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Project Evaluation of Oil and Gas Field
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The assignment comprises the production of a field development plan for an oilfield. It
is split into two parts, and data for the case study is provided below.
Additional Instructions:
Assignment Part 2a Economics
INSTRUCTIONS FOR USE:
1. FILL IN THE SHADED CELLS WITH RELEVANT INFORMATION.
2. COPY THE ENTIRE WORKSHEET TO A NEW TAB IF YOU WANT TO RUN DIFFERENT CASES.
3. CUT AND PASTE INFORMATION IF YOU NEED TO MOVE IT RATHER THAN MOVE OR DELETE THE CELLS AS THIS WILL ALTER THE CALCULATIONS
4. ENSURE YOU LABEL THE WORKSHEET WITH YOUR SELECTED OPTION AS "FINAL"
Discount rate 9 % Total CAPEX 0 £ million inputs
Oil price 50 $/bbl NPV 0.0 £ million
Oil pipeline tariff 1.2 £/bbl IRR ERROR:#NUM!
Gas price 0.5 £/therm
Gas tariff 8 £/MMscf
Tax rate 20 %
OPEX 8 £/bbl liqs
Exchange rate 1.5 $/£
Period Year Total liquids Oil export Sales gas (excl fuel gas) Sales gas (excl fuel gas) Oil sales Gas sales Oil tariff Gas tariff OPEX CAPEX Abandonment Cost Cash flow (pre tax) Tax Cash flow (post tax) Discounted cash flow (PV)
kbbls/year kbbls/year MMscf/year therm £ million £ million £ million £ million £ million £ million £ million £ million £ million £ million £ million
0 2021 0.00E+00 0.0 0.0 0.0 0.00 0.0 0.0 0.0 0.0 0.0
1 2022 0.00E+00 0.0 0.0 0.0 0.00 0.0 0.0 0.0 0.0 0.0
2 2023 0.00E+00 0.0 0.0 0.0 0.00 0.0 0.0 0.0 0.0 0.0
3 2024 0.00E+00 0.0 0.0 0.0 0.00 0.0 0.0 0.0 0.0 0.0
4 2025 0.00E+00 0.0 0.0 0.0 0.00 0.0 0.0 0.0 0.0 0.0
5 2026 0.00E+00 0.0 0.0 0.0 0.00 0.0 0.0 0.0 0.0 0.0
6 2027 0.00E+00 0.0 0.0 0.0 0.00 0.0 0.0 0.0 0.0 0.0
7 2028 0.00E+00 0.0 0.0 0.0 0.00 0.0 0.0 0.0 0.0 0.0
8 2029 0.00E+00 0.0 0.0 0.0 0.00 0.0 0.0 0.0 0.0 0.0
9 2030 0.00E+00 0.0 0.0 0.0 0.00 0.0 0.0 0.0 0.0 0.0
10 2031 0.00E+00 0.0 0.0 0.0 0.00 0.0 0.0 0.0 0.0 0.0
11 2032 0.00E+00 0.0 0.0 0.0 0.00 0.0 0.0 0.0 0.0 0.0
12 2033 0.00E+00 0.0 0.0 0.0 0.00 0.0 0.0 0.0 0.0 0.0
13 2034 0.00E+00 0.0 0.0 0.0 0.00 0.0 0.0 0.0 0.0 0.0
14 2035 0.00E+00 0.0 0.0 0.0 0.00 0.0 0.0 0.0 0.0 0.0
15 2036 0.00E+00 0.0 0.0 0.0 0.00 0.0 0.0 0.0 0.0 0.0
16 2037 0.00E+00 0.0 0.0 0.0 0.00 0.0 0.0 0.0 0.0 0.0
17 2038 0.00E+00 0.0 0.0 0.0 0.00 0.0 0.0 0.0 0.0 0.0
18 2039 0.00E+00 0.0 0.0 0.0 0.00 0.0 0.0 0.0 0.0 0.0
19 2040 0.00E+00 0.0 0.0 0.0 0.00 0.0 0.0 0.0 0.0 0.0
20 2041 0.00E+00 0.0 0.0 0.0 0.00 0.0 0.0 0.0 0.0 0.0
21 2042 0.00E+00 0.0 0.0 0.0 0.00 0.0 0.0 0.0 0.0 0.0
22 2043 0.00E+00 0.0 0.0 0.0 0.00 0.0 0.0 0.0 0.0 0.0
23 2044 0.00E+00 0.0 0.0 0.0 0.00 0.0 0.0 0.0 0.0 0.0
24 2045 0.00E+00 0.0 0.0 0.0 0.00 0.0 0.0 0.0 0.0 0.0
25 2046 0.00E+00 0.0 0.0 0.0 0.00 0.0 0.0 0.0 0.0 0.0
26 2047 0.00E+00 0.0 0.0 0.0 0.00 0.0 0.0 0.0 0.0 0.0
27 2048 0.00E+00 0.0 0.0 0.0 0.00 0.0 0.0 0.0 0.0 0.0
28 2049 0.00E+00 0.0 0.0 0.0 0.00 0.0 0.0 0.0 0.0 0.0
29 2050 0.00E+00 0.0 0.0 0.0 0.00 0.0 0.0 0.0 0.0 0.0
30 2051 0.00E+00 0.0 0.0 0.0 0.00 0.0 0.0 0.0 0.0 0.0
31 2052 0.00E+00 0.0 0.0 0.0 0.00 0.0 0.0 0.0 0.0 0.0
32 2053 0.00E+00 0.0 0.0 0.0 0.00 0.0 0.0 0.0 0.0 0.0
33 2054 0.00E+00 0.0 0.0 0.0 0.00 0.0 0.0 0.0 0.0 0.0
34 2055 0.00E+00 0.0 0.0 0.0 0.00 0.0 0.0 0.0 0.0 0.0
35 2056 0.00E+00 0.0 0.0 0.0 0.00 0.0 0.0 0.0 0.0 0.0
36 2057 0.00E+00 0.0 0.0 0.0 0.00 0.0 0.0 0.0 0.0 0.0
37 2058 0.00E+00 0.0 0.0 0.0 0.00 0.0 0.0 0.0 0.0 0.0
38 2059 0.00E+00 0.0 0.0 0.0 0.00 0.0 0.0 0.0 0.0 0.0
39 2060 0.00E+00 0.0 0.0 0.0 0.00 0.0 0.0 0.0 0.0 0.0
40 2061 0.00E+00 0.0 0.0 0.0 0.00 0.0 0.0 0.0 0.0 0.0
Notes for economics
Provide Notes
Assignment Part 2b Options
INSTRUCTIONS FOR USE:
1. Score each option against each of the criteria ensuring that no two Options have the same score for the crieteria being assessed. See below for scoring convention.
2. Add notes against each option and each criteria to summarise the rationale for the scoring. Make sure that options are differentiated.
3. Fill out the section below the main table detailing the final option selection.
4. Provide a summary of the main reasons for your final option selection.
Score
0 Least preferred
1
2
3
4 Most preferred
Concept Options
A
Single Steel Jacket B
Twin Steel Jackets C
Converted Jack-up D
FPSO E
Subsea Tie-back
Comment Score Comment Score Comment Score Comment Score Comment Score
Criteria Technical
Economic
Safety
Environmental
OVERALL 0 0 0 0 0
FINAL OPTION SELECTION
Enter the selected option here ->
Summarise the main reasons for selecting this option (200 words maximum)
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30/13- 2
30/13- 1
22/16- 6
21/28- 1
21/17- 4
21/17- 3
16/29- 4
16/23- 2
16/22- 2
15/26- 1
15/19- 9
14/18- 1
14/15- 2
14/14- 1
30/25a- 4
30/01a- 7
29/06a- 3
28/09a- 6
23/16d- 6
22/27a- 1
22/22c- 3
22/14b- 3
22/13b- 3
22/13a- 2
22/04b- 6
21/28a- 6
21/27b- 7
21/20f- 7
21/15a- 2
20/03- 2A
16/12b- 6
15/29a- 9
15/17- 8A
15/17- 26
15/17- 24
30/11c- 6C
29/01c- 9Z
22/24c- 11
22/12a- 10
22/11b- 13
21/23a- 8Z
16/21b- 34
15/21b- 50
15/21b- 45
15/19b- 10
30/02- 1
30/02a- 2
29/02a- 2
22/27a- 2
22/08a- 2
15/17- 25
14/30a- 2
14/29a- 4
30/02a- 10
30/01d- 12
30/01d- 10
23/22b- 6Z
22/30a- 17
22/30a- 16
22/23c- 8X
30/13- 3
30/08- 3
30/08- 229/10- 4
29/10- 2
29/07- 1
28/02- 1
22/29- 2
22/19- 1
22/18- 3
22/15- 4
22/15- 3
22/04- 3
21/27- 2
21/24- 4
21/24- 1
21/02- 2
21/02- 1
20/08- 2
20/03- 4
16/23- 4
16/22- 5
16/22- 4
16/18- 1
15/30- 5
15/30- 2
15/18- 2
15/13- 2
14/20- 6
30/29a- 1
30/11b- 4
30/11b- 3
30/01c- 3
29/09b- 2
29/09a- 1
29/08b- 2
29/08a- 4
29/08a- 3
29/05a- 1
29/03b- 9
28/03- 1B
23/21- 6Z
22/24b- 8
22/23b- 5
22/22b- 2
21/30- 25
21/30- 1721/30- 12
21/29b- 9
21/29b- 4
21/28a- 2
21/27- 1A
21/20b- 4
21/20a- 5
21/08- 4Z
21/06b- 8
20/04a- 8
15/27-E1Z
15/26b- 9
15/24a- 4
15/22- 16
15/21a- 7
15/18a- 6
15/12b- 4
30/07a- 1230/07a- 10
30/01a- 11
28/09a- 5A
22/24e- 1221/29d- 11
21/13b- 1A
21/05a- 6Z
16/13a- 2Z
15/23d- 13
15/21b- 47
15/21a- 51
15/21a- 46
15/18b- 11
15/13a- 10
14/20b- 17
30/17a- 14Z
30/01f- 13Z
20/05a- 10Y
15/27a- 12A
15/25c- 15A15/21a- 38Z
21 22 23
28 29 30
1615
20
31
27
14
BRITANNIA
EVEREST
JUDY
JOANNE
AUK
FORTIES
FRAM
NELSON
ORION
JASMINE
PIPER
SCOTT
FRANKLIN
CLAYMORE
TARTAN
ARBROATH
MONTROSE
ATHENA
THELMA
BRAE
BRODGAR
STELLA
AFFLECK
PICT
DONAN
KYLE
CYRUS
BUCHAN
MACHAR
ELGIN
SHAW
HOWE
MUNGO
JADE
ENOCH
FLEMING
LOMOND
ALBA
KINNOULL
ROCHELLE
GALLEY
GANNET A
FLYNDRE
HARRIER
MAUREEN
MARIA
CLYDE
SCAPA
ERSKINE
ALMA
SHEARWATER
GUILLEMOT WEST
GODWIN
BURGHLEY
CURLEW
CALEDONIA
TELFORD
ANDREW
LARCH
BANFF
TONI
FARRAGON
PIERCE (oil)
GOLDENEYE
BALMORAL
DURWARD
BLANE
BRENDA
GANNET D
COOK
ALDER
HERON
MEDWIN
AUK NORTH
GANNET C MADOES
IONA
RENEE
CALLANISH
CAWDOR
HIGHLANDER
BACCHUS
CLAPHAM
GANNET F
SALTIRE
MARNOCK-SKUA (cond)
SHELLEY
FULMAR
STARLING
TWEEDSMUIR SOUTH
CAYLEYMALLARD
HUNTINGTON
MERGANSER
DAUNTLESS
HAWKINS
LEVEN
DUART
JANICE
BIRCH
HALLEY
LOCHRANZA
CATCHER
MIRREN
KITTIWAKE
MILLER
MACCULLOCH
INNES
GANNET B
TIFFANY
TEAL
WOOD
BLAIR
GLAMIS
GUILLEMOT A
CHESTNUT
DRAKE
SYCAMORE
RUBIE
SCOTER (gas)
GANNET E
TWEEDSMUIR
BURGMAN
GALIA
MAULE
BLENHEIM
CURLEW C
BITTERN (oil)
MOIRA
SEYMOUR
GADWALL
TONTO
NICOL
BRECHIN
GROUSE
ANGUS
MONAN
ROB ROY
ARKWRIGHT
CARNOUSTIE
CHANTER
STIRLING
SAXON
MARNOCK-SKUA (oil)
GLENELG
ENOCHDHU
TEAL SOUTH GANNET G
IVANHOE
HANNAY
BALLOCH
GUILLEMOT NORTH
GUILLEMOT NORTH WEST
EGRET
SCOLTY
JAMES
PIERCE (gas)
BLADON
VARADERO
BARDOLINO
BEAULY
CRATHES
PIERCE (gas)
PETRONELLA
GOOSANDER
BITTERN (gas)
NETHAN
BRIMMOND
HAMISH
SCOTER (oil)
FLORA
3°E
3°E
2°E
2°E
1°E
1°E
0°
0°
58°N
58°N
57°N
57°N
Esri, DeLorme, GEBCO, NOAA NGDC, and other contributors
0 20 4010 Miles
0 30 6015 Kilometres
1:300,000
Coordinate System: ED 1950 UTM Zone 31N
Date: 07/10/2016
Contains Data from ESRI, CDA, NPD, TNO and OGA
© Crown copyright 2016. You may re-use this information (not including logos) free of charge in any format or medium, under the
terms of the Open Government Licence.
To view this licence, visit http://www.nationalarchives.gov.uk/doc/open-government-licence/version/3/ or write to the Information
Policy Team, The National Archives, Kew, London TW9 4DU, or email: psi@nationalarchives.gsi.gov.uk.
Any enquiries regarding this publication should be sent to us at john.seabourn@oga.gsi.gov.uk.
CNS Unsanctioned Discoveries including Small Pools
Legend
OGA - Licensed Blocks
Condensate Field
Gas Field
Oil Field
Licensed Pools
Condensate
Gas
Oil
UnLicensed Pools (Gas)
P50 recoverable (mmboe)
0 - 10
10 - 20
20 - 30
30 - 50
50<
UnLicensed Pools (Oil)
P50 recoverable (mmboe)
0 - 10
10 - 20
20 - 30
30 - 50
Pipelines
Oil Pipeline
Gas Pipeline
Other Pipeline
Mixed Hydrocarbons Pipeline
Surface/Subsurface Infrastructure
" Platform
&- FPSO
$ Tee Piece
# Manifold
Norwegian Discoveries
Norwegian Facilities
´
OI
L =
O
, O
&G
GA
S =
G
, G
&O
, G
C Scale
DISCOVERY
PENG 356: Project Evaluation of Oil and Gas Field
INSTRUCTIONS
The assessment for this module comprises the production of a field development plan for an oilfield. It
is split into two parts to be completed in succession over the course of the module.
There is an element of individual and group work. Groups will be assigned randomly. All group
submissions should have a cover sheet signed by each individual in the group as evidence of your
participation and contribution. If your signature is not on the cover sheet, then you will not be assigned
any marks. No individual submission in lieu of a group submission will be accepted.
Submission will be via Google Classroom (code: 5bgusd3, see schedule). Penalties for late
submission will be in accordance with the department’s policy (Student Handbook). Data for the case
study is provided here and will be released in two stages as per the schedule below. Please read the
assignment brief carefully.
SUBMISSION & SCHEDULE
ALL assignments should be submitted as a PDF.
1 – Reservoir and Wells Evaluation
Available immediately. Submission Deadline is 5 weeks from course start date.
1A Development Opportunity (INDIVIDUAL) 30 Marks
1B Wells Productivity (INDIVIDUAL) 20 Marks
2 – Field Development Plan
Available the day after submission of first part of assignment.
2A Option Design, Selection and Evaluation (GROUP) 20 Marks
– Process flow diagram for topsides (Group).
– Completed Excel Workbook (Group) [Detailed study will be presented in PENG 457]
2B Investment Decision Paper (INDIVIDUAL) 30 Marks
1
PART 1 – RESERVOIR AND WELLS EVALUATION (INDIVIDUAL
SUBMISSION, 50 MARKS)
1A Development Opportunity Description (30 marks)
Based on the information provided, prepare an initial high-level evaluation of the development setting
out the main parameters of the field. The document should be structured with the following sections:
• Executive Summary.
• Reservoir Fluids.
• Hydrocarbon Reserves.
• Depletion Plan.
• Export Routes.
The following should be covered in each section as appropriate:
• Summary paragraph providing an overview of the development with pertinent information for
decision makers.
• Description of the hydrocarbon characteristics at reservoir conditions, including a representative
phase envelope for the fluids.
• Characterisation of the oil at stock tank conditions.
• Estimate of the hydrocarbon reserves initially in place.
• Estimated recovery factor based on the preliminary production profile provided.
• Qualitative evaluation of the potential depletion plan options, including enhanced oil recovery.
• Qualitative evaluation of the potential export routes.
PAGE LIMIT = 2 sides A4, Font 11 (excluding appendices which MUST include supporting
calculations)
1B Wells Productivity (20 Marks)
Data from a well test is provided along with a proposed production well design. Using this data and
assuming semi steady-state incompressible flow:
1. Determine the average well productivity index for a production well.
2. Construct a well inflow performance curve for a production well which should include the absolute
open flow oil rate.
2
3. Estimate the number of wells required to achieve the peak production rate shown in the
production profile. Assume that the drawdown is limited to 1000 psi for production.
PAGE LIMIT = 2 sides A4, Font 11 with answers to questions 1 – 3 (excluding appendices with
supporting calculations)
3
PART 2 - FIELD DEVELOPMENT PLAN (INDIVIDUAL SUBMISSION,
50 MARKS)
Ensure you submit a PFD and completed workbook for 2A
2A OPTION DESIGN, SELECTION AND EVALUATION
(GROUP SUBMISSION, 20 MARKS)
The Group task is to work together to evaluate each of the Options (A, B, C, D, E) and make a
final selection. An economic assessment of the development based on the selected option is to be
presented along with a topsides process scheme. Work in your assigned Groups to produce the
following:
• Process Flow Diagram
• Economic Assessment
• Options Ranking and Final Option Selection
Further details on the requirements are set out below.
Process Flow Diagram (10 marks)
Based on the information provided, propose an oil and gas processing scheme for your selected Option
in the form of an annotated block diagram showing key design parameters – pressure, temperature,
oil residence time and flow. (There is no need to show duplicate equipment, just indicate this on the
block diagram as “x2”). Provide the rationale for the major design decisions.
For Options A, B, C, and D your considerations should include issues such as:
• Number of separation stages required.
• Number of trains.
• Processing capacities.
• Impact of temperature in separation and the optimum place(s) for heat input.
• Recycling of separated water.
• Residence times.
• Sufficiency of gravity separation alone.
• Requirement for gas dehydration.
• Number of compression stages (assume 4:1 compression ratio).
4
For Option E the following guidance should be used for developing a process flow scheme:
• Read the Scott Ullage profiles document at the website link provided in the Case Study Data.
• Seabed temperature = 5°C.
• Scott does not have any spare three phase separation capacity.
• Scott gas handling system comprises four stages of compression with gas dehydration between
the third (HP) and fourth (Export) stage operating at 68 barg. Identify tie-in locations for gas
from your development. The compressor suction pressures are as follows:
– Low Pressure (LP) = 7.1 barg
– Intermediate Pressure (IP) = 12.9 barg
– High Pressure (HP) = 20.5 barg
– Export = 67 barg
• Show the required flowline connections between the subsea wells and the topsides for all the
required fluid streams.
PAGE LIMIT = PFD should be submitted on a single PowerPoint slide or as a PDF. Explanatory
notes of decisions should be limited to a single side of A4, Font 11 (preferably in PDF format).
Economic Assessment (5 marks)
Use the Excel workbook provided to help with economic screening of the Options. A full economic
assessment for your final selected Option must be presented in the Excel workbook provided, including
any sensitivity analysis. Use the Notes tab in the workbook to provide a summary of all major
assumptions used in the analysis. WORD COUNT LIMIT FOR NOTES = 500
Options Ranking and Final Option Selection (5 marks)
Company A screens concepts in the following categories all with equal weightings: technical (25%),
economic (25%), safety (25%), and environmental (25%). Using these categories provide an
assessment for each Option with appropriate evidence in the Excel workbook provided:
• Complete the option ranking in the Excel workbook. Rank each option from 4 (most preferred)
to 0 (least preferred) against each of the criteria providing comments as appropriate.
• Present a final recommendation for the development supported by a short summary outlining
the main reasons for your selection in the allocated box within the Excel workbook (200 words
maximum).
The Economic Assessment and Options Ranking should be completed and submitted in the
Excel Workbook provided. Ensure you provide entries in all the required cells.
5
2B INVESTMENT DECISION PAPER
(INDIVIDUAL COMPONENT, 30 MARKS)
Write an Investment Decision Paper making your recommendation for which Option Company A
should pursue. Your answer should comprise the following sections:
1. Development Plan – summarise the selected Option including export routes for products.
2. Petroleum Reserves – describe the economic recovery of petroleum reserves including total
production, life of project and any enhancements which might be considered for improved oil
recovery.
3. Financial summary – summarise the total Capital Expenditure, phased spending profile and
overall economic performance of the development.
4. Risks – discuss four main risks to the ultimate value of the development and identify mitigations
or opportunities for each risk that should be pursued in the next stages of the development.
PAGE LIMIT = 2 sides A4, Font 11 (excluding appendices). You should submit 1 file (a PDF
document).
6
Degree of BSc in Petroleum Engineering
BSc Petroleum Engineering
PENG 356 Practical Evaluation of Oil and Gas Field
CASE STUDY DATA – PART 1
Acronyms & Abbreviations
STOIIP Stock tank oil initially in place
API American Petroleum Institute
FPSO Floating Production Storage & Offloading
BS&W Base Sediment & Water
TEG Tri-ethylene glycol
RVP Reid Vapour Pressure
NPV Net present value
CAPEX Capital Expenditure
IRR Internal rate of return
OPEX Operating Expenditure
GOR Gas oil ratio
ST Stock tank
mbd thousand barrels per day
MMscfd Million standard cubic feet per day
STB stock tank barrels
scf standard cubic feet
g/cc grams per cubic centimetre
cf cubic feet
bbls barrels
therm unit of heat energy
Location
Buchan Area of the Central North Sea – refer to map provided.
Water Depth = 120 m
Infrastructure in the Area
Information on capacity and entry specifications for infrastructure in proximity to the development can be found at the following links:
Flotta Oil Terminal
https://www.repsolsinopecuk.com/files/ICOP_Flotta_2017.pdf
Forties Pipeline
https://www.ineos.com/businesses/ineos-fps/technical/system-ullage/
SAGE Pipeline
http://www.ancalamidstream.com/technical/
Scott
https://intl.cnoocltd.com/operations/europe/uk
Reservoir Characteristics
Crude Oil Gravity [°API]
35.8
Cumulative Solution GOR [scf/STB]
395.1
Reservoir Depth [m]
2860 m
Initial Pressure at Datum [psia]
4473
Reservoir Temperature [°C]
104.4
Bulk rock volume [m3]
3.38x109
Net to gross ratio
0.823
Average Porosity; φ
10.9%
Area [sq km]
14.28
Average water saturation; Sw
0.23
Average permeability [md]
21
Well Sample Analysis
Differential Vaporisation @ 104.4°C
Pressure
Oil Volume Factor Bo
GOR
Rs
Gas
Compressibility
Gas Formation Volume Factor Bg
Gas gravity
Liquid density
bbls/STB
scf/STB
Z
cf/scf
psia
g/cc
4473
1.3034
395.1
-
-
-
0.7417
3749
1.3181
395.1
-
-
-
0.7334
3499
1.3236
395.1
-
-
-
0.7304
2999
1.3353
395.1
-
-
-
0.7239
2949
1.3366
395.1
-
-
-
0.7233
1846
1.3672
395.1
-
-
-
0.7071
1610
1.3657
395.1
0.914
0.0109
0.73
0.7062
1465
1.3462
383.9
0.917
0.0120
0.73
0.7121
1320
1.3274
353.7
0.920
0.0134
0.73
0.7178
1175
1.3093
324.2
0.923
0.0151
0.74
0.7234
1030
1.2918
295.5
0.927
0.0173
0.75
0.7289
885
1.2748
267.5
0.932
0.0203
0.76
0.7342
740
1.2582
240.0
0.937
0.0244
0.78
0.7394
595
1.2418
212.9
0.943
0.0305
0.80
0.7445
350
1.2122
186.1
0.954
0.0525
0.89
0.7535
100
1.1655
139.0
0.969
0.1866
1.25
0.7651
15
1.0865
74.6
0.984
1.2888
2.31
0.7784
15
1.0000
-
-
-
-
0.8457
A HYSYS file “CP527_971 case study base data.hsc” is provided with the above differential vaporisation test reconstructed.
Oil Properties
Wax
Wax appearance temperature 35°C. Wax dissolution temperature 60°C.
Wax content – 6.2 wt.%.
H2S
The reservoir is likely to sour quickly if injected with raw untreated seawater. Souring prevention and mitigation measures will therefore be required if pressure support from water injection is to be utilised. The peak H2S production rate has been calculated as 113 kg/d and preliminary modelling shows that this results in a maximum gas phase H2S concentration of
Degree of BSc in Petroleum Engineering
BSc Petroleum Engineering
PENG 356 Practical Evaluation of Oil and Gas Field
CASE STUDY DATA – PART 2
Acronyms & Abbreviations
STOIIP Stock tank oil initially in place
API American Petroleum Institute
FPSO Floating Production Storage & Offloading
BS&W Base Sediment & Water
TEG Tri-ethylene glycol
RVP Reid Vapour Pressure
NPV Net present value
CAPEX Capital Expenditure
IRR Internal rate of return
OPEX Operating Expenditure
GOR Gas oil ratio
ST Stock tank
mbd thousand barrels per day
MMscfd Million standard cubic feet per day
STB stock tank barrels
scf standard cubic feet
g/cc grams per cubic centimetre
cf cubic feet
bbls barrels
therm unit of heat energy
Location
Buchan Area of the Central North Sea – refer to map provided.
Water Depth = 120 m
Infrastructure in the Area
Information on capacity and entry specifications for infrastructure in proximity to the development can be found at the following links:
Flotta Oil Terminal
https://www.repsolsinopecuk.com/files/ICOP_Flotta_2017.pdf
Forties Pipeline
https://www.ineos.com/businesses/ineos-fps/technical/system-ullage/
SAGE Pipeline
http://www.ancalamidstream.com/technical/
Scott
https://intl.cnoocltd.com/operations/europe/uk
Reservoir Characteristics
Crude Oil Gravity [°API]
35.8
Cumulative Solution GOR [scf/STB]
395.1
Reservoir Depth [m]
2860 m
Initial Pressure at Datum [psia]
4473
Reservoir Temperature [°C]
104.4
Bulk rock volume [m3]
3.38x109
Net to gross ratio
0.823
Average Porosity; φ
10.9%
Area [sq km]
14.28
Average water saturation; Sw
0.23
Average permeability [md]
21
Well Sample Analysis
Differential Vaporisation @ 104.4°C
Pressure
Oil Volume Factor Bo
GOR
Rs
Gas
Compressibility
Gas Formation Volume Factor Bg
Gas gravity
Liquid density
bbls/STB
scf/STB
Z
cf/scf
psia
g/cc
4473
1.3034
395.1
-
-
-
0.7417
3749
1.3181
395.1
-
-
-
0.7334
3499
1.3236
395.1
-
-
-
0.7304
2999
1.3353
395.1
-
-
-
0.7239
2949
1.3366
395.1
-
-
-
0.7233
1846
1.3672
395.1
-
-
-
0.7071
1610
1.3657
395.1
0.914
0.0109
0.73
0.7062
1465
1.3462
383.9
0.917
0.0120
0.73
0.7121
1320
1.3274
353.7
0.920
0.0134
0.73
0.7178
1175
1.3093
324.2
0.923
0.0151
0.74
0.7234
1030
1.2918
295.5
0.927
0.0173
0.75
0.7289
885
1.2748
267.5
0.932
0.0203
0.76
0.7342
740
1.2582
240.0
0.937
0.0244
0.78
0.7394
595
1.2418
212.9
0.943
0.0305
0.80
0.7445
350
1.2122
186.1
0.954
0.0525
0.89
0.7535
100
1.1655
139.0
0.969
0.1866
1.25
0.7651
15
1.0865
74.6
0.984
1.2888
2.31
0.7784
15
1.0000
-
-
-
-
0.8457
A HYSYS file “CP527_971 case study base data.hsc” is provided with the above differential vaporisation test reconstructed.
Oil Properties
Wax
Wax appearance temperature 35°C. Wax dissolution temperature 60°C.
Wax content – 6.2 wt.%.
H2S
The reservoir is likely to sour quickly if injected with raw untreated seawater. Souring prevention and mitigation measures will therefore be required if pressure support from water injection is to be utilised. The peak H2S production rate has been calculated as 113 kg/d and preliminary modelling shows that this results in a maximum gas phase H2S concentration of
Degree of BSc in Petroleum Engineering
BSc Petroleum Engineering
PENG 356 Practical Evaluation of Oil and Gas Field
CASE STUDY DATA – PART 3
Acronyms & Abbreviations
STOIIP Stock tank oil initially in place
API American Petroleum Institute
FPSO Floating Production Storage & Offloading
BS&W Base Sediment & Water
TEG Tri-ethylene glycol
RVP Reid Vapour Pressure
NPV Net present value
CAPEX Capital Expenditure
IRR Internal rate of return
OPEX Operating Expenditure
GOR Gas oil ratio
ST Stock tank
mbd thousand barrels per day
MMscfd Million standard cubic feet per day
STB stock tank barrels
scf standard cubic feet
g/cc grams per cubic centimetre
cf cubic feet
bbls barrels
therm unit of heat energy
ECONOMIC DATA
Economic Information (use spreadsheet provided)
Tariffs - oil pipeline 1.20 £/bbl, gas pipeline 8 £/MMscf
Oil price - 50 $/bbl
Gas price - 0.50 £/therm (assume 96.6 scf/therm for produced gas)
Capital cost (CAPEX) estimating:
Item
£ million
Schedule [months]
Steel Jacket - accommodation
97.0
9
Steel Jacket – production and drilling
204.0
12
Topsides- accommodation only
104.0
14
Topsides - production
Based on capital cost blocks
20
FPSO – hull and marine systems
184.0
18
Drilling - wet trees (per well)
39.0
2 months per well
Drilling - platform, dry trees (per well)
27.0
1 month per well
Pipeline (installed cost per km)
1.7
4 km per day
Subsea systems (per template)
48.0
Module on host platform (excludes production equipment)
186.0
24 months
% of Total Equipment Costs
Bulks (valves, pipe, cables) - topsides
70%
% of Total Bulk +Equipment Costs
Engineering
8%
Installation (where not included above)
4%
Owners costs
5%
Unallocated Provision
7%
Capital Cost Blocks for Equipment Items
Production separator: $5 million each
Production Heat Exchanger: $1.5 million
LP compressor (motor driven): $20 million
LP compressor (GT driven): $30 million
MP/HP compressor (motor driven): $30 million
MP/HP compressor (GT driven): $40 million
Gas dehydration unit: $14 million
Instrument air utilities: $3 million
Cooling Water & Utilities: $18 million
Flare system: $12 million
Power Generation: $45 million
Major Pumps (50000 bbls/day capacity - water injection, main oil export etc.): $15 million each
Process Pumps (water recycle etc.): $0.7 million each
Produced Water Treatment: $12 million
Abandonment costs £120 million
Operating expenditure (OPEX) = 8 £/bbl total liquids
Taxes - 20% profit
Discount rate 9%
Drilling
10 production wells each with a design oil rate of 12000 bbls/day
Three water injection wells with a design water rate of 20000 bbls/day
Production
Operating efficiency benefit from dual trains is estimated to be 3% overall.
Capital Expenditure (CAPEX) Phasing
Option
First Oil Year
CAPEX Phasing by Year [%]
2021
2022
2023
2024
2025
2026
A & B
2025
10
10
25
20
20
15
C
2023
10
25
25
25
10
5
D
2024
10
10
20
25
20
15
E
2023
10
30
30
25
5
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