riserless subsea well abandonment...

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© 2016 BAKER HUGHE S INCORP ORATED. ALL RIGHTS RESERVED. TERMS AND CONDITION S OF USE: BY ACCEPTING THIS DOCUMENT, THE RECIPIENT AGREES THAT THE DOCUMENT TOGETHER WITH ALL INFORMATION INCLUDED THEREIN IS THECONFIDENTIAL AND PROPRIETARY PROPERTY OF BAKER HUGHES INCORPOR ATED AND INCLUDES VALUABLE TRADE SECRETS AND/OR PROPRIETAR Y INFORMATION OF BAKER HUGHES (COLLECTIVELY "INFORMATION" ) . BAKER HUGHES RETAINSALL RIGHTS UNDER COPYRIGHT LAWS AND TRADE SECRET LAWS OF THE UNITED STATES OF AMERICA AND OTHER COUNTRIES. THE RECIPIE NT FURTHER AGREES THAT THE DOCUMENT MAY NOT BE DISTRIBUTED, TRANSMITTED, COPIED ORREPRO DUC ED IN WHOLE OR IN PART BY ANY MEANS, ELECTRO NIC, MECHANICAL, OR OTHERWIS E, WITHOUT THE EXPRESS PRIOR WRITTEN CONSENT OF BAKER HUGHES, AND MAY NOT BE USED DIRECTLY OR INDIRECTLY IN ANY WAY DETRIMENTALTO BAKER HUGHES’ INTEREST.

Riserless Subsea Well Abandonment Methodology

Bart JoppeMay 26th, DDW2016

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Oil & Gas UK Category 1 Well

￭ All annuli & casing isolated

￭ No intervention required

20” Shoe

13 3/8” Shoe

9 5/8” Shoe

Source: Oil & Gas UK, Guidelines for the suspension and abandonment of wells, Issue 4, July 2012

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Oil & Gas UK Category 2.1 Well

￭ Oil & Gas UK Guidelines require aMinimum of 100 ft. of Cement

￭ Category 2.1 – The well has oneannulus uncemented

20” Shoe

13 3/8” Shoe

9 5/8” Shoe

Squeeze Possible

Squeeze NotPossible


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Oil & Gas UK Category 2.2 Well

￭ Oil & Gas UK Guidelines require aMinimum of 100 ft. of Cement

￭ Category 2.2 – The well has two annuliuncemented

20” Shoe

13 3/8” Shoe

9 5/8” Shoe

Squeeze Possible

Squeeze NotPossible

Squeeze Possible


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Wellhead Abandonment Straddle Packer (WASP)

￭ Uses inflatable elements to cover a range of casing sizesand weights

￭ Accommodates two sets of perforating guns to selectivelyperforate and cement two casing annuli

￭ Incorporates failsafe valves for emergency shut-in

￭ Project Managed team to plan and execute campaign

￭ Quick operation and provides financial benefits toalternative methods. (single trip)

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WASP – Run in Hole

Category 2.2 Example

￭Drift and Scraper run performed before WASPdeployment

￭Run Tubing Conveyed Perforating (TCP) Guns andhang off in moonpool.

￭Connect Guns to WASP

￭RIH to land-off in the wellhead.

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WASP – Inflate & Test Packers

￭ Inflate Upper and Lower Packer.

￭Pressure test

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WASP – Perforate A - Annulus

￭ Perforate through casing into ‘A’ Annulus.

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WASP – Flush & Cement A-Annulus

￭Circulate well fluids to surface.

￭Spot Cement into ‘A’ Annulus and hold.

￭Wait on Cement (WOC)￭ Cement hold time will be determined by Baker Hughes onshore

Sample Test.

￭Pressure test

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WASP – Perforate B-Annulus

￭ Perforate through cement and casing into ‘B’Annulus.

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￭Circulate well fluids to surface.

￭Hydraulically Disconnect Lower Guns

WASP – Establish Circulation, Drop Guns

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WASP – Cement B-Annulus

￭ Displace a balanced cement plug across the ‘B’annulus and main bore

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WASP – Deflate Elements

￭Wait on cement (WOC)

￭Pressure test

￭Deflates Packers

￭Pull Out of Hole (POOH) with WASP

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Benefits of WASP over Conventional Methods

￭ Conforms to UK Oil & Gas Guidelines for the Abandonment of Wells

￭ Vessel Workscope allows quick mobilisation and set-up at wellsite

￭ Vessels Use Dynamic positioning to stay on location

￭ Lower cost alternative to Rig hire

￭ No Diver Intervention Required

￭ Small Equipment footprint in comparison to rig based alternative

￭ Project Managed Collaborative team

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Vessel Requirements

￭ Dynamic Positioning Capability (>DP2)

￭ Moonpool for WASP and Severing Equipment deployment

￭ Crane with Capacity of 100Te is preferable

￭ Adequate Deck Space

￭ Storage Capacity for OBM

￭ Accommodation for WASP and Severance Crew (WASP Team, 9 Minimum for 24

hour Ops)

￭ ROV capability (Work Class, Minimum x 1)

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Suspended Well Abandonment Timeframe

Phase Days

Onshore Quayside Prep 2

Transit 1

WASP - 2.1 2

Abrasive Severance 1

Transit * 1

Demob 1

Total 7

Basic 2.1 Job Timeline (1 well)

Phase Days

Onshore Quayside Prep 2

Transit 1

WASP - 2.2 3


Transit * 1

Demob 1

Total 9

Basic 2.2 Job Timeline (1 well)

Phase Days

WASP - 2.1 2


Transit 1

Total 4

Additional 2.1 well (After *)

Phase Days

WASP - 2.2 3


Transit 1

Total 5

Additional 2.2 well (After *)

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Batch and Multi-Well

How do we tackle Suspended Wells more efficiently?

Example 2015 – Two North Sea Customers required for the final Phase 3Abandonment of wells (WASP and Severance of 5 Wells)

Customer A : 4 Wells Customer B – 1 Well

1 x Cat 2.1 1 x Cat 2.1

3 x Cat 2.2

Same Vessel, Same Contractors BUT Separate Contracts

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Future – Where Next

￭ Collaboration between Operators – Inventive Commercial Models

￭ Remove Unnecessary Mob/Demob costs

￭ Gain Efficiencies through planned sharing of Workscopes

￭ Resource Sharing between Contractors

￭ Industry push for tackling multi-well, multi-operator campaigns

￭ Batch work so that rig only completes the plugging of the reservoir. Vessel for Finalplug and Wellhead Removal.

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￭ www.bakerhughes.com/wellabandonment

Riserless Subsea Well Abandonment Methodology

riserless subsea well abandonment...

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