Basis for Design New

7/31/2019 Basis for Design New

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CHESTER MEAD ASSOCI ATES LI MI TED

BASI S FOR DESI GN

FOR

MI DWESTERN OI L AND GAS COMPANY PLC

PROJECT:

UMUSADEGE CENTRAL PROCESSI NG FACI LI TY

ENGI NEERI NG AND PROCUREMENT SERVI CES

CONTRACT NUMBER:

xxxxxxxxxxxx

DOCUMENT NUMBER:EAL/UMUCPF/GEN/DOC/001

AO2 30/04/2012Issued forApproval

AD KK

Rev. Date Description Originator Released Approved (Client)


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UMUSADEGE CENTRAL PROCESSING FACILITY ENGINEERING AND PROCUREMENT SERVICES

BASIS FOR DESIGN - CMA/ UMUCPF/ MDR-GEN/ DOC/ 003Feb 28, 2012

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ADDI TI ONAL AGREEMENT / APPROVAL RECORDS

Part y Rev. I nd. Name Sign Date

REVI SI ON PHI LOSOPHY

All revisions for review will be issued at R01, with subsequent R02, R03, etc asrequired.

All revisions approved for issue or design will be issued at A01, with subsequentA02, A03, etc as required.Documents approved for Construction will be issued at C01, C02, and C03respectively.Documents or drawings revised as As built will be issued as Z01, Z02 Z03 etc.Narrative sections revised from previous approved issues are to be noted in thetable below and/or highlighted in the RH margin (using the appropriate revisionstatus) thus: | A02Previous revision highlighting to be removed at subsequent issues.Drawings/diagrams revised from previous approved issues are highlighted by

'clouding' the affected areas and by the use of a triangle containing the revisionstatus.

REVI SI ON HI STORY

Rev. No.Date ofI ssue

Reason for change

R02 IDC

A01 28/02/12MWOG CommentsRevised Production Forecasts & Well Streams Data

Deleted Offspec collection within CPF


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Table of Cont ent s

GLOSSARY 8

1.0 INTRODUCTION ............................................................................................. 151.1 Purp ose ................................................................................................ 151.2 The Umusadege Field ........................................................................ 151.3 The Field s Fac ilities Develop ment Ob jec tives .............................. 151.4 Ove rview of The Field s Existing Proc essing Fac ilities .................... 15

2.0 KEY CONSIDERATIONS .................................................................................. 172.1 Mode .................................................................................................... 172.2 Brow n Field Eng ineering / Stra te gy Fit ............................................. 172.3 Field Life ............................................................................................... 172.4 Effic ienc y & Op timum Oil Rec overy from the Proc ess Systems .. 172.5 Dry Crud e Export ................................................................................ 172.6 Zero Effluent Emission ......................................................................... 18

3.0 THE EXISTING FACILITIES & INFRASTRUCTURE............................................... 193.1 Surfa ce Fac ilities in Plac e .................................................................. 193.2 The Ea rly Produc tio n Fac ility ............................................................. 193.3 The Field Infra struc ture ...................................................................... 20

4.0 DESIGN REQUIREMENTS ................................................................................ 214.1 Design Capac ities & Spec ifica tions ................................................ 214.2 Well Fluid Cha rac te ristic s and Prop erties ....................................... 224.3 Export Crude Spec ifica tion............................................................... 22


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4.4 Prod uc ed Effluent Wate r Spec ifica tion .......................................... 234.5 Cha rac te rised Well Fluid Da ta ......................................................... 234.6 Formation Wate r Ana lysis .................................................................. 244.7 Prod uc tion Start-Up ............................................................................ 244.8 Erosion Veloc ity & Noise .................................................................... 254.9 Fac ility Sta nd ards ............................................................................... 254.10 Design Simulation Software .............................................................. 25

5.0

THE CENTRAL PROCESSING FACILITY ........................................................... 26

5.1 Fac ilities / Proc ess Desc ription ......................................................... 265.2 Design & Operating Philosophy ....................................................... 295.2.1 The Inlet and Intermediate / ESD Va lves Manifold ....................... 305.2.2 The Test Sepa rator .............................................................................. 315.2.3 The HP Separator ................................................................................ 315.2.4 The LP Separator ................................................................................ 315.2.5 The Gas Boot ....................................................................................... 325.3 The Crud e Export Pum ps ................................................................... 325.4 The Closed Drain System ................................................................... 325.5 Gas Hand ling ...................................................................................... 325.6 Flare System ........................................................................................ 335.7 Water Trea tment ................................................................................ 335.8 Storage Tanks ...................................................................................... 335.9 Diesel Sto rage and Dispensing ........................................................ 355.10 Servic e & Fresh Water System .......................................................... 35


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9.2 LAYOUT CO NSIDERATIONS ................................................................ 4410.0 FIRE PROTECTION .......................................................................................... 46

10.1 Fire Wate r ............................................................................................ 4610.2 Fire and Gas Dete c tion Syste m ....................................................... 46

11.0 ELECTRICAL DESIGN BASIS ........................................................................... 4711.1 Power Generation .............................................................................. 4711.2 UPS ........................................................................................................ 48

11.3

Power Transmission & Distribut ion .................................................... 48

12.0 HSE/ SD REQUIREMENTS ................................................................................. 4912.1 Safety Considerations ........................................................................ 4912.2 Environm enta l Considerations ......................................................... 4912.3 Sec urity Considerations ..................................................................... 4912.4 Risk Assessment and Mana gement ................................................ 50

13.0 ASSET MANAGEMENT ................................................................................... 5113.1 Operating Philosop hies ..................................................................... 5113.2 Asset Reference Plan......................................................................... 51

14.0 MANAGEMENT OF CHANGE & QUALITY ..................................................... 5214.1 Design Change .................................................................................. 5214.2 Qua lity Assuranc e and Control Requirements .............................. 52

15.0 STATUTORY AND REGULATORY COMPLIANCE ............................................ 5315.1 Nigerian Content ............................................................................... 5315.2 Regula to ry Considerations ............................................................... 53

16.0 APPENDICES .................................................................................................. 56


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BFD Matrix ....................................................................................................... 56Produc tion Forec ast / Well Fluid Cha rac teristics and Properties........... 56Fire and Gas Detec tion ................................................................................ 56Proposed General Layout ............................................................................ 56


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GLOSSARY

The Following definitions and abbreviations have been used in this document.

Organisational

API American Petroleum Institute

Client Midwestern Oil & Gas Company Plc

Consultant Chester Mead Associates Limited

CMA Chester Mead Associates Limited

DPR Department of Petroleum Resources

FME Federal Ministry of Environment

MWOG Midwestern Oil & Gas Company Plc

NAPIMS Nigerian Petroleum Investment Manageme

Services

NCD Nigerian Content Division


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CMA-MWOG UMUSADEGE CPF ENGINEERING DESIGN AND PROCUREMENT SERVICESBASIS FOR DESIGN - CMA/UMUCPF/MDR-GEN/DOC/004

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Definitions and Abbreviations (continued)

Technical Terms

AC Alternating Current

AG Associated Gas

AGG Associated Gas Gathering

ALARP As low as reasonably practicable

BFD Basis for Design

B/L Bulkline

BS&W Base Sediments & Water

CASHES Community Affairs, Safety, Health, Environment and Security

CITHP Closed-in Tubing Head Pressure

CNG Compressed Natural Gas

cP Centipoise

CP Cathodic Protection

CPF Central Processing Facility

CPP Central Power Plant

CPU Central Processing Unit

CCR Central Control Room

DCS Digital Control System

D/L Delivery Line

EIA Environmental Impact Assessment

EPF Early Production Facility

ESD Emergency Shutdown

FEED Front End Engineering & Design


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FOB Freight on Board


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Technical Terms (contd.)

F&G Fire and Gas Detection System

F/L Flowline

F/S Flowstation

GGF Group Gathering Facility

GTL Gas To Liquids

GOR Gas Oil Ratio (Surface)

HEMP Hazard and Effects Management Process

HMI Human Machine Interface

HP High Pressure

HSE Health, Safety and Environment

HV High Voltage

HVAC Heating, Ventilation and Air Conditioning

IGF Induced Gas Flotation

ITC Incoming Termination Chamber

I/O Input/output

LACT Lease Automated Custody Transfer

LCR Local Control Room

LEL Low explosion limitLER Local Equipment Room

LPG Liquefied Petroleum Gas

L/P Line Pipe

LP Low Pressure


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LV Low Voltage


Technical Terms (contd.)

MCS Master Control Station

MOC Management of Change

M/F Manifold

OML Oil Mining Lease

PAS Protective Alarm System / Process Automation System

PAGA Public Address and General Alarm

PES Programmable Electronic Systems

PFD Process Flow Diagrams

PID Control Proportional-Integral-Derivative Control

PSD Process Shutdown

P/L Pipeline

RAM Risk Assessment Matrix

SD Sustainable Development

SDV Shutdown Valve

SIMOPS Simultaneous Operations

SPIR Spare Parts List and Interchangeability RecordSRS Safety Requirement Specifications

TMR Triple Modular Redundant

TPI Tilted Plate Interceptor


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Units of Measurements

BCF, bcf Billion Cubic Feet

bpd Barrels per Day

bopd Barrels of Oil per Day

Bscf Billion Standard Cubic Feet

bwpd Barrels of Water per Day

CFM Cubic Feet per Minute

Deg C Degree Centigrade

ft Feet

km Kilometer

km/h Kilometer per Hour

kVA Kilovolts Ampere

m Meter

M Thousand

MBD Thousand Barrels per Day

MM Million

MMscfd Million Standard Cubic Feet per Day

MMstb Million Stock Tank Barrels

MMMscf Billion Standard Cubic Feetpsi Pounds per Square Inch

ppm Parts Per Million

scf Standard Cubic Feet

scf/b Standard Cubic Feet per Barrel


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USD United States Dollar


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1.0 I NTRODUCTI ON

1.1 Purpose

This document establishes the design criteria, outlines the system design,

equipment and component design features, as well as the performance

characteristics consistent with those criteria. The document also creates the

framework for the instruction documents and construction specifications. The

contents of this document represent the objectives of the owner, project

engineers, and consultants in terms of design features, systems functionality, and

performance.

1.2 The Umusadege Field

Umusadege is a marginal field operated by Midwestern Oil and Gas Plc. The field

is near Kwale in Delta State of Nigeria, and is situated in OML 56. The fields

current potential is 20 Mbopd, but is currently producing about 9 Mbopd, through

an early production facility within the field, with the stabilised wet crude routed to

AGIP via existing GGF and LACT systems. Further development activities are

planned, which will maintain the fields production at this level. However, the

production forecasts from the new wells are yet to be reflected in the production

forecast reference in this BFD

1.3 The Fields Facilit ies Development Objectives

The objective is to replace the existing 10 MBD early production facility with a 20

MBD nominal capacity Central Processing Facility of two trains. Furthermore

opportunity will be taken at this stage to address and re-design HSE and

operational deficiencies to bring the fields operations to standard.

1.4 Overview of The Fields Existing Processing Facilities

The existing 10 MBD processing facility is a single train one-stage separation EPF,

consisting of a 3-phase test separator, and 3-phase group separator, and related

ancillaries. The produced crude is stored in rented tanks, from where it is pumped

to a delivery pipeline for export through AGIP. The produced water is passed


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through an oil skimmer tank and disposed to a pit. There is no AG facility and the

associated gas is currently flared.


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2.0 KEY CONSI DERATI ONSThe key considerations are presented and summarized below.

2.1 Mode

The CPF should be designed as a normally not manned facility. It should be able

to operate safely under this mode, as well as being able to be shut down safely

remotely from a PLC based control room. Its start-up has to be locally from the

field, or remotely only with local permissive from the field.

2.2 Brown Field Engineering / St rategy Fit

The design will consider the existing facilities in operation, and equipment already

ordered, and the extent to which they may be incorporated in the design, without

prejudice to HSE, operating standards, and undue production deferment.

2.3 Field Lif e

The projected field life is 20 years, for which facilities life of 25 years shall be

considered appropriate.

2.4 Eff iciency & Optim um Oil Recovery f rom the Process System s

Number of separation stages will be optimized in the light of surface oil recovery

and pressure regimes of the wellhead crude. In this respect more than one-stage

separation will be considered for the higher pressure streams, as that will improve

their oil recovery.

2.5 Dry Crude Export

The design will include infield dehydration, as export will be through a 3 rd party

facility that is willing to accept only dry crude, BSW 0.5%, and TVP 10 psia at 82o

F.


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2.6 Zero Effluent Emission

The design will aim for total gas utilization and disposal of produced gas and water

only by means approved by client.


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3.0 THE EXI STI NG FACI LI TI ES & I NFRASTRUCTURE

Existing processing facilities in the field are limited to the Early Production Facility

(EPF) and rented storage tanks. There are no existing gas processing facilities.

However, some equipment, separators, gas boots, test and production manifolds

have been procured for the planned facilities upgrade, viz:

1 No. Group Separator 8 x 40, 20 Mbopd / 7.5 MMscfd / 4 Mbwpd capacity

(already procured)

2 Nos. Gas Boot / Water Separator 3.28 x 40 (already procured)

1 No. 6 Test Manifold

1 No. 8 Production Manifold

Also two storage tanks, each of 14.5 Mbbl capacity are currently being installed, and

more may be installed later.

3.1 Sur face Facilit ies in Place

The surface facilities in place and in use are:

The 10 MBD Early Production Facility

4 Nos. Wellheads

8 Nos. Wellhead Flowlines, with one of the flowlines hooked up directly to the

Crude Storage Tank

1 No. Field Manifold, complete with Bulk Flowline and Test Line.

Group Gathering Manifold & Delivery Line

6 Nos. Rented Crude Storage Tanks

Crude Oil Metering System

3.2 The Early Product ion Facilit y

The Early Production Facility is of an ad-hoc design, of one-stage separation,

comprising the following:

1 No. Test Separator, complete with Inlet Manifold with 6 Header and ESD


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1 No. Group Separator, complete with Inlet Manifold with 8 Header and ESD- One Bulk 3-Phase Separator

3 Nos. Crude oil transfer pumps

Oil saver skimmer / drain pit system

Diesel system

Instrument air system

Flare system - complete with flare liquid knock-out vessel

Service and fresh water system

Chemical (de-emulsifier) injection system

Power Generation System, - 1 No. 350 kVA & 1 No. 250 kVA Diesel Engine

Sets

Drain Systems, complete with 2 drain water pumps that inject water from the

storage tanks into the drain pit.

3.3 The Field I nfr ast ructur e

The key field infrastructure comprise of the following:

Custody transfer unit - 14,000 bpd capacity, complete with 6 bidirectionalloop for meter proving

A new CAT 725 kVA Diesel Engine Set

Utility air generation, - 2 Compressors of 375 CFM at 120 psi and a self

support test separator instrument air compressor

6 Nos. Crude storage tanks of 12,000 barrels total capacity

Effluent water handling capacity of 2,500 bpd.


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4.0 DESI GN REQUI REMENTS

4.1 Design Capacities & Specifications

The production profile constructed from the fields well streams forecasts is shown

below, with potential production of 23 Mbpd as peak, declining steadily. The

forecasts are from the present wells only, excluding future wells. The production

potentials of the future wells are yet to be established but believed to be

substantial to fully utilize what would be the installed capacity of the CPF.

Productio Year 0 1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 18 19 20 21 22

Forecast Rate 2011 2012 2013 2014 2015 2016 2017 2018 2019 2020 2021 2022 2023 2024 2025 2026 2027 2028 2029 2030 2031 2032 2033

2011 2012 2013 2014 2015 2016 2017 2018 2019 2020 2021 2022 2023 2024 2025 2026 2027 2028 2029 2030 2031 2032 2033

Oil - Mbopd 19.6 17.6 15.8 14.3 12.8 11.6 10.4 9.4 8.4 7.6 6.8 6.1 5.5 5.0 4.5 4.0 3.6 3.3 2.9 2.6 2.4 2.1 1.9

Gas - MMscfd 3.5 7.9 8.3 10.4 10.4 9.6 8.5 6.9 5.5 4.7 4.3 3.8 3.4 3.1 2.8 2.5 2.3 2.0 1.8 1.6 1.5 1.3 1.2

Water - Mbwpd 2.3 2.5 2.7 3.0 3.3 3.5 3.2 3.0 2.8 2.5 2.0 1.8 1.5 1.3 1.0 0.9 0.8 0.7 0.7 0.6 0.5 0.5 0.4

Projected at 10% decline, as supplied forecast did not cover the period

Field' s Production Forcast

0.0

5.0

10.0

15.0

20.0

25.0

2 01 1 2 01 2 2 01 3 2 01 4 2 015 20 16 2 01 7 2 01 8 20 19 2 02 0 2 021 20 22 2 02 3 2 02 4 20 25 2 02 6 2 027 2 02 8 2 029 2 03 0 20 31 2 03 2 2 03 3 2 03 4 2 035 20 36

Field'sProductionProfile ConstructedfromWellStreamsOIlProductionForecast


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4.2 Well Fluid Characteri stics and Propert ies

Well Reservoir / Reservo ir Bubble Oil Water Wellhead API Tank Oil

String Datum Depth Pressure Point Viscosity Viscosity Rsi Boi CITHP FTHP Temp Tank Oil Gas SG Viscosity

ft ss psia psia cP cP scf/ stb rb/ stb psig psig deg C SG (air = 1) cs

1 XIIA/ 7882 3,410 108 1.41 0.00 94 1.400 650 230 96 0.83 0.84 0.00

2 XIIB/ 7950 3,430 110 0.80 0.00 71 1.40 800 300 96 0.85 0.86 0.00

3 IX/ 7606 2,947 116 0.73 0.00 120 1.40 500 320 130 46.00 0.00 0.00

5 XVI/ 8145 3,410 372 0.70 0.00 100 1.12 680 420 151 44.00 0.00 0.00

6 XIIIA/ 8105 3,408 364 0.71 0.00 140 1.12 660 340 145 40.00 0.00 0.00

7 XIV/ 8237 3,522 570 0.64 0.00 127 1.12 780 410 140 44.00 0.00 0.00

8 XIIC/ 8005 3,435 110 0.69 0.00 132 1.12 800 640 135 40.00 0.00 0.00

UMU 7L

Subsurface Conditions Wellhead / Surface Flow Conditions

UMU 1S

UMU 1L

UMU 5L

UMU 6L

UMU 6S

SerialN

o.

UMU 7S

4.3 Export Crude Specification

Reid Vapor Pressure (RVP) 10.0 psia

True Vapor Pressure (TVP) 10.5 psia @ maximum storage temperature

Basic sediment and water 0.5 volume percent

Salt content 35 lb/kstb

Storage Temperature 80 - 82 F


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4.4 Produced Eff luent Water Specification

Maximum instantaneous dispersed oil content of produced water discharges will

be 10ppm.

4.5 Characteri sed Well Fluid Data

Component Mole % Specificgravity

Molecular weight NBP (F)

Nitrogen 0.19

Carbon dioxide 0.14

Hydrogen sulphide 0.00

Methane 8.71

Ethane 3.56Propane 7.34

i-Butane 5.97

n-Butane 6.80

i-Pentane 5.19

n-Pentane 3.61

Hexanes 5.53

Heptanes Plus 5.32 0.7227 96 TBD

Octane Plus 8.28 0.7457 107 TBD

Nonane 5.17 0.7648 121 TBD

Decane 4.69 0.7788 134 TBD

Undecane 3.18 0.7898 147 TBD

Dodecane 2.60 0.8008 161 TBD

Tridecane 2.44 0.8118 175 TBDTetradecane 2.21 0.8228 190 TBD

Pentadecane 2.31 0.8328 206 TBD

Hexadecane 1.92 0.8398 222 TBD

Heptadecane 2.19 0.8478 237 TBD

Octadecane 1.22 0.8528 251 TBD

Nonadecane 1.19 0.8578 263 TBD

Eicosane 0.91 0.8628 275 TBD

Uneicosane 0.84 0.8679 291 TBD

Doeicosane 0.80 0.8729 305 TBD

Trieicosane 0.73 0.8779 318 TBD

Tetraeicosane 0.60 0.8819 331 TBD

Pentaeicosane 0.53 0.8859 345 TBD

Hexaeicosane 0.46 0.8899 359 TBD

Heptaeicosane 0.40 0.8939 374 TBDOctaeicosane 0.35 0.8969 388 TBD

Nonaeicosane 0.30 0.8999 402 TBD

Triacontane plus 4.32 0.9506 544 TBD

Total 100


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4.6 Form ation Water Analysis

Source

Umusadege6 Umusadege4(BHS @ 7,965 ft)

Date Sampled 8th February 2011 2nd March 2007

SG 1.0104 0.9980 @ 60oF

pH 7.83 @ 80oF 7.96 @ 20oC

Conductivity, s/cm @ 80oF 8,403

Resistivity, ohm.metre @60oF

5.900

Total Dissolved Solids, mg/l 4,820 1,380

Total Salinity, mg/l 4,250Total Alkalinity, mg/l 665

Hydrogen Sulphide

CATI ONS

Potassium, mg/l 23

Sodium, mg/l 1,727 295

Calcium, mg/l 16.5 145

Magnesium, mg/l 3.7 3.6

Barium, mg/l 45.0 1.2

Iron, mg/l 0.4 0.8

Strontium, mg/l 0.7

ANI ONS

Chloride, mg/l 2,303 460

Sulphate, mg/l 35 8.5

Carbonate, mg/l 25 Nil

Bicarbonate, mg/l 640 445

Hydroxide, mg/l Nil Nil

4.7 Production Start- Up

The CPF facilities will be designed to allow facility startup using the emergency

(diesel) generator system, as black start.

Facility operability during turn-down to level of 20% of design rates is anticipated.


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4.8 Erosion Velocity & Noise

The optimum diameter for the interconnecting lines between Inlet headers and

separators will be determined to ensure that flow velocities are within erosion

limits and noise avoided.

4.9 Facilit y Standards

This is necessary only in so far as is necessary to ensure variety control as well as

the stocking and inter-changeability of spare parts.

4.10 Design Simu lation Soft w are

The process design software shall be: HYSYS, Pipe Phase, Pipe Sim and Flare Net

while the facility layout shall be designed with AUTOPLANT.

Simulation data and results of analysis will be included in the design reports.


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5.0 THE CENTRAL PROCESSI NG FACI LI TYThe base case concept for the Central Processing Facility is a 2 x 20 MBD capacity

processing facility as shown in the PFD below, and will be developed with a

provision for possible future tie-ins of additional separator(s). The 2-train system is

driven by the objective to minimize production deferment through SIMOPS on the

facilities installation, as well as optimal utilization of equipment already procured.

Other related options are considered and analysed in the concept selection study

report (with Document No. CMA/UMUCPF/MDR-GEN/DOC/004).

The CPF systems include the following facilities: Oil processing and export facilities.

Well test facilities.

Utility and support systems operation.

Produced water treatment facilities.

5.1 Facilit ies / Process Descript ion

The oil processing involves two trains and 3-phase separation. The trains

configuration and installation have been planned to minimize production

deferment at transition. In this respect, the first train, Train-1, will be designed

and installed to start on one-stage LP separation, with provision to use mobile test

unit for well testing (to be evaluated), while the second train, Train-2, will be

designed and installed with the full complement of multi-stage separation,

including a test separator. The multi-stage separation will start with two stages,

with provision for future XHP / XXHP installation as will be dictated by the pressure

regimes based on input information provided on well 9.

The design for the XHP / XXHP integration is outside the current scope of work,

and will be implemented if and when the time comes

Crude processing will be segregated between the two trains as follows: -

higher pressure wells to be processed via the 2-stage separation (HP + LP),


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while the lower pressure wells will be processes through the one-stage

separation (LP).

Piping will be configured for flexibility to flow any well through the HP train or

LP train, as well as connectivity between the two trains.

The test separator, though will be installed in Train-2, will serve both trains. In

addition valving will be designed for flexibility to use the test separator as bulk

HP separator for Train-1.

Figure 1: Train 1 Flow Scheme


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Figure 2: Train 1 & 2 Flow Scheme

Both trains will enable produced oil to be routed through three cascade tanks each

of size 1,000 barrels before export through the LACT, or transfer to storage tanks

with cumulative capacity of 100,000 barrels for temporary if and when the need

arises.

A heater currently available has been converted to function as an LP separator.

All separation stages are placed as three phase separators, enabling water to be

removed from each stage as well as the gas boots, for processing in a TPI facility.

The TPI produced water is anticipated to meet DPR specifications of 10 ppm oil in


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water before disposal in a water injection well, whose design is intended to be

covered in a separate contract.

In addition, given the fact that the produced water is planned to be disposed by

injecting it into well(s), the need for treating to the high quality of 10 ppm needs

to be discussed and confirmed with the DPR, to avoid the cost of achieving

specifications that are unnecessary.

The produced gas will be used as fuel gas for the CPF gas engine generator, with

the excess available for external utilization.

For the excess gas handling, five potential options have been compiled for

evaluation, i.e.:

1. LPG recovery + power generated with surplus methane stream,

2. Power generated with whole stream of gas for export to National Grid,

3. CNG bottles manufactured by third parties,

4. Produced gas sold at CPF fence,

5. Gas injected into Umusadege reservoirs. This last option is only included only

for completeness of the records and not considered to be a serious option, as

DPR will not approve gas disposal by re-injection.

Any or all of the options will be examined for potential uptake by third party off-

takes or MWOG/partners, to enable a specific recommendation. This review will be

carried out as part of the detailed engineering scope and will be reported

separately.

5.2 Design & Operat ing Philosophy

The CPF will be normally not manned


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It should be able to operate safely under this mode, as well as being able to be

shut down safely remotely from a local PLC based control room. The PLC will beequipped with HMI, and SCADA capability.

Its start-up has to be locally from the field, or remotely from the control room only

with local permissives from the field.

TThhee operating modes outlined in this philosophy shall be developed during

detailed engineering.

5.2.1 The I nlet and I ntermediate / ESD Valves Manifold

The inlet manifold will operate in bulk and test mode and both modes can be

operated concurrently. The bulk mode will be the normal production mode in

which wells with the same pressure regime are switched to the same header

where they are commingled. From the header, they flow into a targeted (HP

or LP) or in some cases test separator (when the test is being operated in

bulk mode).

The test mode will be the mode in which a well is put under test to determine

its production capacity and basic composition such as GOR and BS & W. In

this mode, the well under test will be switched to the test headers from

where it flows into the test separator.

The inlet headers are process lines between the ligaments and the inlet

separators. Each well and also each inlet header will have individual

shutdown valves, which is used primarily to isolate the ligaments (wells and

flow lines) from the inlet separators during an operational or emergency

shutdown. On each bypass line is a 2 inch manual globe valve. The bypass

line is used primarily during start-up to gradually pressurize the flow station

and the instrument fuel gas header by the use of the 2 inch globe valve.

The flow station is first pressurized before each header ESD valve can be

opened for the following reasons:-

Enable the lighting of the flare.

Prevent a pressure shock (hammer effect) on the facility.

Prevent possible damage of the header ESD valves seat because of high

differential pressure across them.


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Allow a reset of the pneumatic safeguarding panel.

Each header ESD valve will consist of a ball valve with a spring return

actuator. A pneumatic pilot operated three-way valve operates the actuator.

The pilot signal on the three-way valve will be controlled by a pneumatic

relay based safeguarding system.

Pressure gauges are installed on each header to measure the inlet pressure.

5.2.2 The Test Separator

The test separator operates as 3-phase. It will have two operating modes

(test and bulk).

When in test mode, any of the wells under test is routed to the test

separator.

In the bulk mode, it will be used for normal production and operates like any

of the other two separators (LP & HP). In this mode, all producing wells

within the same pressure regimes are switched manually through their

individual ligament valves into the test header. From the test header they

flow into the test separator.

5.2.3 The HP Separator

The HP Separator will operate between 220 to 240 psig. All producing wells


individual ligament valves into the HP header. From the HP header they flow

into the HP separator.

In the separator, liquid and gas are separated. The flashed gas exits though

the gas outlet, while the oil and water stream is routed to the LP separator.

5.2.4 The LP Separator

The LP separator will operate between 30 to 40 psig. All producing wells


individual ligament valves into the LP header. From the LP header they flow

into the LP separator. The oil, water and gas are separated. The flashed

gas exits though the gas outlet, while the oil is routed to the gas boot / surge

vessel.


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The water is routed to the water treatment facility.

5.2.5 The Gas Boot

The gas boot is a three phase degassing / stabilizing unit, also enabling

additional refinement of de-oiled water to be routed to the water treatment

facility for further processing.

Final separation of gas and liquid occurs in both cases, the flash gas exits

through an outlet line and flows into the flare knock-out vessel. The liquid

(oil) exits through the outlet line where it flows by gravity into the cascade

tanks, from where it is pumped to the LACT.

Details of pump control will be developed with vendor data during detailed

engineering. Pump discharge pressure floats on the pipeline operation

pressure, which is a function of the liquid export flow rate and the other

users of the pipeline system.

5.3 The Crude Export Pum ps

Centrifugal pumps, with variable speed drive mechanism have been procured to

be used. These pumps are already on the site and will be evaluated to assure

they fit the required duty.

5.4 The Closed Drain System

All vessel drains are routed to the closed drain sump tank. Recovered oil is

pumped back to the crude oil export system while removed water is routed for

treatment. Open and closed drainage systems shall be included. Open drains will

channel rain water and non-hazardous fluids to the open drain pit via the open

drain header. Closed drains handling oil contaminated and hazardous liquids are

routed to the closed drain tank via the closed drain header.

5.5 Gas Handling

Associated gas will be routed to an AG solution facility to enable value addition for

sales. Options that may be considered for the AG solution facility include

processing for direct sales, or for LPG extraction and power generation, for own

use or for sale.


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A fuel gas system shall be provided for supply of fuel gas to the gas turbines. The

fuel gas system shall be sized to supply all future equipment required for theDesign Case. Supply pressure will be based on selected gas engine generator.

A purge gas system shall be provided for purging and supply to flare pilots and

ignition system. Critical control valves shall be spared to ensure availability of

supply.

5.6 Flare System

In line with DPR regulations, routine process flaring will not be permitted.

However a full facility flare will be included for use under emergency conditions.The existing flare will be evaluated to determine capacity for the forecast

production. A flare header / flare system will be provided to collect and safely

dispose of produced hydrocarbon gases. As a minimum, the system will consist of

flare headers, a flare knockout drum, and a continuously ignited pilot flare. In

addition, the system will be designed to safely and continuously flare the produced

gas capacity of the CPF and to depressurize all of the production flow lines in the

shortest possible practicable time. Discharges from pressure relief valves and

other hydrocarbon streams as required by the CPF Facility Specifications will be

routed to the flare system. The flare system will be equipped with meters to

measure flare volumes to within an accuracy of 2%.

5.7 Water Treatment

Produced water will be routed to a TPI (Tilted Plate Interceptor) Facility ahead of

disposal. The ultimate disposal route will be via re-injection into an aquifer.

The TPI produced water shall be made to meet DPR specifications of 10 ppm oil in

water before disposal by injection into an aquifer. Before the installation of the

water injection plant, water will be disposed off in the existing pond.

The design of the injection facility is outside the scope of this Basis for Design,

and will be covered in a separate contract.

5.8 Storage Tanks

The tables below summarise the tanks that will be installed:


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Table 1 : Crude Oil Tanks

Tank Designation Capacit y

Processed (dead) Crude 2 x 14,500 barrels

Processed (dead) Crude 2 x 35,000 barrels (Anticipated)

Crude Settlement 3 x 1,000 bbl Cascade Tanks

Table 2: Other Tanks

Tank Designat ion Capacit y

Produced Water 1,000 bbl as part of re-injection phase.

Firewater 5,000 barrels

Chemical (one per chemical type) TBD

Diesel 500 barrels (10 days endurance)

The crude oil tanks will be fitted with a stripping system to permit removal of

water that has settled out of the crude oil. The storage system will be capable of

receiving stabilized crude from the production facilities. The offloading system will

be capable of discharging at a rate and pressure such that it can flow into the GGF.Fiscal metering of the exported crude will be based upon the use of the existing

LACT system at GGF since the existing facility is in-place and is reliable. The tank

shall be fitted with local flow meters (or gauge).

The facility and associated systems will be designed to remain on site for entire

design life and with minimal maintenance and repair (e.g., no major steel, coating,

and piping or equipment renewals) which might result in interruption of production

operations. This will be achieved mainly from material selection.

There will an automated and manual level control system on each tank. Motorised

valves will be interlocked to allow one tank filling at a time. Two 14,500 barrel

crude oil tanks shall be used for storage and settlement. Additional two 35,000

barrels capacity are anticipated for future expansion.

The storage tank inlet motorized valves are controlled by the Level Switch High on

the storage tank to prevent overfilling of the crude oil. The motorized valves are

also at interlock with each other with the philosophy that only one tank can be


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filled at a time. The closure of one motorized valve gives an advent of the opening

of the next motorized valve on priority. The Level Switch Low on the tank controlthe motorized valve on the outlet section of the tank in safeguarding the operation

of the pumps.

The final logic of the tank filling operation shall be done by the detailed

engineering contractor which shall be implemented by the Vendor of the

Programmable Logic Controller.

5.9 Diesel Storage and Dispensing

Diesel is required for the emergency power supply system. Specific care will bemade to ensure that the supplied quality meets equipment requirements and that

adulterated products are not supplied.

5.10 Service & Fresh Wat er System

Potable water system will be included for use in engine cooling system as well as

fire water storage. The borehole supply pump will be powered by electric motor.

5.11 Chemical I nj ect ion System

Chemical Injection points will be included where needed. Such chemicals as

corrosion and scale inhibitors are potentially required.

5.12 Pneumatic Control & Automation System

Dry instrument air will be provided to the process facilities. CMA will determine

the required pressure and capacity of the instrument air and provide 2 or 1 electric

motor driven air compressors. CMA shall consider the cooling demands of

generator when assessing the instrument air demand. An air filtration (leaning)regulator system will be provided.

5.13 Eart hing System

An earth ring main will be designed to provide earthing source for all the facilities


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5.14 Cathodic Protect ion System

Cathodic protection will be provided for buried flowlines & delivery line and also

for vessels and storage tanks.


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6.0 MWOG PROCURED EQUI PMENT

The following equipment items have been procured and, as much as is feasible, will

be included in the design.

Table 1 : Pre-Ordered Equipment I tem s

Tag Dimensions MAWP Design

Temperature

Test Separator 1.1m by 3.1m 655 psig 200OF

L.P Separator 8ft OD x 40 ft s/s 50 psig 140F

H.P Separator 5ft OD x 20ft s/s 740 psig 200F

Gas Boot 1 m x 14m 20 psig 140F

Test Manifold 6 in header 1,400 psig 120OF

Production

Manifold

8 in header 1,400 psig 120OF

Storage Tanks 65ft dia x 24 ft 5 psig Ambient

Pump 67.6 HP

(Rating)

187 psi

(Differential)

Technical information on these items of equipment are available and will be applied

in the design checks.


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7.0 CI VI L WORKSThe scope of civil works covers the following aspects:

1. Determine the facility area including fence lines, roads and footprints of facility

components.

This shall be based on survey maps and as-built drawings provided by MWOG,

which shall be verified during site visits.

2.Appraise existing drainage lines and reconcile with new routing required.

3. The topography of the new CPF area shall be reviewed to ascertain the extent of

cut and fill that will be required.

4. Output from topography review shall form basis for recommending heights of

supporting structures; e.g. pipe supports, tanks, vessels and gas boots

foundations, steel columns, and walkways.

5. Detailed design of all applicable foundations including oil tank foundations,

control room, buildings, skids, bundwalls .

Results of the borehole sampling will be reflected in the design work and shall

form the basis of foundation design.

6. Detailed instructions on materials to be used, method of application, expected

results or outputs and technical development for constructing the works stated in

item 5 shall be adequately provided.

7. Recommend any other structural component required for a resilient structure;

e.g. platforms, walkways etc.

8. The Construction Scope of Work. These items relating to the execution and

completion of construction works shall be quantified and priced as input to the

project cost estimate. It is expected that any modifications and change orders

from the client shall be incorporated as civil works progress, if agreed and

accepted by parties.


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8.0 I NSTRUMENTATI ON

Overall control of the liquid production system is through the Process Automation

System (PAS). This extends over the pump stations, tank farm and the CPF. The

facility will be normally not manned. Normal monitoring of plant performance,

verification of set-points and starting/stopping of equipment, etc, will take place

from the Control Centre located at base.

TThhee Flowstation oil production system will be maintained in stable operation by a

number of factors, including manually set flowlines choke valves that will maintain

the overall station production

8.1 Test Separator I nstrum entati on

The test separator instrumentation will be designed to provide a means to initiate

and carry out well testing locally, and in line with API 14C will have the following

features:

Back Pressure Control

High Pressure Safeguarding

Level Control

Low & High Level Safeguarding

Level & Pressure Measurement

Gas Outlet Measurement

Liquid Outlet Measurements

Temperature Measurement

8.1.1 Back Pressure Cont rol

The test separator will be designed to operate at either LP or HP separator

pressure, and in test or bulk mode. Hence, it will not have a dedicated back

pressure control system, but will share with that of the LP separator (when in

LP mode) or the HP separator (when in HP mode). This sharing shall be

implemented by connecting the test separator gas outlet line to both the LP

or HP header where their back pressure control systems are installed.

The back pressure control will comprise a pneumatic pressure controller and

pressure control valve. The pressure controller measures the process


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pressure and produces a standard pneumatic output signal, which drives a

back pressure control valve.

8.1.2 Level Control

The level control will comprise the following:

a. Displacer type controller / transmitter

b. Level control valve

c. Test / Bulk mode selector switch

d. Level Measurement

Displacer Type Contr oller / Transmit ter

The displacer type pneumatic transmitter receives change in fluid level

through change in buoyant force exerted by the fluid on the sensor

displacer, and consequently produces a standard pneumatic output signal

that drives the control valve.

Test / Bulk Mode Selector Sw it ch

The liquid outlets will be divided into two, - a 2 and a 4 line, with a

level control valve installed in each line, with both lines recombined into a

4 line downstream of the control valves. The required liquid outlet line(2 for test mode, and 4 for bulk mode) is selected by manually opening

of the ball valves upstream and downstream of the level control valve,

while the control valve selection is by use of a manual pneumatic switch.

The pneumatic selector switch connects the standard output signal of the

level transmitter / controller to the selected valve.

The liquid outlet will be divided into oil & water to achieve metering

separately.

8.1.3 Level Measurement

The only level indication will be that directly on the vessel by the use of sight

glass.

There will be no direct level measurement and display on the test separator

except level measurement by the displacer type transmitter / controller used


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in the level control loop. The level control loop will be primarily field located

with no form of indication.

8.1.4 Low and High Level Safeguarding

The test separator will be equipped with a duplex type transmitter and

controller that will provide dual function of level control and high / low level

safeguarding.

The safeguarding instrumentation will consist of high and low level displacer

type pneumatic switches, connected to a pneumatic relay panel used for

plant safeguarding. The safeguarding logic is implemented in the relay panel

such that for a high level in bulk mode, all the inlet valves and the liquid

outlet valve are closed. In the test mode, the inlet valve applicable will be

that of the well on test. In the event of low level, the liquid outlet valve will

be forced down.

Other safeguarding functions will be conducted in accordance with the

flowstations cause and effects diagrams

8.1.5 High Pressure Safeguarding

The test separator high pressure safeguarding will comprise a high pressure

pneumatic switch that will initiate the shutdown. When the pressure switch

senses a high pressure, it sends a signal to the pneumatic safeguarding relay

panel, where the shutdown logic is implemented in accordance with the

cause & effects diagram.

The objective is to close the inlet shutdown valve to the separator so as to

prevent further entry of hydrocarbon.

8.1.6 Pressure Measurement

All pressure measurement will be by pressure gauges only.

8.1.7 Gas Out let Flow Measurem ent

A senior Daniel orifice or ultrasonic meter will be installed to measure all

outlet gas rates.


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8.1.8 Liquid Out let Flow Measurem ent

Oil & water will be metered separately. The oil will be measured usingturbine meters for accuracy that will be in line with DPR requirement.

8.1.9 Temperature Measurement

All temperature measurements will be by temperature gauges only.

8.2 HP Separator I nstrum entati on

The instrumentation and safeguarding functions on the HP separator will be

similar to the test separator, except that there will be no liquid measurement, -

only gas.

Similar to the test separator, it will have a duplex type level instrument, which will

provide both level control and high high level safeguarding function.

8.3 LP Separator I nstrum entat ion

Also, the instrumentation and safeguarding functions on the HP separator will be

similar to the test separator, except that there will be no liquid measurement, -

only gas.

Similar to the test separator, it will have a duplex type level instrument, which will

provide both level control and high high level safeguarding function.

8.4 Crude Oil Export Pump I nstrum entati on

The crude oil pump will have a pneumatic governor, which will be used to vary the

speed of the pump gas engine driver as part of the level control system of the

surge vessel. When the level in the surge vessel goes high, the speeds of the

pumps are set to maximum by the surge vessel controller. At low level, the

pumps are set to minimum speed. In the event that the level drops further, the

recirculation valve begins to open so as to recycle the liquid to the surge vessel.

Pressure gauges will be installed on the pump suction and discharge lines.


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8.5 Flare Knockout Vessel I nstrum entati on

The knockout vessel will have four level switches. Three of the switches will be

electric, while the fourth will be pneumatic two of the electric switches will be used

for level control, while the third will be used to shutdown the pump on low low

level detection. The pneumatic switch will be connected to the pneumatic relay

panel for shutdown on high high level in the flare knockout vessel.

The level control system for the pump will consist of a stand-alone electric relay

logic control panel.


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9.0 EQUI PMENT LAYOUT

The facility equipment shall be laid out to fit within the CPF land boundary, bearing

in mind the limitations created by the position of the new storage tanks under

construction and right of way.

9.1 AREA CLASSI FI CATI ON

Adequate safe distances for all equipment will be considered in accordance with

area classification requirements that will be firmed up at detail design stage. The

layout shows access roads with provision for drainage lines. Inter-connecting

piping from the process area to storage tanks will be buried at road-crossings; i.e.

piping at other areas will be above ground.

The allocation of functional spaces in the layout was based on the following

parameters:

Flare zone: North-West, due to prevailing wind directions

Utility area: North, in the proximity of the administration building, considered

as a safe area

Tank farm: South-West, in the largest free space to accommodate tanks

Process area: South-East, in near proximity to in-coming lines and inlet

manifolds

Fencing: Perimeter of property, and seal-off of restricted areas.

Accesses: Gates to control service accesses into restricted areas

A conceptual layout is included as Appendix to this document.

9.2 LAYOUT CONSI DERATI ONS

1.All equipment will be placed optimally, satisfying the optimum orientation for all

processes, utility and instrument equipment items.

2. The cost of construction will be minimized, e.g. by adopting a layout that gives

the shortest run of connecting piping between equipment.

3. Sufficient working space and headroom will be provided to allow easy access to

equipment.


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4. Equipment such as pumps that require dismantling for maintenance will be

placed under rain/sun cover.5. Equipment will be located so that it can be conveniently tied in with any future

expansion of the process, e.g. future gas off-take.

6.Additional space will be left along the pipe racks to accommodate future piping

needs.

7. The gas flare that is included for emergency use will be located as far as

possible from the process vessels, in line with safe area classification

requirements.

8. The EPF will be tied-in to the new storage tanks via temporary transfer lines that

would be disconnected before commissioning the CPF.

9. The general plant arrangement and orientation will be consistent with the

prevailing atmospheric and site conditions such as wind direction as well as

hazardous area requirements.

10.Adequate allowance will be left for drainage and fire fighting facilities. Access

ways will be provided within the facility for access to items that require removal

for off-site repair.


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10.0 FI RE PROTECTI ON

10.1 Fire Water

Fire water storage tank shall be installed with a capacity suitable to meet

firefighting needs for a minimum period of four hours, as determined by the

period for arrival of firefighting support equipment from nearby locations.

A diesel fuel pump and electrical Jockey pump are included. The critical areas shall

be covered with a pressurized ring main that feeds a series of hydrants each with

hoses located at strategic positions in the CPF.

10.2 Fire and Gas Detection System

A Fire and Gas Detection System shall consist of three parts:

a) Detection

b) Control Logic

c)Active Protection

Fire and Gas Detection devices and Manual Call Points shall be provided.

The System shall provide voting capability (2oo3 and where there is failure in one

of the applicable detectors, it recourses to 1oo2) where multiple detectors have

been installed to minimize nuisance shutdowns. For a large area with multiple

zones (without a barrier), cross zone voting within adjacent zones may be used.

Process shutdown actions initiated by the Fire and Gas Detection System shall be

executed via interlocks to the ESD/PSD systems. Other actions (e.g., release of

fire suppressant systems, fire water pump starts, etc.) may be executed directly

from the F&G System.

The Fire and Gas Detection System shall be designed so that it can be functionally

tested and individual detectors can be calibrated without affecting CPF processes

and equipment operation.

The system configuration for F&G Systems shall comprise centrally located logic

solvers in the control room and either centrally or remotely located I/O systems.


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Further details on the proposed fire protection system are contained in a separate

document in the Appendix.

11.0 ELECTRI CAL DESI GN BASI S

Power will be generated using gas engine generators fired by the produced gas. A

diesel engine set will be retained for emergency power. Furthermore, solar power

will also be considered as that will have prime use for critical installation such as the

CP system or the telemetry system for communications between the wells and the

CPF.

11.1 Pow er Generati on

Power will be generated on site with two adequately sized Gas engine generator

operated in an N+1 sparing philosophy and sized to cater for 100% total plant

peak load, covering the CPF, GGF, Campsite, and Satellites. The required for

future facilities, e.g. water injection plant and AG solution facility will be addressed

separately, when the time comes.

In addition to the gas engine generators, a diesel engine generator shall be

provided for emergency service and cold start of the CPF. The emergencygenerator shall be adequately sized to supply power for vital and agreed essential

services and to start and run a minimum of one oil export pump.

The vital services refer to those services which, when they fail in operation or

when called upon, can cause an unsafe condition of the process and / or electrical

installation, jeopardize life, or cause major damage to the installation; while the

essential services refer to those that when they fail in operation or when called

upon, will affect the continuity, quality or quantity of the product.

The emergency and critical loads will be defined and agreed, and reflected in the

load list. The load list will form the basis for load segregation, as well as sizing

main equipment such as:

1. Main gas engine generators

2. Emergency diesel generators

3. HV switchboards

4. LV switchboards

5. Protective circuit breakers etc.


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11.2 UPS

AC and DC uninterruptible power supply shall be provided complete with battery

banks for the vital loads at the CPF and outlying flowstations. The uninterruptible

power supplies shall use Nickel Cadmium batteries. Each power supply shall be

equipped with two 100% duty chargers capable of both charging batteries and

supporting the maximum load. All batteries shall be 2 x 100% sized, and capable

of supporting their for 30 minutes.

11.3 Pow er Transmission & Dist ribut ion

Power transmission will not be required because the low voltage distribution can

be used.

Main power distribution within the facility will be at 415/220 volt, 50Hz, TPN

(Triple Phase and Neutral) in accordance with local power authority (PHCN)

standard distribution. Power will be distributed to electrical equipment by

adequately sized cables via cable trays or trench.

Adequate protections will be provided to electrical equipment and personnel on

site through a well-designed earthing network that will tie into the existing

earthing system. Other deliverables will be generated in line with the approved

MDR.


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12.0 HSE/ SD REQUI REMENTSHSE issues are those which result from the interaction of the proposed facility with

the environment and safety related issues that need to be addressed as part of

Human Factors Engineering in design and also, during project implementation in the

Umusadege field. CMAs CASHES Plan has been consistently applied in our work

execution, enabling safe working practices and minimum impact on the environment

or damage to human life. Documents created as part of the design activities will

reflect these perspectives.

12.1 Safety Considerati ons

The general approach adopted during design development and the requirement

for further design stages will identify and eliminate hazards as an integral part of

the design process.

12.2 Environmental Considerations

The PMT and HSE regulatory teams will work closely together to assure

environmental issues are considered in the design process, following the

applicable regulations and guidelines listed in section 15.2. An Environmental

Impact Assessment study has been conducted on the facility and all its

recommendations shall be implemented. All new facilities will be installed under

the existing MWOG operating permit.

12.3 Securi t y Considerations

CMA / MWOG are committed to a dynamic, visible security program, which

addresses the threats in the major following areas:

Protection of assets

Office and Residential Security

Personnel Transportation/Travel

Communication/Information Security


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12.4 Risk Assessment and Managem ent

The CPF project has a number of inherent risks and uncertainties. These will range

from sub-surface uncertainties that may affect the production forecast, to

technical and commercial risks, but also include a number of socio-political risks,

especially during the project execution phase at Umusadege. A risk register has

been compiled with 80 items listed. Mitigation factors will be developed and

implemented.

This project will follow standard guidelines for Engineering Managed Modifications

(EMM) as part of the process for managing any associated risk. A Design Risk

Assessment shall be conducted before the detailed design is concluded.

As part of risk assessment, a specific perspective is the need to carry out a

SIMOPS exercise during detailed design. Consideration will be given to

simultaneous operation of the EPF in parallel with the installation of the CPF. A

SIMOPS Study will be carried out to assess the risks and develop the right

approach for risk mitigation during the installation CPF stage.


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13.0 ASSET MANAGEMENT

13.1 Operat ing Philosophies

Operating philosophy envisages that the facility is not normally manned.

Maintenance will aim at preventive maintenance through a computerized

management system. Other features include the following:

a. Field production will continue un-hindered during the installation of the

expanded facility. Aspects include placement and tie-in of processing vessels

and piping works in tandem with systems in operation.

b. Considering that the Umusadege is a marginal field, sparing of equipment

items will be minimized. Also for this reason, high integrity systems will be

included for process safety control. Moderate level of automation for process

control is desired, with process control equipment placed in a purpose-built

office.

c. The facility will operate 365 days a year with shut-down only in the event of

an emergency procedure or for statutory inspections on relief systems and

vessel internals.

13.2 Asset Reference Plan

The ARP that will be created by others at the end of detailed design will aim to

utilize the Operations Readiness and Assurance report to:

Define the boundaries of the asset.

Optimize asset planning and operations with respect to previously completed

sub-surface studies, facilities design and equipment selection and

specifications Integrate business process strategies,

All these actions are aimed at optimizing value of the asset for benefit of MWOG,

its partners, and other stakeholders.


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14.0 MANAGEMENT OF CHANGE & QUALI TY

14.1 Design Change

All changes that interface with MWOG operations will be captured, using the CMA

Management of Change (MOC) process. This would ensure that potential changes

are properly assessed, approved and documented so that risks remain at

acceptable levels while project objectives are met. All necessary approvals will be

secured before any deviation / change is carried out.

14.2 Qualit y Assurance and Cont rol Requirem ents

CMAs Quality Assurance process will be applied through the concept of

competence in work disciplines and the attitude and commitment that mandates

all staff to follow best practices.


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15.0 STATUTORY AND REGULATORY COMPLI ANCE

This design shall follow the guidelines and standards set by Midwestern Oil and Gas,

Department of Petroleum Resources (DPR) and International Codes of Practice as

applicable in the oil industry. Safety standards shall follow the regulations from the

Occupational Safety and Health Act (OSHA) and other Nigerian regulations.

15.1 Nigerian Cont ent

The work shall be done in accordance with the Nigerian Content Development

Regulation passed by the National Assembly in 2010. Nigerian contractors will

fabricate and install, in most cases using Nigerian personnel.

15.2 Regulatory Considerati ons

The Umusadege project will be developed in compliance with all applicable

Nigerian laws and regulations. The project will also be guided by Scope of work

specifications and International Codes and standards referenced therein. The

Nigerian Department of Petroleum Resources (DPR) is the responsible government

entity for regulating petroleum development in Nigeria. Other pertinent

government agencies involved directly or indirectly, in engineering, procurement,construction, and installation activities in oil and gas development include:

Federal Ministry of Environment (FME)

Nigerian National Petroleum Corporation (NNPC)

Nigerian Petroleum Investment Management Services (NAPIMS)

Applicable Regulations and Guidelines related to oil and gas exploration and

exploitation activities include but are not limited to the following:

MWOG joint Operating Agreement

Petroleum (Drilling & Production) Act 1969

Mineral Oils (Safety) Regulations 1997

Guidelines and Procedures for Construction, Operation and Maintenance of Oil

and Gas Pipelines and Ancillary Facilities issued by DPR

Environmental Guidelines and Standards issued by DPR, 2002


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Page 54

The design shall reference industry and international codes and standards. The

engineering work carried out in this project complies with applicable government

regulations, industry standards including, but not limited to those listed in

Appendix 1, and are deemed most applicable to the scope of this project. In all

cases the latest edition of the codes shall be used except otherwise stated for

older/existing components. CMA will operate within the tenets of Companys

standards. Drawings for all new facilities shall comply with all applicable

international standard.

Specifically;

MWOG Project scope of work and other documents from MWOG

MWOG Design instructions from MWOG staff

MWOG Information gathered during facilities site visit

Nigeria All applicable Nigerian Codes and Standards

Unfired PressureVessels

ASME Boiler & Pressure Vessel Code (Section II, SectionSection VIII, Div. 1 or Div. 2, and Section IX)

Process Facilities All applicable API RP (e.g. API RP 14E, 12J etc).

Relief Valves ASME Section VIII, API 520, 521, 526, 527

Piping ANSI B31.3, Code for Chemical Plant and Petroleum Refin

Pressure Piping

ANSI/ASME B16.5 Steel Pipe Flanges and Flanged Fittings

ANSI/ASME B16.9 Wrought Steel Butt welding Fittings

ANSI/ASME

B16.11

Steel Socket Weld Fittings

ANSI/ASME

B16.20

Metallic Gaskets for Pipe Flanges - Ring Joint, Spiral Wou

and Jacketed

ANSI/ASME Valves - Flanged, Threaded and Weld End


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B16.34

API 598 Valve Inspection and Testing

API 600 Steel Gate Valves - Flanged and Butt welding Ends

API 602 Compact Steel Gate Valves

API 650 Welded Tanks

API 12B Bolted Tanks

ASME 8 Boiler and Pressure Vessel Code

Electrical All apparatus shall bear the CSA label

All installations shall be in accordance with the CSA Natio

Electrical Code, latest edition.

API RP 500 Recommended Practice for Classification of Locations f

Electrical Installation at Petroleum Facilities

NFPA National Fire Protection Association

NFPA 10 Fire Extinguishers

NFPA 12 CO2 Extinguishing System

NFPA 13 Sprinkler System

NFPA 14 H2O Spray fixed system

NFPA 14 Standpipe and Hose system

NFPA 20 Fire Pumps

Other NFPA are; 16, 15, 22, 72, 30, 54 and 101


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16.0 APPENDI CES

BFD Matr ix

BFD Matrix.pdf

Product ion Forecast / Well Fluid Character isti cs and Propert ies

Production Forecast& Profile Picture.xls

Fire and Gas Detection

Fire and GasDetection System.do

Proposed General Layout

Proposed GeneralLayout.pdf

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