The Implementation of OGP Report 476 ‘Recommendations …productioneu.offsnetevents.com/uploads/2/4/3/8/24384857/__3... · OGP Report 476 ‘Recommendations for enhancements to

INTERNATIONAL WELL CONTROL FORUM

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The Implementation of

OGP Report 476 ‘Recommendations for enhancements to well control training,

examination and certification’.


• IWCF is a not for profit membership organisation- Approximately 260 members- Those members form branches

• Original Founder Members formed branches in;Denmark, France, Germany, Italy, Netherlands, Norway and United

Kingdom

Background

• Since 2000 new branches in;Europe, Middle East, Russia, Australia, North America and Far East

• HQ in Montrose


• The function of the IWCF was to administer well control syllabi and examinations on behalf of the industry

“ Examination Body”

• IWCF has a global network of accredited centres• Centrally generated exams• Independent invigilation

• Up until 2011 we did not accredit training programmes


IWCF Drilling and Well Intervention ProgrammesPre OGP 476• Drilling

• Three levels• Surface and Subsea

• Well Intervention Pressure Control

• Two Levels• Surface only

• Not Progressive


DevelopmentsPre Macondo


North Sea Offshore Authorities Forum

• Late 2008 Norwegian PSA challenged the NSA and OLF on issues relating to well control competence.

• Joint task force produced a ‘Position Paper’

• Put before NSOAF

• Recognition that more control over the quality of training was required.

• This led to a major change in IWCF’s role


• To ensure that well control training courses are developed and presented consistently, by qualified personnel.

• Formal system of accreditation including

• Course Curriculum and objectives• Teaching Resources• Training Programme

• Retaining independent assessment and examination

Objectives


• From 1st January 2011 all Accredited Centres must demonstrate evidence of ;•Physical resources•Management system•Course outline and lesson plans•Coverage of the entire syllabus•Instructor and Assessor Qualifications

• Audit Programme• Four yearly external• Two yearly internal

• Stopped “Examination only”

Accreditation and Audit of Training


Developments Post Macondo



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Implications of OGP Report 476 ‘Recommendations for enhancements to well control training, examination and certification’. (Referred to as 476)

The IWCF Board has been briefed on 476 throughout its development and has fully endorsed the recommendations and will endeavour to ensure implementation in its entirety.The Board agree that the OGP and the WEC should provide the guidance that our industry needs to maintain self regulation.

In this respect we have taken a holistic, non analytical approach to implementing the recommendations.

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StrategyOur strategic approach has been on a number of levels.

Short Term (End 2013)What we need to do to meet the critical requirements of the recommendations.• Syllabus review to include such subjects as barrier

management, casing, cementing and risk assessment as soon as possible.

• Ensuring that training is role specific at each of the levels.

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Short term (end 2013) plans for existing programmes and new levelsFocus has been primarily on levels 2, 3 and 4 as being the critical areas.

OGP level

IWCF Drilling equivalent

IWCF WI equivalent

1 Well Control Awareness Training

New. 1 syllabus

2 Drilling & Wells Personnel Basic Training

Introductory New

3 Any role expected to shut in a well

Driller Level 1

4 Wellsite Supervisor Training

Supervisor Level 2

5 Engineer/Management Training

New New

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Well Intervention Pressure Control• Syllabus review to include in particular;

• Barrier Management• Risk assessment• Contingency management

• Definition as to which roles the levels applied to;• L2 - Junior operators• L3 - Crew Chief• L4 - Well Services Supervisor

• The new syllabus subjects have been assigned to each level, and content reviewed against 476.

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Well Intervention Pressure Control

• Modules;• Completion Operations• Wireline Operations• Coiled Tubing• Snubbing Operations

• New Syllabus for Subsea Well Intervention/LWI

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Leve

l 1 -

Aw

are

ne

ss

Leve

l 2 -

Bas

ic

Leve

l 3 -

Dri

lle

r

Leve

l 4 -

Su

pe

rvis

or

Leve

l 5 -

We

ll E

ngi

ne

eri

ng

Wellsite ROV personnel (Non Supervisory) P

Wellsite ROV Supervisor 5

Wellsite downhole equipment specialists/operators P

Wellsite Drilling Fluids Engineer / Mud engineer / Completion Fluids Engineer 5

Wellsite Cementing Engineer / Operator 5

Wireline/Slickline crews (Non Supervisory) P

Wireline/Slickline wellsite supervisor, crew chief / lead engineer (Non Pressure Operations) 5

Wireline/Slickline wellsite supervisor, crew chief / lead engineer (Pressure Operations) 2

MPD/UBD wellsite service personnel (Non Supervisory) P

MPD/UBD services Wellsite Supervisor 5

Coiled tubing & intervention services wellsite personnel (non Supervisory) PCoiled tubing & intervention services Wellsite Supervisor (Non Pressure Operations) 5

Coiled tubing & intervention services Wellsite Supervisor (Pressure Operations) 2

Casing running personnel, casing-crew (non-supervisory) P

Wellsite Casing-Crew Supervisor 5

MWD/LWD, Surveying Engineer or Operator P

Directional Driller 5

Other non-supervisory and non-critical drilling or intervention personnel P

Supply and support vessel Watch Officers and Captains P

Tubular and rig inspection personnel P

Oilfield equipment repair personnel P

Fishing Engineer / Fishing tool Operator (Non Pressure Operations) 5

Fishing Engineer / Fishing tool Operator (Pressure Operations) 2

Mud Logger/ wellsite Drilling Data Engineer 5

Positions normally associated with well equipment, service and

other support companies


Examinations• Our current Question Bank is in the process of being

reviewed to;• Create and assign questions to specific roles.• Raise the taxonomic level of the questions to remove

the “name the parts” to;• What does it do?• How do I operate it?• How do I know it has worked?• What do I do if it doesn’t?

• Development of online testing25


Critical KnowledgeIn both programmes there will be a “critical knowledge” component in both the training programme and assessment methodology.

Practical Assessment

Introduce an element of practical assessment to WIPC

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Level 1 (Awareness)• Syllabus published• We believe that the training should be a general

awareness of operations, then a focus on well control.• It should encompass anyone who has direct dealings with

operations;• Logistics.• HSE.• HR.• Support staff.

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Level 5 (Well Engineering)• Syllabus under development;• Modular to take into account all roles.• Focus on Well Integrity throughout the lifecycle of the

well

• Oil and Gas UK Competency Guidelines used as a model

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Medium TermImplementation of “Enhanced Certificate renewal” training with emphasis on;• Case studies• Simulation• Scenario based training• Continued renewal of syllabus based around;• Changes in equipment and practices• Incident data

Implementation of HFTF P 2 Crew Resource ManagementIWCF continues to be involved in the development of CRM for Well Operations

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Medium Term

Training and Assessment will be;

• Role Specific• Progressive• Evolutionary

Focus on the “Quality of Learning”;

• Competency of Instructors

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We Remain

• Independent• Democratic• Representative of all sectors of our industry• Truly ‘not for profit’ -all surplus funds are reinvested to

serve our primary mission

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IWCF is an industry body, here to serve your needs.

To do that we need industry support.

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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

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Wireline Engineering’s Roller Bogie Solution

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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

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Features & Functions.wmv


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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

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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

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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

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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


• Knuckle Joint


• Tubular Jar


• 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”

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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

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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

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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

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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 $$$$

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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

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2011-504-WE_AKT_WIP_v1_101.mp4

2011-504-WE_AKT_WIP_v1_101.mp4

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

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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

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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

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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

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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

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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

The Implementation of OGP Report 476 ‘Recommendations …productioneu.offsnetevents.com/uploads/2/4/3/8/24384857/__3... · OGP Report 476 ‘Recommendations for enhancements to

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