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Live Well CompletionsLive Well Completions
Hydraulic Workover Units (HWO)Hydraulic Workover Units (HWO)
1
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
2
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.
Mechanics of Hydraulic Workover
y• Cudd’s Hydraulic Rig Assist Unit
has a passive rotary - requires PDM or power swivel for rotational
i trequirements
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Mechanics of Hydraulic Workover
• Stationary and Traveling Slips are both engaged at beginning
Mechanics of Hydraulic Workover
are both engaged at beginning of snubbing stroke.
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Mechanics of Hydraulic Workover
• Stationary Slips are disengaged• With Traveling Slips engaged, the
Mechanics of Hydraulic Workover
With Traveling Slips engaged, the hydraulic cylinders are extended retracted - lowering the tubing - and completing the stroke.
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Mechanics of Hydraulic Workover
• At completion of downward stroke, the stationary slips are engaged
Mechanics of Hydraulic Workover
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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Mechanics of Hydraulic Workover
• Process is repeated as the tubing is snubbed through the
Mechanics of Hydraulic Workover
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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Ram to Ram HWO Procedures
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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Ram to Ram HWO Procedures
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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Ram to Ram HWO Procedures
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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Ram to Ram HWO Procedures
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
25
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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Case History #6 – Live Well Completion
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.
29
Case History #7 – Live Well Completion
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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