thursday 22 nd of march 2012
DESCRIPTION
Photo courtesy of Howard Johnson. Wytch Farm Field Development Project. Thursday 22 nd of March 2012. Marcel&Conrad for Team B. Mohammed Alshawaf , Lanray Hammed Bakare , Francisco J. Barroso Viseras , Aristeidis Karamessinis , Ha Nguyen and Shi Su. Field overview. - PowerPoint PPT PresentationTRANSCRIPT
Thursday 22nd of March 2012
Photo courtesy of Howard Johnson
Wytch Farm Field Development Project
Marcel&Conrad for Team BMohammed Alshawaf , Lanray Hammed Bakare, Francisco J. Barroso Viseras, Aristeidis Karamessinis,Ha Nguyen and Shi Su
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Marcel&Conrad Field overview
• Southern coast of the UK
• Onshore and offshore
• High sensitive environmental area: AONB, HC among others
BP for Imperial College, 2012
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Marcel&Conrad Aim and objectives
Prove the economic viability of the project
Characterise and model the reservoir
Propose a development and production plan
Demonstrate the economic facts
Assess the uncertainties and risks P10 P50 P90
Reserves (MMstb) 412 318 219NPV15%(USD millions) 928 735 442
IRR (%) 41.5 39.7 34.0
Marcel&Conrad Reservoir facts
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Geological overview• Reservoir Sherwood Sandstone• Seal Mercia Mudstone• Source Lias Formation• Play type Tilted fault blocks
Underhill & Stoneley, 1988Source
SealReservoirUnderhill & Stonely, 1988
Field appraisal
• 3D seismic survey• Producers 1X-02, 1D-02• Appraisal wells 3
Depth (TVDSS) 1585 m
Pressure 165 bar Oil column thickness 39 m
Areal extent 40 km2 API gravity 38.1° @ 15°C
GOR @ 165 bar, 66°C 320 scf/stb
P90 P50 P10
STOIIP (MMstb) 580 795 1040
Recoverable oil (MMstb) 219 318 412
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Marcel&Conrad Building a simulation model
• Integrate various sources: from outcrop to cores
• Coarsen to allow simulation
• QC to ensure consistency
2.5 million 80,000 cells
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Marcel&Conrad Development plan strategy
Parameter Constraint Solution
Drilling strategy
Number of wells Recovery factor vs economics
11 producers / 5 injectors
Schedule Rates and rigs 3 months/well
Well type & location Environment and oil distribution
Extended reach
Production strategy
Plateau Maximise recovery and surface facilities 3-year plateau
Water injection Pressure maintenance After 14 m
Production time Lease and economics 23 years
• Oil expansion and aquifer drive are the most plausible
• Low primary recovery => water injection
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Marcel&Conrad Development plan results
• 3-year plateau• Injection starts after 14
months• 318 MMstb recoverable• 40% recovery factor
based on P50
STOIIP 795 MMstbRecovered 318 MMstb
P90 P50 P10STOIIP (MMstb) 580 795 1040
Recovered oil (MMstb) 219 318 412
Recovery factor 38% 40% 40%
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Marcel&Conrad HSE Policy
High responsibility policy• Labour accidents• Oil and gas spillage• Noise pollution and
biodiversity
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Marcel&Conrad Surface facilities and export
Transport• Flowlines
Separation• 3-stage Gas Liquid
Treatment• Chemical additives• Water
Storage / Export• Pipelines• Terminals
P90 P50 P10
Produced oil ;ďŽƉĚͿ 52,000 76,000 98,000
Gas ;D D ƐĐĨ ĚͿ 5.5 8 10.4
LPG ;ƚŽŶŶĞƐ ĚͿ 87 126 163
Injected H2O ;ďďů ĚͿ 43,000 63,000 82,000
Quantities Destination ;ůŝĞŶƚ Ϳ
Produced oil ;ďŽƉĚͿ 76,000 Fawley refinery
(Esso)
Gas ;D D ƐĐĨ ĚͿ 8 Iwerne Courtney
(National Grid)
LPG ;ƚŽŶŶĞƐ ĚͿ 126 LPG loading plant
(Flexible)
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Oil• 75 km, 18” OD pipeline
Gas• 34 km, 8” OD pipeline• Pressure regulation tie-in
LPG
• 4 km, 6” OD pipeline• LPG loading plant
16.5 km
Marcel&Conrad Project economics
Parameter Value
Discount Rate 15%
Inflation Rate 2%
Price of Oil ($/stb) 15
Price of Gas ($/Mscf) 1.7
Price of LPG ($/tonne) 210
First Oil (Year) 2017
• Ensure viability of the project
• Estimate annual cashflows
• Assess uncertainties
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Marcel&Conrad Project economics
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Marcel&Conrad
Reprocess Seismic Data
Coring
Fluid Sampling
RFT
Full Suite Logs
SBHP/T
Separator/Wellhead Samples
Well Rate Tests
PLT
PNL
Oil Production
Year
Dat
a A
cqui
stio
n
2016 2023 2024 2025 2026 To 2039202220212020201920182017
Reducing uncertainties
Data acquisition plan Reprocess seismic data Coring of the first few wells
SCAL Logging
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Marcel&Conrad Risk analysis
• Flow assurance, facility checks
• Training, PPE, housekeeping
• Various production plans
• Pollution prevention, noise reduction
• Promise work positions
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Marcel&Conrad
>
Q1 Q2 Q3 Q4 Q1 Q2 Q3 Q4 Q1 Q2 Q3 Q4 Q1 Q2 Q3 Q4 Q1 Q2 Q3 Q4 Q1 Q2 Q3 Q4 Q1 Q2 Q3 Q4 > Q1 Q2 Q3 Q4 Q1 Q2 Q3 Q4 Q1 Q2 Q3 Q4 Q1 Q2 Q3 Q4
Company approval
Planning FDP
Governmental approval
Project management
Front end engineering design
Engineering
Procurement
Construction
Commisioning
Drilling
Production
Decommissioning
Abandonment
2039 2040 20412017 2018 20382012 2013 2014 2015 2016
Project lifecycle
First oil
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Marcel&Conrad
P10 P50 P90
Reserves (MMstb) 412 318 219
Recovery factor (%) 38 40 40
Recommendations
Environmental regulations upheld
Shrewd reservoir management
practices planned
High profitability achieved
Efficient mitigation schemes designed
P10 P50 P90
NPV15%
(USD millions)928 735 442
IRR (%) 41.5 39.7 34.0
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Marcel&Conrad
Thank you
Any questions ?
Safely
Reliably
Cost-Effectively
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Marcel&Conrad
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Marcel&Conrad
• Drive mechanism• Sweep efficiency• Upscaling:
• Tubing performance• Pipelines design:
• Drilling mud• Completions design: - Casing
- Perforations
- Parameters- Quality check
Appendices
- Oil- Gas
Marcel&Conrad Drive mechanism determination
• Limitations of material balance
• Oil expansion and aquifer drive are the most plausible• No assumption can be validated
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Marcel&Conrad Sweep efficiency analysis
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• Injection after 14 months• 92% sweep efficiency achievable over 23 years
Marcel&Conrad Upscaled model consistency
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Static properties
Geology
Volumetrics
Upscaled properties
kh, kv
Φ
Facies
Dynamic properties
Cumulative production
Bottom-hole pressure
Oil saturations
Sweep efficiency
Water cut
Coning water
Numerical diffusion
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Marcel&Conrad Geology and upscaled properties: facies
Fine grid Coarse grid
Marcel&Conrad Upscaled properties: kh
Fine grid
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Coarse grid
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Marcel&Conrad Upscaled properties: Φ
Porosity distribution: Fine vs Coarse grid
%
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Marcel&Conrad Cumulative production
- Fine grid
- Coarse grid
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Marcel&Conrad Bottom-hole pressure
- Fine grid- Coarse grid
Injectors Producers
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Marcel&Conrad Oil saturations
Fine grid Coarse grid
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Marcel&Conrad
0 0.1 0.2 0.3 0.4 0.5 0.6 0.70
0.05
0.1
0.15
0.2
0.25
0.3
0.35
0.4
0.45
Coarse Fine One to One line
tD (pore volume injected)
NpD
(por
e vo
lum
e pr
oduc
ed)
Sweep efficiency
Marcel&Conrad Water cut
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- Fine grid
- Coarse grid
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Marcel&Conrad Coning water
Fine grid Coarse grid
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Marcel&Conrad Numerical diffusion
Fine grid Coarse grid
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Marcel&Conrad Drilling schedule
DrillingOil productionWater injection J F M A M J J A S O N D J F M A M J J A S O N D J F M A M J J A S O N D1P-011P-021P-031P-041P-051P-061I-011I-022P-012P-022P-032P-042P-052I-012I-022I-03
Year2016 2017 2018
Q1 Q2 Q3 Q4 Q1 Q2 Q3 Q4 Q1 Q2 Q3 Q4
• 1 permanent rig for each site, 1 moveable rig
• Priority based on oil production rate
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Marcel&Conrad Well type and location
• Extended reach wells
• 2 well sites
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Marcel&Conrad
0 2 4 6 8 10 12 14 16 18 20 220
20
40
60
80
100
120
140
160
180
Reservoir pressure profile throughout the field life
With injection
Without injection
Time Elapsed (year)
Reservoir pressure (bar)
Water injection strategy
• Water injection after 14 months in order to ensure pressure maintenance
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Marcel&Conrad Tubing performance, ESP design
0 10,000 20,000 30,0000
20
40
60
80
100
120
140
160
180
Tubing performance without ESP
IPR, Pr=160 bar
IPR, Pr=124 bar
IPR, Pr=103 bar
TPC, No ESP
Bottomhole flowrate (stb/d)
Bottomhole pressure (bara)
0 5,000 10,000 15,000 20,0000
20
40
60
80
100
120
140
160
Tubing performance with ESP
IPR, Pr=124 bar
IPR, Pr=103 bar
TPC, ESP 10 stages
TPC, ESP 90 stages
TPC, ESP 170 stages
Bottomhole flowrate (stb/d)
Bottomhole pressure (bara)
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Marcel&Conrad Gas pipeline design
• An optimum of 8” OD has been chosen
4 5 6 7 8 9 10 11 12 13 14 15 16 17 18 19 20 2165
67
69
71
73
75
77
79
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Gas pipeline design
Pipeline OD (inches)
Delivery outlet pressure (bar)
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Marcel&Conrad Oil pipeline design
• An optimum of 18”OD has been chosen
13 14 15 16 17 18 19 20 21 22 23 24 250.9
0.92
0.94
0.96
0.98
1
1.02
1.04
1.06
Oil pipeline design
Pipeline OD (inches)
Delivery outlet pressure (bar)
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Marcel&Conrad Mud weight
• A mud weight of 1.15 sg has been chosen
0 50 100 150 200 2500
200
400
600
800
1,000
1,200
1,400
1,600
1,800
Pore Pressure
Fracture pressure
Mud pressure
RFT 1K-01
RFT 1F-11
RFT 98/6-08
Pressure (bar)Depth (mTVD)
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Marcel&Conrad Casing
36”150m
20”550m
7”1630m
13 5/8”150m
4”150m
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Marcel&Conrad Perforation density
• An optimum of 8 spf has been chosen
0 5 10 15 20 25 3013800
14000
14200
14400
14600
14800
15000
15200
Perforation density sensitivity
Perforation density (shot/ft)
Liquid production rate (stb/d)
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Marcel&Conrad Upscaling parameters
Parameter / Property Static model value Constraint Dynamic model
Grid dimensions 100x100Capture geological and petrophysical hetereogeneities
390x270
Zonation and layering 7 zones, 140 layers Capture vertical hetereogeneities 7 zones, 50 layers
Facies N/G Respect the depositional model Most of
Horizontal permeabilities kx, kyHonour the channel distribution Arithmetic
Vertical permeability kzCapture the heterogeneities Geometric
Porosity Φ Honour the channel distribution Arithmetic