OPC's David Gorsuch and INTECSEA's John Harley recently delivered this presentation at the 9th Annual Offshore Production Technology Summit in London. The presentation highlights the importance of integration between the subsurface and surface facility design teams in achieving optimal field development plans for oil & gas assets.
The Importance of Integration of subsurface with surface facilities design
1. The importance of
integration of subsurface
with surface facilities design
John Harley, Regional Director INTECSEA Consulting
David Gorsuch, Technical Director OPC
2. WorleyParsons Structure
Major
Engineering
Project Delivery
Strong FEL technical team
Deepwater SURF
Topsides Facilities
Floating Solutions
FA
CAPEX
Offshore commissioning
Decommissioning (Aberdeen)
Regulations, consents and licences
UK energy market, including market reforms
Energy industry policy
Proven successful relationships with Governments,
including DECC
Transaction Services
North Sea
Fabrication Subsea
& Topside modules
3. WorleyParsons Group and Friends
Major
Engineering
Project Delivery
Strong FEL technical team
Deepwater SURF
Topsides Facilities
Floating Solutions
FA
CAPEX
Offshore commissioning
Decommissioning (Aberdeen)
Regulations, consents and licences
UK energy market, including market reforms
Energy industry policy
Proven successful relationships with Governments,
including DECC
Transaction Services
North Sea
Fabrication Subsea
& Topside modules
4. What is Value?
Value - Defined as “The material or monetary worth of
something”.
Maximum Value - the correct development, chosen first time,
right-sized
Inefficiency – Defined as “the magnitude of the value
that can be lost”
Risks not clearly identified and resolved
5. Value Destruction – an example
200 MMbbl of recoverable oil
No sales gas product
1200 m water depth
Fast track project
(36 months to first oil)
25 year production life
Oil price of $100/bbl
Inflation at 2.5%
200 MMbbl of recoverable oil
No sales gas product
1200 m water depth
Fast track project (36 months to first oil)
25 year production life
Oil price of $100/bbl
Inflation at 2.5%
6. Initial production plateau not achieved
Only 65% of intended production for 3 years
Production Profile
Same total oil recovered,
but slower rate of recovery
7. Pre-Tax NPV
Missed Plateau Value Impact
Original FDP Missed Plateau
NPV, MM$ 4,074 3,621
Delta, MM$ - -453
Delta, % - -11.1%
IRR, % 22% 20%
8. Additional Production and Water Injector wells needed after only 2
years of operation
CAPEX required for drilling, equipment procurement and installation.
(Loss of production during installation/hook-up/commissioning is ignored)
Additional Wells Value Impact
Original FDP Missed Plateau Extra Wells
DRILLEX, MM$ 1,600 1,600 2,400
CAPEX, MM$ 3,220 3,220 4,220
Total, MM$ 4,820 4,820 6,620
Delta, % - 0% +37%
9. Pre-Tax NPV severely eroded
IRRs remain attractive
(IRR by itself is not a reliable indicator of good/bad project)
Value Impact
Original FDP Missed Plateau Extra Wells
NPV, MM$ 4,074 3,621 2,075
Delta, MM$ - -453 -2,000
Delta, % - -11.1% -55.2%
IRR, % 22% 20% 16%
11. Oilfield Production Consultants (OPC)
The OPC-Worley Parsons INTECSEA partnership
Who are OPC? We are a specialist supplier of subsurface engineering,
geosciences and production technology expertise globally for over 25 years.
OPC offices – London, Aberdeen, Stavanger, Houston, Astana, Doha & Basra.
The strategic partnership with INTECSEA /WorleyParsons is designed to allow
proper integration of predictions of the behaviour of the sub-surface with
surface facilities design.
Our aim – a fully integrated Reservoir to Market (R2M) full field development
planning platform
Integrating reservoir understanding (OPC Group)… with surface facilities design (WorleyParsons Group)
12. Oilfield Production Consultants (OPC)
The value of the partnership
The importance of integration of subsurface with surface facilities design
Communication – passing the right information at the right time and using
the right vocabulary.
Management of uncertainty – designing for robustness not optimisation
Front-end loading of facilities design – ensuring all the appropriate
options are considered.
Optimal FDP
13. Oilfield Production Consultants (OPC)
Low Oil Price Scenario (LOPS) planning
Adapting to a new world…
Many plans developed in the context of $100 oil no longer make sense.
Assets still need to be monetised and revenue needs to be generated. In
many cases, this is still possible but requires a fresh look at the
development.
OPC and INTECSEA/WorleyParsons can help companies to carry out
Prospect Re-framing (PReF) by stepping back and taking a completely new,
holistic view of developments against the backdrop of…
$50 oil
Low appetite for risk
14. Thank you
David Gorsuch
Technical Director
Oilfield Production Consultants (OPC) Ltd
1-2 Apollo Studios, Charlton Kin’s Road,
London NW5 2SB
Mob: +44 (0)7585 770455
Tel: +44 (0)20 7428 1111
e-mail: david.gorsuch@opc.co.uk ww.opc.co.uk
John Harley
Regional Director
Consulting
Lansbury Estate
102 Lower Guildford Road,
Surrey, GU21 2EP
Direct: +44 (0) 1483 878 504
Mobile: +44 (0) 7760 669 199
john.harley@worleyparsons.com
www.worleyparsons.com
Editor's Notes
We are going to focus on the Field Development Value Chain
This is where value is created in the monetisation of an asset but without protection can be destroyed through the chain.
First some definitions
We need to define value in our case we may see this as the correct development, chosen first time, right-sized. Prevents excessive costs in over conservative designs, prevents against post-FEED project stop / recycle, developments that are more likely to stay on schedule, developments that are less likely to miss production plateau.
Inefficiency = issues not clearly identified and resolved. Much of that inefficiency comes through poor decision making. Adding data will help resolve issues and remove uncertainties and assumptions, and therefore risk. Fewer unresolved issues leads to greater efficiency and less value destruction.
In the FDP value chain let us look at how value can be trickled away through inefficient decision making and lack of risk awareness using a modified historical deepwater field.
Sanitised and simplistic – but just something to give an appreciation of the magnitude of the value that can be lost at the early stages of a development
This is a “fast track” schedule – real but unusual in that it might set a benchmark for many CEO’s & banks to emulate
Highlights:
The reference a large reservoir circa 3bn bbl in place, which means this wasn’t such an issue – there was so much value in the field with high oil prices and the driver was speed….. Not necessarily so much emphasis on capital efficiency
What about today?
Note the underachievement in production - Somewhere in the order of 2/3 of predicted production was achieved over the first 3 years
In addition, during this period, additional production and water injection wells were drilled & tied-in to increase the production
The same amount of oil is recovered, it is just recovered a bit later – so how does this impact the value?
Missed plateau production for initial years
No impact on CAPEX
A loss in NPV terms of $450 million
Still an attractive IRR at 20%
Not an insignificant amount………… (IRR still looks good though)
The missed production in itself didn’t add anything on to the CAPEX – additional wells certainly do though
An additional x production and y water injection wells (50% more wells) were required in the first couple of years to try to raise production.
Reservoir was clearly (although not exclusively) the issue here – lack of definition prior to production commencing.
Out of interest, typically a 15% cost reduction across all equipment, installation, drilling, commissioning etc. would produce an improvement in NPV of approximately $400 million
$2 BILLION lost from original NPV
But, you have a project with an “attractive” IRR of 16% - this could be spun as a great success
This would still be considered a viable project - but it could have been so much better………..
How do we help clients define, protect and therefore maximise value through the chain?
We make sure that the business drivers are articulated and recorded.
That they are agreed with all stake holders.
That the strategic decisions such as whether this is a stand alone development, partnering, contract strategy and schedule duration look like all meet those drivers.
That they are embedded in the decision framework going forward.
That the tactical level decisions of appraisal drilling, subsea spread, production and facilities solutions are all recorded and auditable back to the strategic business drivers.
We do this by bringing the right people into the value chain from our and client side and enabling them to make informed quality decisions in a formal decision framework.
We help them to look at all possible options for a development and weed it down to all of the credible developments that meet the business drivers.
We are geared specifically to help our clients to analyse those credible developments for technology readiness, CAPEX implications, economic metrics, robustness and importantly we help them to understand the technical and non technical risks that surround the field limits such as commercial and geopolitical risks.
We see it as helping our clients to sleep better at night by helping them to make informed decisions at the appropriate time.
But more than this. Aligning our technical surface strength with OPC allows us to import an understanding of subsurface risk into the client business plan.
David will now take us through that.
Why is integration of subsurface with surface facilities design important?
Bullet 1 - Different things are important to those involved in understanding the subsurface and those responsible for surface facilities design. For a reservoir engineer, a fluid with a condensate gas ratio of 1 bbl/MMscf is essentially the same as a fluid with a CGR of 2 bbl/MMscf. Both are "dry gas". For a surface facilities engineer, they are very different. Engagement of the two teams from the very beginning helps to ensure that information is properly propagated from the subsurface stage of the study to the surface facilities design stage.
Bullet 2 - The levels of uncertainty involved in the subsurface and surface facilities design are very different. In the context of surface facilities design, almost everything is known or knowable. In the subsurface, a great deal of stuff is unknowable. This gives different mindsets in the two communities. A surface facilities design engineer tends to focus on optimisation of the design for the expected inputs. In practice however, a design that is robust in the face of unavoidable uncertainties may be a much better bet. For example, the condensate gas ratio of the produced fluid may not be known with certainty. A design that can cope with anything between 60 bbl/MMscf and 90 bbl/MMscf may be a much better bet than a design that is optimised for 60 bbl/MMscf but will not be able to cope with 90 bbl/MMscf.
Bullet 3 - Front-end loading discussions between the subsurface professionals and the surface facilities design engineers may also allow consideration of a much wider range of possibilities. For example, a gas field may be vulnerable to water production. Two approaches could be adopted. Wells could be drilled to minimise the risk of water production and Surface facilities constructed with minimal water handling capability. Alternatively, simpler and cheaper well could be drilled, increasing the risk of water production, and surface facilities constructed that could handle the produced water. Early engagement of the subsurface and surface facilities professionals will allow the best choice to be made as early as possible.