facilities engineering-field development concept_project2
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© 2011 UTP Slide No. 1
MAB4633/MBB4513
Evaluate the energy consumption of the following offshore oil and gas facility,
identify energy saving options and suggest the energy supply options to meetthe current and future demands of the facility.
You should include basic engineering calculations and analysis in your proposal.Economic analysis based on assumed cost of the proposed equipment/facility
is required for this project. You must demonstrate how you achieve yourselection and how you de-risk your proposal.
You will submit a report (approx 25 pages) and a ppt of max. ONE (1) slide onlyfor your group’s work.
Remember, you’re only part of a whole. So work together.
Group Project Guideline
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MAB4633/MBB4513
An offshore oil producing facility is currently used for exploration and
production operations of an oil field, 50 km offshore Sarawak. The facility is
designed to handle 300kbpd of oil production from which 20% of the well
output is natural gas. The energy demand for the platform (LQ, motors, drilling
etc.) is 150 MW Peak. The existing power generation facility provides for only
45MW Peak at 100% loading. The facility operators need to decide on theadditional power generating options for the platform. The existing energy
scenario for the facility can be summarized in the following table:
Job Invoice for CTR
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© 2011 UTP Slide No. 3
MAB4633/MBB4513
Equipment Rated Power Loading Thermal /Mechanical
Efficiency
Fuel
Gas Turbines (2 nos.) 45MWp 100% 23% Gas from field
Diesel Genset 1MW 0% (standby) 22% Diesel storage tank
Fire water pump 500kW 0% (standby) 20% Diesel day tank
Main Oil Line Pumps (4 nos.) 550kW 70% 75% Electricity
Auxiliary pumps 250kW 50% 69% Electricity
Refrigeration and AirConditioning
(Vapor Compression cycle )
800kW 80% 24% Electricity
Utilities 1MW 80% 30% (avg) Electricity
Process 10MW 70% 20% (avg) Electricity
Process 2MW 50% 80% Heating
Drilling 40MW 100% 85% Electricity
Future Requirements 100MW 100% - Electricity
Equipment on site
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© 2011 UTP Slide No. 4
MAB4633/MBB4513
Time
(hrs)
Typical Daily
Solar insolation
(W/m2
)0800 165
0900 170
1000 185
1100 190
1200 190
1300 290
1400 380
1500 305
1600 280
1700 170
1800 1150
1900 50
Time Wind Speeds
(m/s)
Typical daily averages for
the months between
October to December
2-6
Time Wave Heights
(m)
Typical daily averages for
the months between
October to December
1-1.5
Typical daily averages for
the months between
January to March
0.5-1
Typical daily averages for
the months between April
to October
0.5 – 0.8
Renewables
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© 2011 UTP Slide No. 5
MAB4633/MBB4513
Time Flare flowrates
(kg/hr)
Jan 45
Feb 50
March 50
April -
May -
June 45
Time Flare flowrates
(kg/hr)
July 45
August 55
September 60
October -
November -
December -
Time Flare flowrates
(kg/hr)
Typical blowdown
requirements
500
Flare
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© 2011 UTP Slide No. 6
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Time Field gas Availability
(MMcf/d)
Jan 150
Feb 100
March 110
April 100
May 100
June 110
Time Field gas
Availability(MMcf/d)
July 120
August 100
September 150
October 110
November 110
December 110
Field Gas
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Time Typical Daily LQ
demand data (kW)
0800 950
0900 900
1000 750
1100 500
1200 1100
1300 900
1400 900
1500 500
1600 800
1700 750
1800 600
1900 950
Time Typical Daily LQ
demand data (kW)
2000 1000
2100 1100
2200 750
2300 500
2400 500
0100 500
0200 500
0300 500
0400 500
0500 650
0600 650
0700 950
LQ Demand
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CTR - Lab projects
Cost per person = RM60/hr
Time per person = 8 hrs/week Group cost per day = (60 x 8 x 5 )/5 = RM480/day
Ext consultant cost (Lab tech + GA) = RM120/hr x 2 = RM240
Total lab cost (10 days) = RM4800 + 240 = RM5040/lab (FIXED)
Group lead please kindly keep track and recover CTR from commencement of lab/project. Include CTR in Report.
Recovered CTR = 5040 –
(Amount You Spent)
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CTR - Group project
Cost per person = RM60/hr
Time per person = 8 hrs/week Group cost per day = (60 x 8 x 5 )/5 = RM480/day
Total project cost (35 days) = RM17,280 = RM17,280 (FIXED)
Group lead please kindly keep track and recover CTR from commencement of lab/project. Include CTR in Report.
Recovered CTR = 5040 – (Amount You Spent)
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RM60/hr ?
RM60/hr x 8 hrs/day x 200 days = RM96,000
Employee cost to company per month RM96,000/12 =RM8,000
Employee gross compensation = RM8,000/3 = RM2667 per month
Co. leverage ratio (2-6)• Market capitalisation • Debt (5~26%) depending on rating • Stock & dividend payout • Bonus to Snr. Exec
Effective Employment 365-(52x2)-(15)-(17)=229 days
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How to include CTR in Report
DESCRIPTION ANALYSIS COST ($)FIXED COST 5040
Group cost per day 480
Ext. Consultation 240
Days spent 7
Exp cost 480*7+240 (3600)
RECOVERED 1400
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Report Expectation
• Report to be reviewed by colleagues before submission
• Contribution of each members clearly outlined
• Report format is correct (see template given)
• No plagiarism
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© 2011 UTP Slide No. 13
MAB4633/MBB4513
Backup
The following ideas may help
you
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© 2011 UTP Slide No. 14
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TASKS DAYS
1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 18 19 20
1
2
3
4
MILESTONES
A
B
C
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•
•
•
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• History
• Reservoir Characteristics
• Reservoir Performance
• Opportunity Statement
• Action Plan • Opportunity Realized
• Stakeholder Mapping • Opportunity Vs Threats
• Strategic Fit (HSE)
Identify & Assess
New opportunities
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Discovery well followed by 5 appraisals
First 3-D seismic survey Field development with 7 producers (5 platform and 2 subsea and 5 subsea injection wells
First oil Initial 4D seismic acquisition
Drilling of 6 th platform producer
Gxxx West development with 2 producers 2nd 4D seismic data acquirement
Drilling of 2 Rxxx south subsea producers Conversion of 1 subsea producer to injector
4D/high resolution seismic survey
1984 2004 1994
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© 2011 UTP Slide No. 18
MAB4633/MBB4513
Leverag e
Low Me d
High
L o w
M e d
H i g h
Costs
Infill Drilling
Partner s Manageme
nt
Well
Service s Competitor
s
Contractors
Fishing Industry Lobbyist
Shareholder s
Competitor s
Shareholde rs Partners
NGO
Manageme nt
Equipment Vendors
Seismic Vendors
Influence
I n t e r e s t a n d S u
p p o r t
Monitor
Inform
Engage
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Low Me d
High
Risk Analysis
Ability to Influence
I m
p a c t o n U n r i s k e d V a l u e
Poor supplier relationship
Inclemen t weather
Separator
Capacity Debottlenec k
Drill/redrill from existing wells
Loss of Compressio n
Subsurface realization update
Threats
Opportunities
Using current manifold system
Seismic processing delays
Internal approvals within ORP
Partner support
Drilling rig scheduling issues
Worker strikes
Reduce cost
High
Me d
Low
High
Low
Me d
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Value Drivers Critical Success Factors
Oil production rate Good sweep efficiency
Manage/Monitor water-flood Utilize idle well slots to tap poorly drained areas
Update geological model Use of new technology – using well or seismic data - Simplified well design, fewer casing strings
- Improved history matching Knowledge sharing
Company reputation Keeping government and unions continuously engaged
Minimize Capex and Opex Communicate with other operators in the area to investigate mutually beneficial
scenarios
(oil and gas pipeline, selling facility space)
Near field exploration to increase reserves Investigate tertiary recovery methods to extend life of field
Operational Success Preventive maintenance on injection to maximize uptime
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You need to learn how to (& when not to) make decisionduring conflict of situation, where information is
insufficient, outlook is uncertain, and your peers would
do everything they could to overpower you.
Plan for the worst, hope for the best but don’t over do it.
Key Takeaway from This Project
John Lennon: Life is what happens to you when you are busy making your plan