Embed Size (px)
Citation preview
Offshore Well Intervention
Conference 2014
Technology & Approach for the North Sea
Managing Friction,
Extending the range of Wireline
Presenter, D.Mitchell,
Product Development Director, Wireline Engineering
Agenda
Company Introduction
Product Line Summary
Product Benefits
Case Histories
Questions
Wireline Engineering
Scottish SME with a Global Footprint
o 16 years of history in the Global Well Intervention Arena
o Strategic presence in key Oil & Gas Hubs
o All facets of Engineering from Design & Manufacture to Test & Service
3
Wireline Engineering’s Roller Bogie Solution
4
What is a Roller Bogie?
o Simple, Robust mechanical tool string conveyance device
o Relies on gravity alone
o Based on ‘unique’ patented body geometry, self orienting
o Conveys toolstring along the low side of a well
5
6
How does the Market Benefit?
o Closely aligned with Stakeholder’s Intervention Risk Management Strategy
Supports tool string, Creates Clearance - Eliminates Friction
Reduces pick-up weight
Increases run-in weight
Improves tool string visibility at surface
Enables longer / heavier toolstring conveyance, Eliminates runs
Increases range of intervention in deviated & tortuous wells
Reduces slip stick, improves log data quality
Improves load transfer whilst jarring at high-angle
Roller Bogie Technology Enables access to areas in a well normally associated with more costly
intervention methods - SAVING $$$ AS A RESULT -
A Step Change in reducing Intervention Risk Profile
7
CASE #1
Cased Hole E-Line Roller Bogie – Product Intro
o Roller Bogie conveys toolstring to high-angle targets in tubing and liner
Robust In-Line Multi-Roller arrangement assembled around a mandrel conduit
Industry standard monoconductor, multiconductor and perforating connections
Multiple Roller Bogie units are connected at strategic points to support toolstring
components
20+ sizes available to suit different tubing and toolstring scenarios
8
CASE #1
Cased Hole Roller Bogie – Well Scenario
Middle East (ref SPE113655 Pushing Wireline Operations to New Frontiers)
o Wireline operations restricted to <65 degrees
o 1st in a planned 3 well field trial campaign
o Offshore oil producer, 6.1/8” hole, 4.1/2” cemented liner
o Accidental side-track thru a high water sat zone from 8,110ft to 8,240ft
o Plugged back and trajectory adjusted, eventual TD at 9,154ft MD at 87deg
max deviation
o Accidental side-track isolated with 4.1/2” liner but not plugged and cemented
o Well Completed with 3.1/2” plastic coated tubing
o Well watered-out shortly after flowing back
o Decision taken to run a Cement Bond Logging Tool to determine the location
of water influx
9
CASE #1
Cased Hole Roller Bogie Deployment
Middle East
o Run#1: 2.400” Slickline Roller Bogie Drift Toolstring
o Reached 8,393ft at 80deg deviation
o Run#2: 2.600” E-Line Roller Bogie Cement Bond Toolstring
o Reached 8,406ft at 80deg deviation, logging pass executed
o Log data analysed, indication of good cement around accidental sidetrack area,
as well as rest of casing string
o Successful outcome proving the viability of running Roller Bogie in
comparison to CT or Tractor, saving $$$$
Run #1
Slickline Roller Bogie Drift Toolstring
• Rope Socket
• Slickline Roller Bogie, 2.400”
• Stem
• Slickline Roller Bogie, 2.400”
• Knuckle Joint
• Slickline Roller Bogie, 2.400”
• Tubular Jar
• Slickline Roller Bogie, 2.400”
• Knuckle Joint
• Stem
• Fluted Drift, 2.600” O/D
Run #2
E-Line Roller Bogie CB Log Toolstring
• Cable Head
• E-Line Roller Bogie, 2.600”
• Weight Bar
• E-Line Roller Bogie, 2.600”
• Cement Bond Logging Tool
• Guide Roller Bogie, 2.600”
10
CASE #2
Cased Hole Roller Bogie & Low Loader Deployment
Middle East
o 2nd and 3rd wells in the 3 well field trial campaign
o Land oil producers, 4.1/2” completion
o Ceramic Disk Rupture Operation
o Slickline Roller Bogie Toolstring with Low Loader Jar and Chisel
attachment
o Well #1: Successful rupture of disc at 7,639ft located at 81 degrees
o Well #2: Successful rupture of disc at 8,510ft located at 79 degrees
o Operating Company had been using Coiled Tubing for these types of
operations for >65 degrees
o Four days were budgeted in the programme for a CT operation of this
type
o Only one day was spent per well using Slickline and Roller Bogie
Costs were reduced by 60% per well
11
CASE #3
Open Hole E-Line Roller Bogie – Product Intro
o Conveys toolstring to high-angle targets in an open hole environment
Robust In-Line Multi-Roller arrangement
Clam Shell Body Arrangement
Industry standard multiconductor connections
Multiple Roller Bogie units are connected at strategic points to support toolstring
components
Selection of sizes available to suit different hole size and toolstring scenarios
12
CASE #3
Open Hole Roller Bogie Well Scenario
Far East
o Open Hole Logging up to 62 degrees in Malaysia
o Predictive software indicated that logs could only be deployed using pipe-conveyed Vs gravity deployed
wireline method
o 8.1/2” hole, 9.5/8” shoe set at 1,750ft building to a max deviation of 62deg at 5,890ft
o TD at 8,090ft leading to 6,240ft of 8.1/2” to negotiate
o 2 runs planned, Borehole Imaging Tool & Reservoir Sampling Tool
13
CASE #3
Open Hole Roller Bogie Deployment
Far East
o Open Hole Roller Bogies enabled logs to be deployed using wireline, 2 In-Line OHRBs and 1
Holefinder OHRB utilised
Run#1: 118ftlg Borehole Imaging Tool deployed successfully, no over pulls recorded,
good quality logs obtained
Run #2: 84ftlg, max O/D 5.284” Reservoir Sampling Tool deployed, hung up at 5,890ft
at a ‘hump’ in the well
Toolstring retrieved, max O/D section halved in length and then re-run.
Deployed successfully without incident, constant head tension recorded during logging
passes good quality data obtained
Significant rig hours saved, saving $$$$
14
CASE #4
Advanced Kickover Tool (AKOT) – A Systems approach
o AKOT Enables high-angle Kickover Tool Operations
Friction is minimised throughout the Tool, efficiencies maximised
Integral Swivels, Roller Subs & Balanced Tray Concept ensures smooth operation
Low Loader positioned above transmits high-efficiency Jarring Force
Slickline Roller Bogies positioned within toolstring above maximise weight transfer
whilst jarring
Greatly improves visibility at surface, critical toolstring manipulation is well defined
15
CASE #4
Advanced Kickover Tool – Well Scenario
UKNS
o 5.1/2” Gas Lift Completion
o 3 Gas Lift Mandrels in completion string
o Max deviation 73 degrees at 4,157mtrs (13,300ft)
o 1.1/2” MMRG Unloading Valves with RK Latches
o Bottom Mandrel located at 3,331mtrs ( 10,700ft)
o Lower Gas Lift Mandrel positioned aro 70deg deviationSIDEPOCKET MANDRELLATC H RK 1 1/ 2 "
Unloading 2 0 / 6 4 t hs
C AMC OMMRG
4 .7 15 8 .0 132 6 2 2 18 7 8
SIDEPOCKET MANDRELLATC H RK 1 1/ 2 "
Unloading 12 / 6 4 t hs
C AMC OMMRG
4 .7 15 8 .0 1313 5 4 12 4 9
COMMUNICATION SUB PESC S
4 .6 2 5 8 .2 5 0
ANNULUS VALVE9 .5 / 8 " x 5 .5 "
PESAV2 C APS
4 .7 5 0 8 .4 7 53 5 1 3 5 1
TRSCSSSV ( TFVE 8 9 9 )5 .5 " C om plet e wit hPet ro line 4 .5 7 8 " QN Prof ile
B OTTSME- 5
4 .5 7 8 7 .7 0 03 2 4 3 2 4
TUBING HANGERC / W Pet ro line 6 .18 7 QN Prof ile
C AMERON 6 .18 7 13 .5 32 7 2 7
SPF PHSZONE INTERVAL STATUS GUN TYPE DATE
MSM 5 0 7 0 - 5 0 8 9 Open 3 .3 / 8 " HSD 4 13 0 4 / 10 / 0 3
MSM 5 0 9 2 - 5 111 Open 3 .3 / 8 " HSD 4 13 0 4 / 10 / 0 3
MSM 5 111- 5 117 Open 3 .3 / 8 " HSD 4 13 0 3 / 10 / 0 3
MSM 5 12 0 - 5 13 0 Open 3 .3 / 8 " HSD 4 13 0 3 / 10 / 0 3
MSM 5 13 0 - 5 13 8 Open 3 .3 / 8 " HSD 4 13 0 3 / 10 / 0 3
MSM 5 13 9 - 5 14 2 Open 3 .3 / 8 " HSD 4 13 0 3 / 10 / 0 3
MSM 5 14 3 - 5 14 8 Open 3 .3 / 8 " HSD 4 13 0 3 / 10 / 0 3
WELLHEAD DATA
RATING ( psi)FLANGES ( in)B ORE ( in)TYPEMAKER
XMAS TREE C AMERON SINGLE B LOC K 6 .3 7 5 R4 6 x R5 0 5 0 0 0
ADAPTOR FLANGE C AMERON 5 P Seal 6 .3 7 5 R5 0 x B X15 9 5 0 0 0
TUBING SPOOL C AMERON 2 STAGE 12 .3 8 0 B X15 9 x R7 4 10 0 0 0
TUBING HANGER C AMERON SINGLE 6 .18 7 10 0 0 0
( LB / FT) TVDMDC ONN.GRADEWTSIZE ( in)
LINER DATA
CASING DATA
SIZE ( in) WT GRADE C ONN. MD TVD( LB / FT)
3 0 3 10 X5 2 LYNX/ MER 3 8 6 3 8 6
18 5 / 8 8 7 .5 K5 5 B UTT 8 7 6 8 7 0
13 3 / 8 7 2 N8 0 B UTT 112 5 10 8 9
9 5 / 8 4 7 L8 0 N VAM 2 8 7 0 19 9 6
9 5 / 8 5 3 .5 L8 0 N Vam 3 4 7 4 2 2 9 1
5 1/ 2 17 13 C r L8 0 V TOP HT 5 2 6 3 2 9 9 7
HUD:
FIRST C OMPLETED:
COMMENTS
DEPTH UNITS:
REF. LOG:FLUID WT:
ANN. FLUID:
KOP:
RTE:
SWAB :
MAX. DOGLEG:
MAX. DEVIATION:
AV. ANGLE THRU PAY:
WORKOVER NO:
WORKOVER DATE:
PLATFORM:FIELD:
O.D.
MAX.
I.D.
MD
BRT
TVD
BRT
MIN.
WELL NO.
TYPE
MAKER/DESCRIPTIONWELL SCHEMATIC
@
@
DATE:C HEC KED B Y:PREPARED B Y:c PETROTEC HNIC S LIMITED
WELL TYPE:
WELL STATUS RECORD
MINIMUM I.D.: @
2 1 1 / 1 2 a MAGNUS A2 ( M5 1 )
GAS LIFT PRODUCER
15 .07 .84
Sep 2003
4
TREATED SEAWATER
1.03
5 7m AMSL
2 5m MDbr t
113 8m MDbr t
5 218m MDbr t
METRES
GR/ NDEN 1st Pass 17 / 9 / 03
4 .2 3 7 3 3 m
69 4 079 m
6 8 deg
4 .5 78 " 3 2 4 m MDbrt
D Milner D Irvine 0 7 .10 .2003
5 1 / 2 " TUBING17 lb / f t 13 C r L8 0
VAM TOP HT 4 .8 11 6 .0 5 0
5 1 / 2 " TUBING17 lb / f t 13 C r L8 0
VAM TOP HT 4 .8 11 5 .9 7 8
5 1 / 2 " TUBING17 lb / f t 13 C r L8 0
VAM TOP HT 4 .8 11 5 .9 7 8
SIDEPOCKET MANDRELLATC H RK 1 1/ 2 "
Or if ice 2 4 / 6 4 t hs
C AMC OMMRG
4 .7 15 8 .0 133 3 3 1 2 2 2 0
SB- 3 H PERMANENT PACKER9 5 / 8 " x 5 1/ 2 "
B OT 4 .7 5 0 8 .2 5 03 3 5 1 2 2 3 0
G2 2 NON- SEALING LOCATOR B OT 6 .0 5 9 7 .3 10
UNIFLEX LINER HANGER SYSTEM B OT 7 .3 7 5 8 .2 5 0
9 5 / 8 " CASING SHOE
TOP LINER HANGER PBR B OT 6 .0 5 9 7 .3 103 3 8 3 2 2 4 6
Lin er TD5 2 6 3 2 9 9 7
7 " X 5 1 / 2 " XO SUB
All t ub ing used in t h is com plet ion is 5 .5 " 17 lbs/ f t
13 C r L8 0 Vam Top HT. Tubing Dr if t : 4 .7 6 7 "
Annulus vo lum e t o packer : 4 8 2 bbls
Non- sealing locat or pu lled back 2 m f rom landout
po int . B ot t om of locat or at 3 3 8 7 m
Volum e t o t op per f at 5 0 7 9 m m dbr t ( 2 9 11Mt vdbr t ) :
3 8 6 bbls
16
CASE #4
Advanced Kickover Tool Deployment
UKNS
o Gas Lift intervention AFE ‘d at 2.75 days
o Industry standard Kickover Tool had mixed success during 2 separate Operations
Op1: Deviation and suspected well debris led to multiple mis-runs and failure to latch
GL Valve
Op2: Standard KOT was run once again, Valve retrieved and new Valve set after a
number of mis-runs
Op2: During retrieval of next Valve, standard KOT toolstring became stuck resulting in
10 days NPT (fishing)
o AKOT, Low Loader and Roller Bogie Toolstring mobilised
o AKOT toolstring was used to successfully work-over all remaining
Gas Lift Mandrels with no further issues recorded
Advanced Kickover Toolstring
• Rope Socket
• Slickline Roller Bogie
• Stem
• Slickline Roller Bogie
• Power Jar
• Low Loader
• Advanced Kickover Tool
17
CASE #4
Advanced Kickover Tool Deployment
Elsewhere
o Other Geographical Regions where AKOT and associated Low Friction Technology are providing real
benefit include:
Malaysia, recent success with NOC & IOC changing -out GL Valves at up to 78deg
Norway, where Gas Lift remediation is a regular occurrence and AKOT is included within
standard operating procedure for a number of assets, known success up to 74deg
Russia, GoM, Canada, Indonesia & Brunei
Advanced Kickover Tool Reduces Mis-Run
Risk is managed effectively and REAL COST $$$ SAVINGS ARE REALISED
18
o
CASE #5
Roller Bogie Cutter & Dropbar – Product Intro
o Incorporates Roller Bogie®Technology to enable high-deviation well access
Features:
Industry standard ‘rotating knife’ cutting mechanism
Anti-vibration feature (prevents premature cut)
Fast Load and Lock
19
CASE #5
Roller Bogie Cutter & Dropbar Deployment
South America
o E-Line logging toolstring stuck, 5/16” mono cable back to surface
o 7” completion in a gas environment
o Long step-out 63 degrees from E.O.B at 2,400ft to fish at 11,860ft MD
o Cutter and Dropbar mobilised from Aberdeen to S.America, aro. 1 week to
reach well site
o Bogie Cutter operated effectively first-time by Dropbar
o Cutter and Dropbar returned on cable without the need for additional runs
20
THANKS FOR YOUR ATTENTION!
OPEN HOLE LOGGING
CASED HOLE LOGGING
INFLATE SETTING
PERFORATING
PACKER/PLUG SETTING
CUTTER DEPLOYMENT
CABLE WEIGHT
MEMORY LOGGING
SHIFTING SSD
GAS LIFT
TRACTOR ASSIST
