SPE Facilities Group Technical Evening
Transcript of SPE Facilities Group Technical Evening
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SPE Facilities Group Technical Evening
Australia’s offshore well decommissioningApplication of global lessons learned
Christopher MurphySenior Research [email protected]
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Agenda
1. Offshore O&G well decommissioning liabilities & practices
2. Well decommissioning compliance
3. Cap rock restoration explained
4. Cost saving opportunities – Australian well decommissioning
5. CUWIM 1 - Forecast cost estimate
6. Summary
1 CUWIM = Curtin University Well Inventory Model
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Well DecommissioningPreviously known as permanent well abandonment or P&A
RiglessWorking on a well without the use of a conventional drilling or workover rigWireline and fluid circulating systems are the primary methodsCoil tubing and hydraulic workover unit are also classed as rigless
RiserlessWorking on a subsea well without the use of a riser back to surface
Cap Rock Restoration (CRR)Restoring the reservoir cap rock to pre-drilling /geological condition
Definitions
RR = Rigless / Riserless
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Offshore O&G well decommissioning liabilities & practices
Australia
UK
USA GoM
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USD 16.6 billion (41%)
1,008 wells
USD 16.5 million / well
Total Liability USD 40.5 billion
Offshore Oil and Gas Decommissioning Liability (Australia)ADVISIAN Exec Summary (10 Mar 2020)
Average cost indicates a rig operation
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Advisian - Cost reduction opportunity (Wells)
The following three factors combined would provide an estimated USD 4.1 billion saving:
1. A dedicated P&A workgroup to share lessons learned, pre-screen wells, optimize the execution schedule and ensure continuity of the work schedule (even mini-campaigns); Collaboration
2. Given the sheer volume of wells and a focused effort, it is conceivable that application of a ‘Technical Limit’ approach (best possible performance, limited only by technology and nature) could provide at least 1.2 days saving in operations optimization per well; Technical Limit
3. It is also conceivable that suitable application of new technology could also provide at least a 1.0 day saving in operations per well. New Technology
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12,375
4,981
7,394
4,158
3,236
1,487
Total records indatabase
Duplicate recordsremoved
Unique well records Wells already decom Remaining wells to bedecom after 2020
Wells in <100m ofwater
Wells Decommissioning Liability (UK)
Source: UK OGA borehole database statistics (Jan 2021)
UKCS Wells Liability USD 40.1 billion
USD 12.4 million / well (UK)~25% less than Australia
46% in water < 100m
Average cost indicates a rig operation
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54,736
17,505
37,231
25,713
11,518
8,564
Total records indatabase
Duplicate recordsremoved
Unique well records Wells already decom Remaining wells to bedecom after 2020
Wells in <100m ofwater
Wells Decommissioning Liability (USA GoM)
Source: BSEE borehole database statistics (Jan 2021)
GoM 1980 -2020 ~20,000 wells decom, >70 % in water < 100m (Primarily rigless techniques - Prof Mark Kaiser at LSU)
Why rigless?Cost reduction, meeting regulations(Cost data not published by BSEE)
My experience USD 1.0 million per well is common
74% in water < 100m
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Well decommissioning compliance
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Well decommissioning compliance
NOPSEMA(Based on OPGGS Act 2006)Considers well decom in the latest editions of OGUK WDG and NORSOK D-010as “good industry practices”
OGUK Well Decommissioning Guidelines issue 6, June 2018
NORSOK D-010:2021 Well integrity in drilling and well operations
CFR 250 Subpart Q – Decommissioning Activities, current(USA, Code of Federal Regulations)
Note: OGUK WDG and NORSOK are based on the underlying principle of CRR
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Well decommissioning compliance
Note: OGUK WDG and NORSOK are based on the underlying principle of CRR
• NOPSEMA
• Assess and approve WOMP
• Operator can select well access method and barrier philosophy
• Risks to be demonstrated as ALARP
• As previously stated, the latest versions of the OGUK WDG and NORSOK D-010 documents are accepted as “meeting good industry practice”. Both documents are based on CRR as a barrier philosophy and accept rigless/riserless techniques as a suitable access methodology to install the well barrier(s) through the production tubing string(s).
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Cap rock restoration explained
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SSD - C
SSD - C
SSD - C
SSD - C
XN
SSD - O
SSD - C
XX
SSD - C
SSD - C
SSD - C
SSD - C
SSD - C
XX
XX
Well decommissioning current practice (Australia)
Not to scale
Reservoir
Impermeable
Impermeable
Impermeable
Impermeable
Cap rock
All completion equipment
can be removed
Cap rockPrimary barrier envelope
Secondary barrier envelope
Well severed below mudline
Operations can be 20-30 days or moreRig up, BOPs, pulling comp string, PWC, milling etc.
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SSD - C
SSD - C
SSD - C
SSD - C
XN
SSD - O
SSD - C
XX
SSD - C
SSD - C
SSD - C
SSD - C
SSD - C
XX
XX Down hole completion equipment
may be left in place. There are
some outliers e.g. electric cables
and control lines
Rigless with CRR normally takes
significantly less time than other
methods resulting in less project
cost (often 25 - 75%)
All lower zones in equivalent
or risk assessed pressure
regimes where cross flow is
deemed acceptable over
geological time
Primary barrier envelope
Secondary barrier envelope
Well severed below mudline
Cap rock
Reservoir
Impermeable
Impermeable
Impermeable
Impermeable
Not to scale
Rigless well decommissioning
Operations can be 5 – 7 days or less
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Practical case – well decom
Plug-01
Plug-02
Plug-03
Plug-02
Plug-01 Plug-01
Cap rock
Rigless = 5 - 7 days common in GoM
Day 1 Day 2 Day 3-4 Day 5 - 7
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Cost saving opportunities – Australian well decommissioning
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Hypothesis – Australia well decom
If the principle of cap rock restoration (CRR) can be applied to the significant portion of the total well inventory containing a completion (i.e. production tubing), then application of rigless/riserless (i.e. subsea wells) and rigless (i.e. platform wells) access methods can significantly reduce cost, versus current practice, while ensuring the same standards of well integrity.
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Geoscience Australia
Australian Wells Databases(public)
NOPIMS (GA)
CUWIM(Excel)
Raw Data
>20k Records of hard to visualise data
Data Processing
& Validation
Curtin University Well Inventory Model (CUWIM)
Mar 2020
>20k Records Fully customizable
sort and filtercapabilities + graphics
WAPIMS (GA)
~900 wells on Barrow Island
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Not to scale
Target well
CRR
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CUWIM - Forecast cost estimate
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CUWIM – Well classifications
i. DNC - Dry, Not Completed
ii. DCNR - Dry, Completed, Not Rigless
iii. DCR - Dry, Completed, Rigless
Dry (platform) wells – easily accessible Wet (subsea) wells – more complicated
iv. WNC - Wet, Not Completed
v. NR - Wet, Completed, Not Rigless
vi. WCR - Wet, Completed, Rigless
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CUWIM – Summary of wells (offshore Commonwealth)
Data Processing
& Validation
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CUWIM – Cost table
Access Method DescriptionWell Decom
Million USD
Duration
Days ATotal Well Cost Rate
USD/day B
i Floating rig (semi)- conventional techniques 7.70 35 220,000
ii Floating rig (semi) - rigless/riserless techniques 3.80 20 190,000
iii Jackup - conventional techniques 3.75 25 150,000
iv Jackup - rigless techniques 1.88 15 125,000
v HWU - conventional techniques 2.40 20 120,000
vi HWU - rigless techniques 1.65 15 110,000
vii Rigless - only wireline & pumping 1.02 12 85,000
A Interfield rig move included in duration, international mob excluded.B Operator total cost per well in USD divided by duration days.
Access methods i and iii are in line with costs for Southern North Sea operations (OGUK 2019).
Access methods ii, iv & vi rigless techniques means the unit is used as an access platform. All well work is performed with wireline and
pumping. Reduction in USD/day and durations due to multiple service companies not required, drilling BOPs and risers are not used,
tripping pipe operations are minimised, completion strings left in situ up to the bottom of the SCSSV.
Access method vii rigless uses stand alone wireline and pumping spread supported by a minimum cross trained crew.
Table 1. Single well access method and cost estimate
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CUWIM - Hypothetical cost estimate
Floating rig, Not Completed
Floating rig, Not Completed
Floating rig, Conventional
Floating rig, Rigless
Floating rig, Rigless
Jackup, Conventional
Jackup, Conventional
Jackup, Conventional
HWU, Conventional Rigless
Rigless
0
500
1,000
1,500
2,000
2,500
3,000
3,500
4,000
4,500
Base Case(no rigless)
Step 1. Rigless(no deep set lines)
Step 2. Rigless(inc deep set lines)
USD
Mill
ion
s
Estimated Cost Reduction OpportunitiesCUWIM (840 wells)
USD 1,655 millionUSD 854 million
USD 4.9 million / well (CUWIM)
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● Current offshore well decom liability USD 16.6 billion
● Cost saving opportunities highlighted by Advisian can be supplemented by methodology
changes
● Rigless methodology is applicable on many wells provided well barrier element
verification is demonstrated.
● GoM executing rigless since 1980
● Applied to Australian offshore well inventory
○ 21% Through methodology change (rigless vs. rig)
○ 20% additional if barrier element with cable or hydraulic lines are acceptable
● Barrier element verification remains the key uncertainty and requires a lot of work
Summary
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APPEA Journal Reference
Murphy, C., and Higgins, S. A. (2021) Australia offshore well inventory characterisation and decommissioning cost
saving opportunities through cap rock restoration and rigless/riserless techniques.
The APPEA Journal 61. In press. doi: 10.1071/AJ20118
https://www.appeaconference.com.au/
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Thank you
Christopher MurphySenior Research [email protected]
Curtin University Oil and Gas Innovation Center (Perth, WA)https://cuogic.curtin.edu.au/