aasta hansteen info-01
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Gas Field Development Torolf Christensen, Statoil, October 16, 2013 Development and Production Norway, Field Development North
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Gas Field Development - Contents
Lecture 1
Opening a new area
Investment decision framework in Statoil
The Aasta Hansteen development concept
Concept screening and selection Aasta Hansteen
Lecture 2
Economic analysis model in Statoil
The gas transportation system
The gas infrastructure processes
The Polarled development concept
Summing up
2
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3
Aasta Hansteen
Norwegian Sea
Aasta Hansteen - opening a new area
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Key Area Objectives Opening up a new area with new infrastructure
gives Statoil a key position in the region
Considered as a promising area
Development supports Statoils production ambition from 2017 and onwards
Maintain and extend options for further developments
Resulting effects
Develop competence and experience in harsh and deep water environment
Create local spin-off effects in Northern Norway
Contribute to develop the industry in the region
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Ormen Lange
Aasta Hansteen
Heidrun Skarv Norne
sgard
Njord Linnorm
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Aasta Hansteen Reservoir structures
5
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Investment decision framework in Statoil
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What is the capital value process? The model for investment decisions - a risk based decision model to mature large projects through decision gates
Acquisitions /farm-ins/mergers
Business Identifi- cation
Concept planning
Definition Execution Operations
DGA DGB DGC
DG0 DG1 DG2 DG3 DG4
Screening business opportunities
Bid preparations
Concession/ Negotiations
Business planning
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Project development
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DG0 Approval to start business planning
Business planning phase: establishes whether a business opportunity is economically, technically, operationally and organizationally feasible.
DG1 Approval to start concept planning Concept planning phase: identify alternative concepts,
select a viable concept, define and document the selected concept and develop design basis for approval at DG2.
DG2 Project pre-sanction start definition
Definition phase: further mature, define and document the business case based on the selected concept for project sanction.
DG3 Investment decision start execution Execution phase: realizes the business case.
DG4 Decision to hand over to start operation
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Decisions at increasing maturity level: The Decision Gates Business case and work alignment: Stakeholder Start-up meeting (SSUM) Follow up business case assumptions and context, risk and stakeholder management, and
strategic change management: Steering Committee Quality Assurance Assistance (QAA) Independent technical and commercial review at decision milestones: Investment Arena
review.
Processes between DGs
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The Aasta Hansteen development concept
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Aasta Hansteen development concept
Spar-platform with condensate storage
Process capacity 23 MSm3/day
Steel catenary risers
Polyester mooring
Subsea system
two 4-slots templates plus a satellite
Seven production wells
Gas export through Polarled to Nyhamna
Margins included to serve as future hub Aasta Hansteen Pioneer in Norwegian deep waters
Gas reserves 47 GSm3 Condensate reserves 0.9 Sm3 Lean gas condensate, low CO2 content
Partners: Statoil (operator) 75% OMV15% ConocoPhillips 10%
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Aasta Hansteen Key information
Substructure
length 198 m, diameter 50 m
Dry weight 46.000 tonnes
Condensate storage 25.000 Sm3
Topside
Dry weight 23.000 tonnes
Conventional gas processing plant
Gas turbine power generation
Produced water treatment and disposal to sea
LQ 100 beds
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Aasta Hansteen challenges
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New area and long distance from shore
Water depth 1300 m
Harsh weather conditions
Worlds largest spar and first on NCS
Need for technology qualifications
Aasta Hansteen
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14 -
Concept screening and selection - Aasta Hansteen
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Product
Multiphase flow land*) Sales gas & rich gas land*) *) Nyhamna or other
Condensate handling
Multiphase transport (Subsea) land*) Injection Piping Heidrun, Skarv, others Storage & off-loading
Production facility
Subsea ( Deep water ) Semi (Deep water ) Semi (Shallow water ) Spar (Deep water) FPU mono-hull (DW) FPU mono-hull ( SW ) Others ?
Power supply
El. power from land ?
Capacity constraints
Capacity at Nyhamna or other landing facilities?
Flexibility to include additional resources ? ( disc. & prosp. )
Subsea Platform Semi Spar FPU (mono-hull) Others
Additional resources in the area
Discoveries Prospects Leads
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16
Norwegian sea evacuation scenarios
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17
Product streams to Nordland
Snefrid
300 k
m 24
"=> 26
"=> 28
" multi
phase
flowli
ne
LuvaDevelopment
DG2 cases
Statoil
Pipelines- MTO-PTT-DEC
Schematic Sketch
Luva to ShorePhase I development
SIZE Date Prepared by REV
A4 14.12.2009 Per Harald Hansen 0SCALE NTS SHEET 1 OF 1
Luva
300 k
m Umb
ilical
Haklang
Manifold
300 km
2 7/8"
MEG i
njectio
n
Assumptions: 2-4 slot subsea templates + 1 satellite tie-back to
subsea manifold (8 x-trees) with flowlines 12,75" x 22,2 mm X 65 matr, each of 3 km lengths
Subsea manifold w/ structure (600 tonnes) with connection points for 4 x 12" flowlines, 1+ 24"multiphase flowlines, 6 x umbilicals and 2 x 12" future risers and 1 x 16" future risers for compression
One multidiameter flowline to shore 60 km of 24"x 1" mm + 90 km of 26"x 1" + 150 km of 28" x 1 to onshore terminal, Carbon steel, 6 mm asphalt and 60 mm concrete. 1000000m3 gravel installation, shore approach and freespans
1x 300 km umbilical, trenched 1x 300 km 2 7/8" x 6,4 mm MEG injection, X65 matr,
FBE + 5 mm PP coating. Strapped to umbilical, Trenched
Phase I
Phase II From year 5 compression required to produce at plateau rate Power from shore required for Subsea compression This solution creates a very large technology gap, a big
challenge to bridge The near field platform compression alternative selected as
base case
Snefrid
300 k
m 24
"=> 26
"=> 28
" multi
phase
flowli
ne
LuvaDevelopment
DG2 cases
Statoil
Pipelines, MTO-PTT-DEC
Schematic Sketch
Luva to Shore Phase II with Platform located compression
SIZE Date Prepared by REV
A4 07.01.2010 Per Harald Hansen 0SCALE NTS SHEET 1 OF 1
Luva
300 k
m Um
bilical
Haklang
Manifold
300 km
2 7/8"
MEG i
njectio
n
Assumptions: 1 import flowline and SCR from subsea manifold to
floater 6 km - 16" x 22,2 mm X 65 matr , incl SCR 1 export flowline and SCR from floater to subsea
manifold of 6 km - 16" x 22,2 mm X 65 matr incl SCR 2 x 6 km umbilicals from floater to subsea manifold
inlusive dynamic section 320 km DC power cable 30-35 MW
320 km
Powe
r
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Alternative floaters with SCR - storage Floater Deep draft semi
with separate storage columns
Cylindrical FPSO with large bildge or heave damping
SPAR With storage
Octabouy Floater with SCR and separate storage
Pros Acceptable motions Proven Large storage
Heave motions
Proven (under construction)
Proven
Cons Need qualification Limited storage
Motions (roll /pitch) Air gap/green water Topside cosnstruction
Need qualification Motion / air-gap issues HCOG sensitive Limited storage Topside layout
Storage in column and pontoon Open storage /soft tank
Cost
Power cable
Possible Possible
Favorable
Possible
Possible
Offloading Loading buoy Direct needs qualification
Direct proven (ref. Goliat)
Loading buoy Direct needs qualification
Loading buoy Direct needs qualification
Direct
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Air gap and green water requirements
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No green water on spar deck or negative air gap in 100 year storms
Positive air gap to lifeboats in 10.000 year storms
Negative air gap in 10.000 year storms shall not escalate into a sever scenario
The Spar FPSO fulfilled all requirements in competition with the Circular FPSO
Extensive modell testing performed
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Economic analysis model
Classification:
C fid ti
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Principles of economic evaluation
Value Creation. Corporate decisions based on an overall management evaluation. Value creation for shareholders the main criterion (net present value after tax)
Balanced approach. All elements that can be quantified shall be part of the valuation to obtain an expected value
Strategic value. Compliance with strategic direction
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Risk management. All relevant risks to be identified and described
HSE considerations a part of the total evaluation of any proposed decision
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Value chain considerations
Values for Statoil (and partners) as owner(s) also outside Aasta Hansteen:
Owner shares in other licenses that utilize the infrastructure
Value of avoided deferral (capacity) and acceleration of volumes
Additional values from other licenses in the Vring area
Value of Gassled ownership
Risk considerations
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Important contributors to value creation
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Value chain considerations
Polarled and Nyhamna tariffs directly affected by gas volume basis (non-linearity)
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Industrial development of the Norwegian Sea requires a new pipeline to transport gas from existing and future fields in the area
The Polarled pipeline and Nyhamna modification project provides the gas export solution from Aasta Hansteen
Other fields will likely utilize the new pipeline for export of gas
Kristin Gas Export Pipe (KGEP) an opportunity for the currently restrained gas volumes from sgard Transport (T)
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Volume and tariff scenarios
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The gas transportation system - Norwegian Sea Infrastructure development Security
Classification: Internal
- Status: D ft
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Norwegian Sea
Barents Sea
Aasta Hansteen
Moving into deep water in the Norwegian Sea
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How to transport the gas from Aasta Hansteen?
?
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Players in the gas transport value chain Gassled
Owners of the existing gas transport system
Gassco Operator of the transport system
Statoil as Technical Service Provider on Krst and Kolsnes
New infrastructure architecht
Supply fields (licences) Operators and partners of supply fields
Shippers Companies requesting gas transport capacity
Potential funders of new infrastructure
NPD & OED
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Gassco yearly transport plan analysis
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Further development
phases
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Gas transport capacity situation from the Norwegian Sea
Existing transport system (sgard Transport) full until 2020 +
New gas transport infrastructure needed
Several companies agreed with Gassco to consider a new transport solution ~2009
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Source: Gassco transport plan 2013
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Process of establishing Polarled
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Polarled Aasta H
Zidane
Linnorm
Nyhamna
2009 2010: Gassco facilitated feasibility studies for new infrastructure
Recommendation: a pipeline to Nyhamna connecting into the Ormen Lange processing plant and further gas export through Langeled to Sleipner
March 2010: Gassco submitted an invitation to Open season
Several companies invited to participate and 13 joined the study phase
December 2012: Concept decision (DG2) in parallell with Aasta Hansteen
December 2013: Investment decision (DG3) in parallell with Aasta Hansteen
10 companies participated finally
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Pipeline route
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Pipeline length 481 km Uneven seabed Many free spans Optimize route
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Polarled Pipeline Project
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PLEM
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FIRST DRY WELD
DRAUGEN GAS EXPORT (LINNORM)
NYHAMNA
Aasta Hansteen
ZIDANE
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FUTURE
KRISTIN
PIP
ELI
NE
SYS
TEM
SU
BM
AR
INE
PIP
ELI
NE
SYS
TEM
SCR 14
Parameter Unit Value
Design pressure barg 233 @ 30 m MSL
Design temperature C -10 / + 60
Operating pressure barg 115 - 231
Operating temperature C 55 (max) + temp. profile
Capacity MSm3/d 58 (entry @ kp0) 70 (exit @ Nyhamna)
VICTORIA
18 (16 ID)
18 16 ID
12
PLEM ERB
PLET
POLARLED
LEGEND SUBSEA STRUCTURE PIPELINE IN-LINE TEE UMBILICAL NYHAMNA PIG RECEIVING FACILITIES
PLEM: PIPELINE END MANIFOLD/TERMINATION ERB: EXPORT RISER BASE SCR: STEEL CATENARY RISER
Max. hydrocarbon
dew point
Max. water dew-point
barg at 0 C C at 69 barg
110 -18
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Nyhama Ormen Lange well stream processing plant ( operated by Shell) Tie-in of processing of Polarlead rich gas Export of sales gas through existing Langeled to Sleipner/UK
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Commercial challenges prior to investment decision
No. of commercial agreements/ arrangements needed, such as
Tie-in and construction agreements between tie-in fields and Polarled and Polarled and Nyhamna (Ormen Lange)
Participants Agreement for Polarled Owners
Capacity allocation agreement at Nyhamna
Proposal for tariffs
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Operating phase
Polarled and Nyhamna will be merged with Gassled prior to start-up in 2016
Gassco will take over as operator of Polarled and Nyhamna
Shell ( todays operator at Nyhamna) will be Technical Service Provider at Nyhamna
Transport tariffs for Polarled and Nyhamna to be settled finally by MPE prior to start-up in 2016
All shippers requesting capacity must document that they have a Duly Substantiated Reasonable Need for Capacity (DSRN)
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Key messages
Developing a gas field and building infrastructure in parallel is a demanding task
Requires knowledge and understanding of the entire value chain
Close cooperation across internal units and external stakeholders is a must
Involves all technical and economical disciplines
An inspiring challenge, serving as a great learning arena
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Presentation title: Gas Field Development
Presenters name: Torolf Christensen Presenters title: Vice President E-mail address : [email protected] Tel: +4791589645 www.statoil.com
Thank you for your attention Time for questions
Gas Field DevelopmentGas Field Development - ContentsSlide Number 3Key Area Objectives Aasta Hansteen Reservoir structuresInvestment decision framework in StatoilWhat is the capital value process? The model for investment decisions - a risk based decision model to mature large projects through decision gatesProject developmentSlide Number 9The Aasta Hansteen development conceptSlide Number 11Aasta Hansteen Key informationAasta Hansteen challengesConcept screening and selection -Aasta HansteenSlide Number 15Norwegian sea evacuation scenariosProduct streams to NordlandSlide Number 18Air gap and green water requirementsEconomic analysis model Principles of economic evaluationValue chain considerationsValue chain considerationsVolume and tariff scenariosThe gas transportation system - Norwegian Sea Infrastructure developmentMoving into deep water in the Norwegian SeaPlayers in the gas transport value chainGassco yearly transport plan analysisGas transport capacity situation from the Norwegian SeaProcess of establishing PolarledPipelineroutePolarled Pipeline ProjectSlide Number 33Commercial challenges prior to investment decisionOperating phaseKey messagesSlide Number 37