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NeoDrill Yes, we CANTM!


CAN-Technology Presentation

OGTC Showcase Event Aberdeen 22/08/17

By Fred Hardinges Tel : 07538 426 049

Email : [email protected] August, 2017

www.neodrill.com

http://www.neodrill.com/


Conventionally drilled and cemented Conductor Instability

23.08.2017 2

Insufficient cement support of the

conductor for whatever reason

may result in :

• Lack of conductor structural

integrity (axial, accidental etc)

• severe well barrier integrity

issues («gas on the backside»)

• Increased Rig NPT due to

remedial operations to try and

rectifiy the above issues

• In worst case lead to a Re

Spud....

• Potentially more challenging

P&A ops resulting in NPT

The use of CAN based top hole

well construction mitigates

most, if not all, of the all above

Confidential


• CAN = Conductor Anchor Node • A pre-rig installed well foundation to replace a conventional

conductor for exploration wells. • A CAN can also serve as a a single production well template, or in

a Dual CAN configuration for a 2 well template

23.08.2017 Confidential 3


CAN = A better Top-hole Well Construction Method

4

Conductor: Coventionally installed and cement by Rig on critical path

CAN ductor : Vessel installed AHEAD of Rig arrival off critical

path

23.08.2017 Restricted Distribution

? AXIAL LOAD CAPACITY ?

? LATERAL LOADS? ? BENDING?

? VERTICALITY ?

VERIFIED LOAD CAPACITY SMALLER SPUD BHA SIMPLIFIED P/A

RISK MITIGATION SHALLOW KICK OFF FATIGUE MANAGEMENT

SAVES 3-4 RIG DAYS

? FATIGUE ?

Idealized as no

“guarantee” that the

conductor is vertical and

concentric within the 36 or

42” HS which is usually

drilled in v soft fmts,

therefore, not optimum for

cementation, well integrity

or well fatigue life

Cement ?


23.08.2017 CAN Technology Presentation 5

Conventional top hole well

construction gives Unpredictable results with potentially more associated

risks /cost overruns

CAN Conductor well

construction Gives Predictable results / costs and virtually eliminates all historical top hole well construction risks


How / When is a CAN Installed ? Offline from the rig’s critical path by Light Well Intervention Vessel

• Vessel requirements

– DP

– AHC Crane ≥ 150 ton

– Work ROV

– Surveying services

• On Location time < 24 Hrs

• Multiple CAN installation/ recovery campaign will significantly improve cost efficiency



P&A ?? – the CAN is FULLY recoverable

together with the LP and HP WH’s.

• Casing cutting – CAN Basic

Conductor & Surface Casing only

– CAN-ductor Surface casing only

• ROV pump out CAN

• Vessel retrieves the CAN

• Prepare CAN for next job the CAN is fully reusable!



Required Soil Information to determine CAN configuration (mainly its length)

• Ideally CPTs from a site specific survey as deep as possible Undrained

shear strength – see example below:

Note : In absence of site specific data offset / analogue data can be use.

• Clay sensitivity – Would require cores and lab tests

– Usually values from literature are used (range which define LB and UB values)



CAN Track Record to Date 15 Successful CAN installations to date for :

• 14 Exploration wells on NCS

• 1 Production well on UK CS

Therefore, the use of CAN Technology is a well PROVEN field technology !

Water Depth Settings • Shallowest: WD 125 m

• Deepest: WD 1,444 m

The use of CAN Tech is NOT water depth dependent !


To increase the knowledge and awareness of CAN Tech on the UK CS Neodrill and ITF have set up a CAN related Joint Industry Project (JIP) which is kicking off in the very near future .

Confirmed Participants are 4 active Operators on the UK CS


CAN installations detailed data



VALUE REALISATION / EXECUTION PHASE

VALUE IDENTIFICATION /ADDING PHASE

VALUE

TIME

Excellent Project Execution

Set Up for Success?

S P UD

Planning Phase Drilling Execution Phase

Value Erosion (Rig NPT) can be highest in the top hole well construction phase for a wide range of well documented reasons, which in worst case can lead to a very costly Re Spud.

In addition the well P&A phase can incur significant Value Erosion / Rig NPT , particularly due to consequences of remedial cementations in the conductor phase of the well.

Use of a CAN for Top Hole Well Construction mitigates the well documented potential sources of NPT / Value Erosion in this crucial Phase of the well



3 Main CAN Options Avaialable CAN-slender

c/w Preinstalled LP and HP wellheads

Drill slim wells ( no 30” or 20” HS), spud with 17 ½” BHA

with returns to seabed


CAN Main Options


1. CAN Basic (Problem solver)

– Very soft seabeds

– Drill and cemeted Conductor / Conductor jetting hang off point


Field Example – Ivory 1,444 m waterdepth Enabling technology for reducing potential NPT and well

cost savings and landing off a short jetted conductor


Objectives • Engineered load capacities

• CAN installation in very soft seabed

• Shorter conductor

• Jetting and drill ahead w/o conductor soaking rig time

• Saved 3-4 rig days

• Risk mitigation

• Easy P/A No NPT !

Achievements • All of the above

CAN top after jetting completed Conductor Hanger landed in CAN


Information from the offset Pilot Hole used to determine the length of the Jetted In Conductor

16

More Competent Formation – evaluated as not “jettable”

1 x 36” DQ Wellhead housing with 36” x 2” WT Wellhead extension with XO to 30” D-90 MT DQ conn

2 x 30” Conductor Joints with “Slim” D-90/MT DQ conns 1 x 30” Open Shoe Joint with D-90/MT DQ conn

Total Conductor Length : 49.82 m !!

Optimized Conductor Length and Configuration

CAN

Without the “structural support” of the CAN this short length of Conductor would not have been viable so Jetting would not have been an option, with all its associated

operational benefits, at this location.


17

• Bit / bit nozzle space out critical relative to the tip of the conductor

• Spaced out with pup joints and subs rather than having to cut conductor

DQ CADA Tool Conductor and Jetting BHA Configuration

and Jetting Plot

Conductor with open Shoe

Cutting Return Flow Path


CAN Main Options

2. CAN-ductor (Cost Cutter)

– Conductor Pre-installed in CAN in the workshop


Best Ever 30” Cement Job !!


Field Example – OMV Wisting, Barents Sea (CAN ductor) Enabling technology for shallow reservoir deveopment


Objectives • Drill to shallow target 250m(750ft) below

seabed in a WD of 402 m.

• Demonstrate field development capability

• Risk mitigation

• Save 3-4 rig days

• Easy P/A

Achievements • ALL objectives successfully achieved and

• Field development feasibility demonstrated based on a CAN-ductor top hole well design

• WORLD RECORD: Shallowest horizontal well drilled from floater ever

• SPE Engineering achievement of the year 2016 “Sump” is a

potential water block for production


Future CAN Basic Options

• CAN-ductor pre-bent

– Slender hole


• CAN-ductor pre-bent

– Conventional


As an enabler to to drill slender / finder wells

‘CAN-slender’

• LP WH integral part of CAN (= HP WH receptacle)

• HP WH joint installed in CAN in the workshop

• Benefits

• Pre-installed rig-ready HP WH • No 30’’ & 20’’ sections • No top-hole cementing • 17 ½‘’ Spud BHA (returns to seabed) • Full string of 13-3/8" "surface casing"

permits a DST with 9-5/8" liner design as no XO to 20» or 18 3/8» to reduce pressure rating.

• Easier and faster P&A



Conventional «slim»Top-Hole Design

Reduced burst pressure surface casing. Above XO Therefore, requires full 9 5/8” string for DST / drlg a pressure ramp etc.



CAN-Technology Presentation OGTC Showcase Event

CAN as a foundation for SS Production Wells

Aberdeen 22/08/17

By Fred Hardinges Tel : 07538 426 049

Email : [email protected] August, 2017

www.neodrill.com

http://www.neodrill.com/


CAN for SS Production Wells

Confidential - Presentation to OD 25

• CAN is essentially a one-well template for small field / infill wells

Dual CANS = 2 well template Pre-rig arrival tophole well construction Pre-rig arrival SPS installation

• Over-trawlable structure integral part of CAN • Fatigue management

23.08.2017


Conventional SS development is rig dependent

23.08.2017 DEAe Meeting 03.03.17 - Aberdeen 26

Main Challenge for the above conventional process is Rig Dependency throughout the

project – which usually = “delays” to production start up for a wide variety of reasons

= reduced project NPV !

R i g Dependen t


CAN based SS development is “Rig Independent”

23.08.2017 27

20 ?? days 5 MM USD

(5000 bbls/day @ 50$/bbl)

R i g Dependen t

= improved project NPV

R i g I ndependen t


CAN-based (Single, Dual or Daisy Chain)

Subsea Development • Optimal well placement and reservoir drainage

• Early / accelerated production

– Reduced rig dependence – Improved planning and scheduling

• Shallow / “Stranded” / compartmentalized /reservoir enabler

• Cost effective design and installation

– reduced footprint, weight reductions, smaller installation vessels

– Integrated manifold and protection structure

• Reduced rig scope of work = Cost reduction – Pre installed top hole section (install from smaller vessel) – Drill shorter and less complicated wells



Proven Technologies - Combined


CAN-ductor showing the LP WH

Protection Structure Flowbase


Installation (Ahead of Rig Arrival)

• CAN installation by Light Well Intervention vessel and ROV as usual

• Flowbase and protection structure integrated into CAN by Light Well Intervention vessel and ROV

• Proven track record of all elements


CAN


Drilling Phase

• Rig opens cover, runs BOPs and performs drilling operations.



SURF Work (AHEAD of rig arrival)

• Laying of flowlines and control cables

• Only one vessel mobilization ahead of rig arrival to fully utilize the operational and cost synergies for CAN and SURF installation


CAN


Completed System

• Rig closes protection structure and leaves site with well ready to produce

• 3-8 weeks of accelerated production

– 5000 bbl/day

– 50 USD/bbl

– 9 MM USD (5 weeks)




CAN Integrator for SS Production wells video


CAN’s Value Proposition

23.08.2017 35

Superior Technical Solution (BAT: Best Available Technology)


How the use of a CAN Conductor can mitigate several low probability but extremely high consequence HSE risks

associated with a conventional top hole well construction using a drilled and cemented conductor



HSE RISK NO.1 Dropping a conductor joint on the DF


Use of a CAN mitigates this potential Risk



HSE RISK No.2 conductor joint bend over making BOP disconnect / installing a capping

stack problematic / impossible

Use of a CAN mitigates this potential Risk

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