl) 5.7 Design volume for slug catcher (bbl) 485.7*1.2 = 582.8

Pipesim 2006[1]. Answers

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