Session 208-Mike Lam-20 (Hydraulic-Workover Units-LW Completions)

Live Well CompletionsLive Well Completions

Hydraulic Workover Units (HWO)Hydraulic Workover Units (HWO)

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TOPICS for DISCUSSION

•Live Well Completions ApplicationsM h i f H d li W k•Mechanics of Hydraulic Workover

•Stripping Procedures•Engineering and Well Planning•HWO Live Well Completions Case Historiesp

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Live Well Completion Applications with HWO

• Live Completion/Re-completion –i S iti F ti

p pp

in Sensitive Formations

Especially gas wells where conventional methods result in l f d tiloss of production

• Running / Pulling Tubing, Drill Pipe, or Casing Under PressurePipe, or Casing Under Pressure

• Conventional Live Well Completions

• Horizontal Live Well Completions

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Mechanics of Hydraulic Workover

• The Rotary and Traveling Slips can work simultaneously.


y• Cudd’s Hydraulic Rig Assist Unit

has a passive rotary - requires PDM or power swivel for rotational

i trequirements

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• Stationary and Traveling Slips are both engaged at beginning


are both engaged at beginning of snubbing stroke.

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• Stationary Slips are disengaged• With Traveling Slips engaged, the


With Traveling Slips engaged, the hydraulic cylinders are extended retracted - lowering the tubing - and completing the stroke.

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• At completion of downward stroke, the stationary slips are engaged


the stationary slips are engaged.• The Traveling Slips are

disengaged, then the hydraulic cylinders are extended to make the next stroke.

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• Process is repeated as the tubing is snubbed through the


BOP Stripper rams or annular

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Ram to Ram HWO Procedures

STEP1: With tree valve open, BHA is lowered through snubbing stack – All BOP rams are open. PV#1, PV#4, PV#7, PV#8 are closed

BOP #2 Stripper rams are closed around tubing above BHA

Tubing is snubbed until tool joint/connection is between BOP #1 rams and BOP#2 ramsBOP #1 rams and BOP#2 rams

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STEP 2: Close BOP#1 stripper ramsstripper rams

STEP 3: Open Hydraulic PV#1

STEP 4: Allow pressure under BOP #2 stripper rams to equalize below BOP#1 stripper rams

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STEP 5:Open BOP#2 stripper ramsppSTEP 6: Snub tubing into the well bore until tool joint/ connection is below BOP #2 stripper rams#2 stripper rams

STEP 7: Close PV#1

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STEP 8:Close BOP#2 stripper ramsppSTEP 9: Open PV#4 and allow pressure between Bop#1 ans BOP#2 stripper rams to bleed offrams to bleed off

STEP 10: Allow pressure to bleed to -0- between stripper ramsstripper rams

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STEP 11:Open BOP#1

HWO Procedures

STEP 11:Open BOP#1 stripper rams

STEP 12: Close PV#4

STEP 13: Again, tubing is snubbed until joint/ connection is between BOP#1 and BOP#2 stripper ramsREPEAT THE PROCESS

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ENGINEERING

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Engineering Calculations ForHWO/Snubbing ApplicationsHWO/Snubbing Applications

• Collapse / Burst calculations for tubing - based on anticipated compression, tension, and torsional loadstension, and torsional loads

• “Critical Buckling Load Limitations” - calculations based on comprehensive list of factors

• Required Snubbing Forceq g• Required Hydraulic Snub / Lift Pressure - Jack Forces• Well Control considerations• Unit stability (wind loading analysis)Unit stability (wind loading analysis)• Applied loads to wellhead• Torque & Drag

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Engineering Calculations ForSnubbing ApplicationsSnubbing Applications

Critical Buckling

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Engineering Calculations ForSnubbing ApplicationsSnubbing Applications

Combined Stresses

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HWO Live Well Completions Case Histories

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Case History #1 - Onshore ESP Workover CampaignCampaign

Completed 8 wells – ESP Change-Outp g• Average Well Depth: 3415m (11,205 ft)• Tubing Sizes: 3 1/2” & 4 1/2”• Average Rig Up time: 10.5 hrsg g p• Average POOH time: 25.1 hrs (446 ft/hr)• Average RIH time: 21.2 hrs (529

ft /hr)• Average RD time: 7.8 hrs

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Case History #2 – Live Well Completion

• Type Job: Live well completion• Date: 13 Jan., 2003• Location: South Texas

y p

• Location: South Texas• Unit Type: 150K “Quick Jack”• Pressure: 20.7 MPa (3000 psi ) (well flowing)• Tubing: 2-3/8” 4.7# P-110 8RD-MOD• Well Depth: 4 977 m (16 330’)• Well Depth: 4,977 m (16,330 )• Duration: 2 days (daylight)• Trip Speed: 579 m/hour (1,900 foot/hour)

• Description: MU 3-3/4” Mill, Hyd-disconnect, 1jt. Tbg. & 1.875” X-Nipple. TIH live, to top of CIBP @ 15,190’, mill up plug and wash down to PBTD @ 16,330’. Drop 1-1/4” ball, pressure up tbg. w/ N2 & disconnect mill. POOH to 12,570’. Space out and MU extended neck hanger so that when hanger lands, BOT is @ approx. 12,570’. ND snubbing unit and BOP’

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BOP’s.

Case History #3 – High Pressure SnubbingCase sto y #3 g essu e S ubb g• Type Job: Washout 3-1/2 Production Tubing, H2S• Date: April - May, 2002• Location: GOM• Location: GOM• Unit Type: 150K Jack• Pressure: 90 MPa (13,100 PSI )• Workstring: 1-1/4” CS. Hydril tubing• Well Depth: 7,003 m (22,978’ )• Duration: 17 days (8 days snubbing)• Trip Speed: 122 to 304m/hr

(400 to 1,000 ft/hr)(400 to 1,000 ft/hr)

• Description: Repair Xmas Tree, R/U BOP’s & Unit, Test, MU Mill, BPV’s, Nipple on 1-1/4 workstring. TIH to bridge at 2,472’, wash & mill to 4,800’, circ out. TIH to 10,100’, tag bridge, wash & mill to 10 200’ circ out Bullhead into well POOH Run W/L gauge Cmt perfs Perforate new zone

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mill to 10,200 circ out . Bullhead into well. POOH. Run W/L gauge. Cmt perfs. Perforate new zone. R/D snubbing unit and BOP’s, turn well over to production.

Case History #3 – High Pressure Snubbing1) 1 3 9 7 CUDD

Circulation Drawing for High Pressure H2S Wash OutOperation # 3 Well Mobile 903

26 April; 2002

150K Snubbing Jack

Stand Pipe

1)p-1,p-3,p-9,p-7 2)p-4,p-2,p-8,p-10 3)p-16 4)p-15 5)p-6,p-5,p-11 6)p-12,p-13,p-14 7)Remove check k-3,#5 Blind ram,c-2,c-3, Rental crown valve,8) #5 Blind ram,c-1,c-5,c-4,Rental Master

p17

circdrawing.dsf No scale

Diverter line to rig manifold or flare stack

) 9) P/U 1-1/4''tbg.,#9 1-1/4'' safety,p-17 10) #8 1-1/4'' safety 11) #4 1-1/4''safety,c-6,k-1 12) #2 1-1/4 stripper,e-4,e-5,c-7,c-22,c-21 c-24,k-2 13) M/U check k-3,#2 1-1/4'' stripper,e-3,e-6, c-20,c-8,c-23,c-25 14) #2 1-1/4'' stripper,e-1,c-18,c-9

d 1

15) #2 1-1/4''stripper,e-2,c-18,c-1016) #1 1-1/4''stripper,b-1,c-11,c-12,c-17,c-1617) #1 1-1/4''stripper,b-2,c-13,c-15,c-1418) hydril,d-1,note 10m, L/D 1-1/4''tbg.19) P/U 1-1/2''tbg.,#7 1-1/2'' safety ram20) kill line stabbing valve(t i w ) b p v

Bleed OffLine to rig manifold or flare stack

EqualizingPump Line

Diverter line to rig manifold or flare stack

Pump Bleed Off ( routed to GBor safe area) 1 1/4 stripper ram

1 1/4 stripper ramb-1 b-2

e-2 e-1

e4e3 e5 e6

#1

#2

e1 e2

d-1 20) kill line,stabbing valve(t.i.w.),b.p.v.21) 1-13/16''20m csg. valve22) 2'' 1502 stabbing valve23) 2'' 1502 stabbing valve24) 1-1/4'' b.p.v.25) 1-1/4'' b.p.v.

ChokeLine

ChokeLine

Mud/GasSeparator

Mud Pu6'x14' ,

Pump Bleed Off(routed to GBor safe area)

Check ValveFastorqtest unit

p6

p7

p9

blind ram

1 1/4 safety ram

1 1/4 slip ram

c-1 c-2 c-3p-15 c-5

#3

#4

#5

c-6

p10

p8

p11 p12p-16

ChokeManifold

choke manifold 15m

3-1/16''20mx2-1/16''15mspool to manifold

c-8

c 7

c-9 c-10 c-11

c-12

14c-13c-23c-22

KillLine

M 15M Pump

mp #2

, 24k Check Valve

p-2

p3 p4

p51 1/2 safety ram

sh ea r ramc-4

#8

#6

#7

#91 1/4 safety ram

1 1/4 safety ram

k-1k-2k-3p1

p11 p12

p14p13

Transducer

spool to manifold c-7 c-14

c-17c-18

c-16

c-15

c-20

c-21

c-19

c-25c-24

GlycolInjection

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Pump Bleed Off ( routed to GB or safe area)

Mud Pum

p #16'x14', 24k

125 bbl Mud Tank

pManifold

Case History #3 – High Pressure Snubbing

CUDDR/U Drawing for High Pressure H2S Wash OutOperation # 3 Well Mobile 903

26,April : 2002RU drawing H2S. No scaleNo scale

150K Snubbing Jack

4-1/16"15m X 3-1/16''20mBOP Stack240"

4-1/16''15mX4-1/16''10m Adapter Spool4-1/16''10mX4-1/16''10m Swivel Spool

Elevation = 1188"(Approx. 99')

53''12''

2-9/16''I.D.X4''O.D.Guide to Bottom ofJack and Top of Hydrill

(Approx:62 58'Elevation= 751''

4-1/16''10m Hydril

# 1-1-1/4''Stripper Ram 4-1/16''15m4-1/16''15mSpool w/ 2-9/16''I.D.

# 2 1 1/4''Stripper Ram 4 1/16''15m

4-1/16''15m Helical Adapter W/2-9/16'' Guide 4-1/16''15m Diverted Line

29 25''

29.25''

25.25''

17.75''

24''

4-1/16''10x4-1/16''15m D.S.A.

to Top of # 1- Stripper

6.0''

6.25''

2'';1502 10m

2'';1502 10m

(Approx:62.58above rig floor)

ChokeLine

Flow Cross# 5-Blind Ram 3-1/16''20m

# 3-1-1/4''Slip Ram 4-1/16''15m

# 2-1-1/4 Stripper Ram 4-1/16 15m

ChokeLine

# 4-1-1/4''Safety Ram 3-1/16''20m

32''

32''

29.25''

29.25

4-1/16''15mX3-1/16''20m D.S.A11''

2'';2202

2'';1502

2'';2202

KillLine

# 7-1-1/2''Safety Ram 3-1/16''20m

Flow Cross

# 6-Shear Ram 3-1/16''20m

# 8-1-1/4'' Safety 3-1/16''20m

# 9 1 1/4''S f t 3 1/16''20

32''

32''

16''

32''3-1/16''20mX2-1/16''15m

2'';1502

2'';1502

2'';1502

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3-1/16''20mX2-9/16''20m D.S.A

# 9-1-1/4''Safety 3-1/16''20m

2-9/16'' 20m Crown Valve2-9/16'' 20m Master Valve

Rig floor Rig floor

32''

12''

432''

26.5''26.5''

Spool 2-9/16''20m 33'

Case History #4 – Gas Storage Well: 4-1/2” Tubing ChangeoutTubing Changeout

• Type Job: Pull 4-1/2 “Injection” Casing and Set Plug ( i l t t i )(rig an replacement string)

• Date: April, 1994• Location: Wyoming, USA• Unit Type: 170K Hydraulic Rig Assist Jack Unityp y g• Well Press: 12 to 15 MPa (1,800 to 2,200 psi )• Workstring: 4-1/2” Casing• Well Depth: 2,743 m (9,000’ ) (approximately)

Duration: 1 1/2 Days per well (snub phase only)• Duration: 1-1/2 Days per well (snub phase only). (3 Well Campaign)

• Description: Preset plug in 4-1/2” and rigup workover rig, Remove down p p g g p gXmas Tree, install rig BOPs, R/U Snub Unit, Test, Snub out 4-1/2 Casing and lay down, Rig Down Snub Unit, Run W/L plug and set in tail pipe, Run new 4-1/2” Injection Casing w/seal assy on Rig.

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Case History #5 – JI #1 Gas Storage Well: P ll 5 1/2” T biPull 5-1/2” Tubing

• Type Job: Pull 5-1/2 “Injection” Casing D A il 2002• Date: April, 2002

• Location: Mississippi, USA• Unit Type: 340K Hydraulic Standalone Jack Unit• Well Press: 9 MPa (1,300 psi )• Workstring: 5-1/2” Casing• Well Depth: 2,743 m (6,000’ ) (approximately)• Duration: 4 Days (10 wells total)

• Description: Preset plug in 5-1/2”, Remove Xmas Tree, R/U Snub Unit & BOP T t S b t 5 1/2 C i d l d Ri D S b U itBOPs, Test, Snub out 5-1/2 Casing and lay down, Rig Down Snub Unit

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Case History #5 – Gas Storage Well

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Case History #5 – Gas Storage Well

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Gas Storage Wells T i l U f S bbiTypical Uses of Snubbing

• Snub out injection/wash strings (up to 7”)• Remove and replace Tubing/Casing/Packerp g g• Reposition tubing/casing within cavern• Washout Obstructions (through tubing)( g g)

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Type Job: Live well completionDate: 27 March., 2005Location: Qui 101 Burlington Resources China

225K Rack Jack

Location: Qui 101 Burlington Resources ChinaUnit Type: 225K Well Press: 35.8 MPa (5200psi) shut in; 10.3 MPa (1500psi) well

flowing)Tubing: 2-3/8” 4 7# P-110 8RDTubing: 2 3/8 4.7# P 110 8RDWell Depth: 3250 m (10,662’)Duration: 4 days (daylight)Trip Speed: 377 m/hour (1240 foot/hour)

Description: MU 4-1/2” Mill, Pump through-Pump off Bit Sub, 1jt. Tbg. & 1.875” X-Nipple. TIH live, to 3150 m tag sand and clean out with water and well gas to 10 meters below perfs @ 3250 m. Pull up to 3140 m (10 meters above

f ) M k d l d t bi h Ri d bbi it dperfs). Make up and land tubing hanger. Rig down snubbing unit and BOP’s, Nipple up production tree. Drop 7/8” ball in tubing and pressure up with water to release bit. Turn well over to production.

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Type Job: Live well clean out and drill out bridge plugDate: 10 March, 2005Location: Jiao 61-1B Burlington Resources ChinaUnit Type: 225KPressure: 41.7 MPa (6000 psi) shut in; 3.4 MPa (500 psi) well flowingTubing: 2-7/8” 6.5# P-110 8RDWell Depth: 3310 m (10859’)Duration: 6 days (daylight)

Description: • Make up 4-1/2” Blade bit, bit sub, 1 joint, 2 BPV’s, 1 joint and 2.313 X-nipple.• Snub in hole with well flowing at 3 to 4 MPa. Tag top of sand @ 3116 m, clean out using well gas and

water to top of bridge plug @ 3244 m. • Mill out Bridge plug at 3244 m and clean to PBTD, depth of 3310 m.• Snub and Strip out of hole racking back tubing.p g g• Snub and strip in with composite bridge plug and set manually @ 3196 m.• Bleed well to 0 psi and test Casing and plug to 62 MPa, 9000 psi.• Strip out of hole laying down tubing.• Rig down snubbing unit and BOP’s.• Well is ready to perforate and frac

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• Well is ready to perforate and frac.

Questions and AnswersQuestions and Answers

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Documents

Session 208-Mike Lam-20 (Hydraulic-Workover Units-LW Completions)