Gas Well Deliquification Workshop Sheraton Hotel Denver Colorado

Gas Well Deliquification Workshop Sheraton Hotel, Denver, Colorado February 17 – 20, 2013 Model the Effectiveness of Pump and Plunger by Transient Multi-Phase Flow Simulation Kees Veeken – Shell (NAM) Rahel Yusuf – SPT Group

Contents • Objectives • Transient Vs Steady State • Pump modeling • Plunger modeling Feb. 17 – 20, 2013 Gas Well Deliquification Workshop Denver, Colorado 2

Objectives • How much back pressure is introduced by the flowing wet gas column in the presence of a pump that removes liquids from the bottom of the well ? – The outcome determines the effectiveness of a pump and defines the best ways of operating a pump • What is the effectiveness of a plunger that travels up to the subsurface safety valve but does not cover the short distance between subsurface safety valve and wellhead ? – The outcome determines the requirement for a second plunger to dewater the top section Feb. 17 – 20, 2013 Gas Well Deliquification Workshop Denver, Colorado 3

Transient Vs Steady State • Pump intake pressure sits in between too high steady state VLP and too low dry gas VLP – How effective is downhole separation? – How steady is production and how much gas will enter pump ? • Plunger action is transient in nature – Will slug of liquid be able to bridge “gap” ? Feb. 17 – 20, 2013 Gas Well Deliquification Workshop Denver, Colorado 4

Pump Modeling Parameters • 5. 5” tubing + 5” liner down to 3040 m Power Liquid Gas • Pump on 1. 5” CCT @ 3020 m • Inflow across 2770 -3040 m with 3% below pump • Darcy inflow A=80 bara/(e 3 m 3/d) • Reservoir Pres=35 -55 -65 -75 bara • WGR=23 -7, CGR=10 m 3/e 6 m 3 • Wellhead pressure = 9 bara v Constant mass pump rate for liquid and gas i. e. keeps pumping in case of gas ingress Feb. 17 – 20, 2013 Gas Well Deliquification Workshop Denver, Colorado 5

OLGA Liquid Loading Point IPR – Pres=69 bara LL – OLGA Qmin=58 e 3 m 3/d VLP – Modified Gray VLP - Gray VLP – Cullender-Smith Feb. 17 – 20, 2013 Gas Well Deliquification Workshop Denver, Colorado 6

Pres=55 bara – No Pumping Gas rate (e 3 m 3/d) Pressure @ pump intake (bara) Holdup @ pump intake (-) Liquid in wellbore (m 3) Feb. 17 – 20, 2013 Gas Well Deliquification Workshop Denver, Colorado 7

Pres=55 bara – Pumping @ 1 m 3/d • Stable holdup @ pump intake: gassy liquid (8 Sm 3/d gas) Gas rate (e 3 m 3/d) Pressure @ pump intake (bara) Holdup @ pump intake (-) Liquid in wellbore (m 3) Feb. 17 – 20, 2013 Gas Well Deliquification Workshop Denver, Colorado 8

Pres=55 bara – Pumping @ 1 m 3/d Significant holdup across bulk of wellbore Feb. 17 – 20, 2013 Gas Well Deliquification Workshop Denver, Colorado 9

Pres=55 bara – Pumping @ 1 m 3/d Liquid holdup increases pump intake pressure Feb. 17 – 20, 2013 Gas Well Deliquification Workshop Denver, Colorado 10

Pres=55 bara – Pumping @ 2 m 3/d • Oscillating holdup @ pump intake: gassy liquid or gas Gas rate (e 3 m 3/d) Pressure @ pump intake (bara) Holdup @ pump intake (-) Liquid in wellbore (m 3) Feb. 17 – 20, 2013 Gas Well Deliquification Workshop Denver, Colorado 11

Pres=55 bara – Pumping @ 2 m 3/d Holdup is slugging up and down wellbore Feb. 17 – 20, 2013 Gas Well Deliquification Workshop Denver, Colorado 12

Pres=55 bara – Pumping @ 2 m 3/d Pump intake pressure oscillates Feb. 17 – 20, 2013 Gas Well Deliquification Workshop Denver, Colorado 13

Pres=65 bara – Pumping @ 2 m 3/d • Oscillating holdup @ pump intake: gassy liquid or gas Gas rate (e 3 m 3/d) Pressure @ pump intake (bara) Holdup @ pump intake (-) Liquid in wellbore (m 3) Feb. 17 – 20, 2013 Gas Well Deliquification Workshop Denver, Colorado 14

Pumping Operating Points IPR – Pres=75/65/55/35 bara VLP – Modified Gray VLP – CS (dry & wet) OLGA – Pumping (m 3/d) & LL Feb. 17 – 20, 2013 Gas Well Deliquification Workshop Denver, Colorado 15

Pumping Summary • Back pressure due to liquid holdup is unavoidable • Magnitude increases as Q increases – Insignificant at low enough Q but significant at higher Q as downhole separation becomes less effective – Back pressure does not increase with higher WGR! – Production penalty increases as inflow improves! • Gas ingress into pump depends on pump rate and location of pump intake relative to inflow profile – Pump off triggers slugging and large gas ingress v Further explore influence of pump location, liner size and deviation on back pressure and gas ingress Feb. 17 – 20, 2013 Gas Well Deliquification Workshop Denver, Colorado 16

Plunger Modeling Parameters • 3. 5” tubing to 1169 m, 5”x 4. 5” liner to 1310 m Trap • Pres=12 -18 bara, WGR=10 -88 m 3/e 6 m 3, CGR=0 m 3/e 6 m 3 PL • Wellhead pressure = 8 bara • 3. 5” tubing plunger weight = 7. 5 kg, zero leakage, SV or 3 bara BPV • 9 plunger cycles 2 hr flow, 1 hr shut-in Feb. 17 – 20, 2013 Gas Well Deliquification Workshop Denver, Colorado SV Launch Wellbore • Inflow @ 1310 m, A=5. 2 bara/(e 3 m 3/d) Tubing • Plunger between “launch” @ 1145 m and “trap” @ 0 -330 m (SSSV @ 102 m) 17

Field – No Plunger, Close to LL • 1 hr flow, 0. 5 hr shut-in THP (barg) Gas Rate (Nm 3/d) FTHP (bara) Gas Rate (Nm 3/d) Feb. 17 – 20, 2013 Gas Well Deliquification Workshop Denver, Colorado 18

Field – Plunger 11 hrs ON, 1 hr OFF • 1 hr flow, 0. 5 hr shut-in TT~20 min (excessive) VEL~52 m/min (170 ft/min) ON period too long THP (barg) Gas Rate (Nm 3/d) FTHP (bara) Gas Rate (Nm 3/d) Feb. 17 – 20, 2013 Gas Well Deliquification Workshop Denver, Colorado 19

Field – Plunger 2 hrs ON, 1 hr OFF • 1 hr flow, 0. 5 hr shut-in TT~5 min VEL~209 m/min (690 ft/min) THP (barg) Gas Rate (Nm 3/d) FTHP (bara) Gas Rate (Nm 3/d) Feb. 17 – 20, 2013 Gas Well Deliquification Workshop Denver, Colorado 20

WGR=88 m 3/e 6 m 3, Pres=17. 5 16. 5 bara Gas rate (Sm 3/d) Cumulative Liquid (m 3) Liquid in tubing (m 3) Liquid in wellbore (m 3) Qmin=29 e 3 m 3/d @ Pres=16. 9 bara Feb. 17 – 20, 2013 Gas Well Deliquification Workshop Denver, Colorado 21

OLGA Liquid Loading Points IPR – Pres=14. 3 -16. 9 bara VLP – Modified Gray WGR=10 -88 m 3/e 6 m 3 OLGA LL Points WGR=10 -88 m 3/e 6 m 3 Feb. 17 – 20, 2013 Gas Well Deliquification Workshop Denver, Colorado 22

WGR=88, Pres=15, Trap @0, BPV (#8) THP (bara) Gas rate (Sm 3/d) Liquid in Tubing (m 3) Liquid in Wellbore (m 3) Plunger Velocity (m/s) Plunger Position (m) TT~6. 5 min VEL~161 m/min (530 ft/min) Feb. 17 – 20, 2013 Gas Well Deliquification Workshop Denver, Colorado 23

WGR=88, Pres=15, Trap @0, SV, 23. 9 hr Holdup Tubing (-) Pressure Tubing (bara) Holdup Wellbore (-) Pressure Wellbore (bara) Feb. 17 – 20, 2013 Gas Well Deliquification Workshop Denver, Colorado 24

WGR=88, Pres=15, Trap @0, SV, 24. 05 hr Holdup Tubing (-) Pressure Tubing (bara) Holdup Wellbore (-) Pressure Wellbore (bara) Feb. 17 – 20, 2013 Gas Well Deliquification Workshop Denver, Colorado 25

WGR=88, Pres=15, Trap @0, SV, 24. 1 hr Holdup Tubing (-) Pressure Tubing (bara) Holdup Wellbore (-) Pressure Wellbore (bara) Feb. 17 – 20, 2013 Gas Well Deliquification Workshop Denver, Colorado 26

WGR=88, Pres=15, Trap @0, SV, 24. 15 hr Holdup Tubing (-) Pressure Tubing (bara) Holdup Wellbore (-) Pressure Wellbore (bara) Feb. 17 – 20, 2013 Gas Well Deliquification Workshop Denver, Colorado 27

WGR=88, Pres=15, Trap @0, SV, 25. 9 hrs Holdup Tubing (-) Pressure Tubing (bara) Holdup Wellbore (-) Pressure Wellbore (bara) Feb. 17 – 20, 2013 Gas Well Deliquification Workshop Denver, Colorado 28

WGR=88, Pres=15, Trap @0, SV, 26. 05 hr Holdup Tubing (-) Pressure Tubing (bara) Holdup Wellbore (-) Pressure Wellbore (bara) Feb. 17 – 20, 2013 Gas Well Deliquification Workshop Denver, Colorado 29

WGR=88, Pres=15, Trap @0, SV, 26. 1 hr Holdup Tubing (-) Pressure Tubing (bara) Holdup Wellbore (-) Pressure Wellbore (bara) Feb. 17 – 20, 2013 Gas Well Deliquification Workshop Denver, Colorado 30

WGR=88, Pres=15, Trap @0, BPV (#8) THP (bara) Gas rate (Sm 3/d) Liquid in Tubing (m 3) Liquid in Wellbore (m 3) Plunger Velocity (m/s) Plunger Position (m) TT~6. 5 min VEL~161 m/min (530 ft/min) Feb. 17 – 20, 2013 Gas Well Deliquification Workshop Denver, Colorado 31

WGR=10, Pres=15, Trap @0, SV THP (bara) Gas rate (Sm 3/d) Cumulative Liquid (m 3) Liquid in Tubing (m 3) Liquid in Wellbore (m 3) Feb. 17 – 20, 2013 Gas Well Deliquification Workshop Denver, Colorado 32

WGR=10, Pres=15, Trap @0, SV (#8) THP (bara) Gas rate (Sm 3/d) Liquid in Tubing (m 3) Liquid in Wellbore (m 3) Plunger Velocity (m/s) Plunger Position (m) TT~3. 0 min VEL~350 m/min (1150 ft/min) Feb. 17 – 20, 2013 Gas Well Deliquification Workshop Denver, Colorado 33

WGR=10, Pres=14, Trap @0, SV (#8) THP (bara) Gas rate (Sm 3/d) Liquid in Tubing (m 3) Liquid in Wellbore (m 3) Plunger Velocity (m/s) Plunger Position (m) TT~3. 3 min VEL~320 m/min (1050 ft/min) Feb. 17 – 20, 2013 Gas Well Deliquification Workshop Denver, Colorado 34

WGR=10, Pres=13, Trap @0, SV (#8) THP (bara) Gas rate (Sm 3/d) Liquid in Tubing (m 3) Liquid in Wellbore (m 3) Plunger Velocity (m/s) Plunger Position (m) TT~4 min VEL~260 m/min (850 ft/min) Feb. 17 – 20, 2013 Gas Well Deliquification Workshop Denver, Colorado 35

WGR=10, Pres=12, Trap @0, SV (#4) THP (bara) Gas rate (Sm 3/d) Liquid in Tubing (m 3) Liquid in Wellbore (m 3) Plunger Velocity (m/s) Plunger Position (m) TT~5 min VEL~209 m/min (690 ft/min) Feb. 17 – 20, 2013 Gas Well Deliquification Workshop Denver, Colorado 36

WGR=88, Pres=15, Trap @0, BPV THP (bara) Gas rate (Sm 3/d) Cumulative Liquid (m 3) Liquid in Tubing (m 3) Liquid in Wellbore (m 3) Feb. 17 – 20, 2013 Gas Well Deliquification Workshop Denver, Colorado 37

WGR=88, Pres=15, Trap @50, SV THP (bara) Gas rate (Sm 3/d) Cumulative Liquid (m 3) Liquid in Tubing (m 3) Liquid in Wellbore (m 3) Feb. 17 – 20, 2013 Gas Well Deliquification Workshop Denver, Colorado 38

WGR=88, Pres=15, Trap @102, SV THP (bara) Gas rate (Sm 3/d) Cumulative Liquid (m 3) Liquid in Tubing (m 3) Liquid in Wellbore (m 3) Feb. 17 – 20, 2013 Gas Well Deliquification Workshop Denver, Colorado 39

WGR=88, Pres=15, Trap @330, SV THP (bara) Gas rate (Sm 3/d) Cumulative Liquid (m 3) Liquid in Tubing (m 3) Liquid in Wellbore (m 3) Feb. 17 – 20, 2013 Gas Well Deliquification Workshop Denver, Colorado 40

With Plunger – Operating Points IPR – Pres=14. 3 -16. 9 bara VLP – CS WGR=11 -88 m 3/e 6 m 3 � – LL WGR=11 -88 m 3/e 6 m 3 O – WGR=11, Trap=0 – WGR=88, Trap=102 Feb. 17 – 20, 2013 Gas Well Deliquification Workshop Denver, Colorado 41

Plunger Summary • Transient multi-phase flow model produces credible results and provides insight into influence of well parameters on plunger performance • Plunger needs to travel to top of tubing to deliver maximum value i. e. liquid slug cannot bridge large “gap” • Plunger introduces back pressure proportional to WGR which can limit applicability in prolific wells – Gas production during upward travel must deliver minimum plunger velocity and will diminish as slug size increases v Further explore influence of plunger launch position, wellbore (plus annulus) volume, inflow performance and plunger ON/OFF schedule Feb. 17 – 20, 2013 Gas Well Deliquification Workshop Denver, Colorado 42

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