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West White Rose Project Functional Specification Electrical Submersible Pumps (ESP)

Technical Document

Project: Location:

West White Rose Project Atlantic Region

Document Title: Total Pages

Functional Specification for ESP EOI 33

Document No.: Geographic Location - if required: Revision No.:

St. John’s, NL EOI

Comments:

EOI Revision:

Confidential Data Removed and some contractual phrasing revised.

Company Stamp Engineering Stamp

EOI Jan 24, 2017

Confidential Data

Removed

E1 Nov 7th,

2017 Issued for

Use

Jennifer Fallon

Dan Schoonhoven

John Franklin Chris Rideout Andrew Montes

Lisa Wishart Craig Pardy Anthony Purpich

Rev Date Reason For

Issue Prepared Prepared Prepared Approved Approved Approved Approved Approved

CONFIDENTIALITY NOTE: All rights reserved. No part of this document may be reproduced or transmitted in any form or by any means without the written permission of Husky Oil Operations Limited.


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Table of Contents 1.0 INTRODUCTION ................................................................................................................4

1.1 WWRP PROJECT OVERVIEW ...................................................................................................... 4 1.2 REQUEST FOR INFORMATION & EOI ............................................................................................. 4

2.0 PRINCIPAL REQUIREMENTS ..........................................................................................5

2.1 ALTERNATIVELY DEPLOYED ESPS ............................................................................................... 5 2.2 CONTRACTUAL DETAILS .............................................................................................................. 5

3.0 SUBSURFACE DATA .......................................................................................................6

3.1 IPM MODEL OUTPUTS: ............................................................................................................... 6 3.2 PRESSURE, VOLUME, TEMPERATURE DATA (PVT) ........................................................................ 7 3.3 SETTING DEPTH VARIATIONS ....................................................................................................... 7 3.4 SOLIDS AND GAS HANDLING ........................................................................................................ 8 3.5 VENDOR DELIVERABLES .............................................................................................................. 8

4.0 VARIABLE FREQUENCY DRIVES ...................................................................................9

4.1 VFD SCOPE ............................................................................................................................... 9 4.2 FOOTPRINT AVAILABILITY............................................................................................................. 9 4.3 INSTALLATION PLAN .................................................................................................................. 10 4.4 VFD HOUSING ROOM VENTILATION ........................................................................................... 10 4.5 GENERAL VFD REQUIREMENTS ................................................................................................. 11 4.6 MEDIUM VOLTAGE DRIVE SPECIFICATIONS ................................................................................. 15 4.7 VENDOR DELIVERABLES ............................................................................................................ 16

5.0 WELL ARCHITECTURE ..................................................................................................16

5.1 WELL SCHEMATICS ................................................................................................................... 16 5.2 PRESSURE RATING ................................................................................................................... 18 5.3 CASING CONSTRAINTS AND ANTICIPATED TUBING ....................................................................... 19 5.4 BARRIER PHILOSOPHY .............................................................................................................. 19 5.5 REQUIRED COMPLETION FUNCTIONALITY .................................................................................... 19 5.6 CONTROLS PASSAGE ................................................................................................................ 20 5.7 OTHER SPECIFICATIONS ............................................................................................................ 21 5.8 WELLHEAD DETAILS .................................................................................................................. 22 5.9 VENDOR DELIVERABLES ............................................................................................................ 22

6.0 MECHANICAL HANDLING CONSTRAINTS ..................................................................23

6.1 INTERVENTION CAPABILITIES ..................................................................................................... 23 6.2 DECK WEIGHT LIMITATIONS ....................................................................................................... 26 6.3 CRANE LIMITATIONS .................................................................................................................. 26 6.4 HANDLING HEIGHTS .................................................................................................................. 27 6.5 CABLE AND SPOOLER CONSTRAINTS .......................................................................................... 30 6.6 SIMOPS ................................................................................................................................. 31 6.7 VENDOR DELIVERABLES ............................................................................................................ 31

7.0 INSTALLATION AND MAINTENANCE ..........................................................................31

7.1 REQUIREMENTS ........................................................................................................................ 31 7.2 VENDOR RFI DELIVERABLES ..................................................................................................... 31

8.0 RELIABILITY & OPERABILITY ......................................................................................32

8.1 VENDOR RFI DELIVERABLES ..................................................................................................... 32

APPENDIX A – WELL SCHEMATICS ........................................................................................33


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List of Appendices

Appendix A - Conceptual Well Schematics


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1.0 Introduction

1.1 WWRP Project Overview 1. Approximately 350 km east of the island of Newfoundland on the eastern edge of the Jeanne d’Arc

Basin, and approximately 50 km from both the Terra Nova and Hibernia fields. Water depth is approximately 120 meters.

2. The WWRP will consist of a concrete gravity structure (CGS) with topsides consisting of drilling facilities, wellheads and support services such as accommodations for 120 to 130 persons, utilities, a flare boom and a helideck.

3. There will be 20 well slots with each slot planned to have two wells each (total well count of 40 wells). Of the planned production wells, 8 are planned to utilize ESPs. The balance of the production wells are planned to be gas-lifted.

4. The primary function of the WWRP is drilling. There will be no oil storage in the CGS. Topsides will be equipped with a test separator. All well fluids will be transported via subsea flowlines to the SeaRose FPSO for processing, storage and offloading.

5. The platform topsides will consist of a drill deck with middle, cellar, and sub decks below. The majority of coiled tubing and coil tubing deployed ESP services will be conducted on the middle deck.

6. Water depths in the White Rose field range from approximately 115 m to 120 m. 7. The Grand Banks region has a harsh environment due to the presence of intense mid-latitude low-

pressure systems during fall and winter, tropical cyclones in late summer and fall, and sea ice and icebergs in spring.

8. There is a potential for superstructure icing to occur between November and May with the highest potential for freezing spray being in February due to colder temperatures and high wind and wave conditions.

9. Air temperatures in the region range from a minimum of –10°C to a maximum of 20°C. Winds in the area are primarily from the west in winter and southwest in summer, and have been recorded at speeds of up to 51 m/s (99 knots).

1.2 Request for Information & EOI Husky Energy is requesting that vendor(s) propose system solutions for the electrical submersible pump (ESP) system scope of work outlined within this West White Rose Project (WWRP) ESP Functional Specification. Vendors with responses submitted under the prior RFI will be automatically considered for invitation to bid based on their submitted information. No resubmission is required; but vendors are free to supplement or modify their prior submission if desired.

Figure 1: Wellhead Platform (WWRP) tied back to the existing SeaRose FPSO


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2.0 Principal Requirements

2.1 Alternatively Deployed ESPs In the interest of reducing well workovers and maintaining rig focus on new well delivery, ESP wells will utilize Alternatively Deployed ESPs. Consideration is open only to systems facilitating rigless pump and motor replacement via coil tubing, wireline or slickline. The core focus is maximizing production uptime (through robust ESP design, quick change-out capability, and simplified completion architecture to drive higher reliability). The ability to offer both coil tubing and wireline deployed systems would be considered advantageous. When invitations to bid are issued, Husky Energy may choose to consider only bids associated with a specific deployment technology.

2.2 Contractual Details

2.2.1 Contract Scope

ESP contract scope is to include the following:

All ESP system components, including: o High efficiency electrical submersible pumps o Associated BHA components o High efficiency electric submersible motors o Protectors o Downhole cable o Gas handling o Well Head penetrator o Downhole monitoring system

Variable Frequency Drives (VFDs) Ability for real-time artificial lift monitoring and optimization Surface power and control solutions Monitoring and maintenance support through the life of the project Responsible for root cause failure analysis

2.2.2 Support and Delivery

Requirements:

The ability to maintain, service and test ESP tools and equipment locally Provide flowchart or outline all potential sub-contractual arrangements, such as for VFDs or other

components Discuss/propose how all sub-contracts will be managed, particularly with respect to provision of field

and technical product support in the well design phase and for troubleshooting during either installation or product lifetime

Ability to meet the required delivery timeline: o EOIs: Q1/Q2 2018 o Contract Award: Q4 2018


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o All VFDs delivered Q1 2019 o Downhole designs finalized, tested (SIT) & proven: Q3 2020 o Delivery of equipment for 1st well Q3 2021

3.0 Subsurface Data The following section provides a subsurface overview of ESP simulation and associated production targets. The development plan includes 8-9 ESP wells. Data provided is based on a type well production and values are estimated based on forecasted simulation in IPM software. Integrated Production Modelling (IPM) is a Petroleum Experts modelling suite which allows engineers to construct and integrate realistic models that take the effects of interacting reservoirs, wells, networks and process facilities into account. IPM was used to model the West White Rose development and provide data for ESP selection. Trends provided were obtained from IPM using a coiled tubing deployed ESP as a base scenario. The base scenario utilizes an ESP as a means of artificial lift; set at 3000m measured depth (MD). A Prosper (vertical lift profile/inflow performance) model was based on 7” production tubing with 2 3/8” inner coil tubing string and a flow path in the annular space between the 7” tubing and 2 3/8” string. The use of other ESP deployment methods resulted in variations in subsequent data. Simulation results (production profiles, pressure and rate plots, etc.) have uncertainty that is not demonstrated in the provided type case. During the design phase these are to be used as a guideline with oil production being the target, considering there are uncertainties within several reservoir characteristics used in the outcomes provided. However, the proposed vendor designs are not limited to this well architecture.

Below, data is displayed from two type wells. These wells are representative of a higher and lower producing well relative to others in the development plan.

3.1 IPM Model Outputs: This section outlines the data provided using two type wells. Production profiles are based on a development scenario with first oil in 2022.

3.1.1 IPM Assumptions

8-9 ESP wells in development scenario Pumps are installed at initial production in this scenario, however, this is under evaluation ESPs have a power limitation of 1000 HP in IPM model, therefore pump and motor selection limit the

pump power and amperage IPM model takes the annual FPSO shutdown into account. The frequency and duration of the

temporary production shutdown is estimated and input into IPM, which affects subsequent model outputs.

One pump and one motor is used throughout the life of the well


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3.1.2 IPM Output Data Ranges

Data pertaining to liquid rate, water cut and productivity index (PI) can be found in the tables below for each type well. Well 1 represents a high production well, and Well 2 represents a low production well.

Well 1 Daily Liquid Rate Water Cut PI

m3/d % m³/day/kPa

1500 ‐ 2500 0 ‐ 95 0.07 ‐ 0.14 Table 1: Well 1 – Production Ranges

Well 2 Daily Liquid Rate Water Cut PI

m3/d % m³/day/kPa

500 ‐ 1000 0 ‐ 95 0.03 ‐ 0.04 Table 2: Well 2 – Production Ranges

3.2 Pressure, Volume, Temperature Data (PVT) Pressure, volume, temperature and additional data for West White Rose ESP wells are shown in the table below. Note that for the equations provided, temperature is in units of Kelvin and pressure is in units of kilopascals.

Fluid Properties Specific Gas Gravity: 0.67987 Specific Water Gravity: 1.029 - 1.0365 At 15.6°C (from water analysis) Bubble Point GOR: 115 m³/m³ Separator corrected Bubble Point Pressure: 27,960 kPa

PVT Data Temperature: 112.4°C Reservoir Pressure 31,500 kPa

Gas Impurities H2S: 0 % (mole) (PVT Sample) Designed to 200 ppm CO2: 2 % (mole) N2: 0 % (mole)

Other Data API: 29.6 API At ST (separator corrected)

Table 3: PVT Data

3.3 Setting Depth Variations IPM modelling was based on an assumption of 3000 m MD with a reservoir depth of approximately 3000-3100 m TVDss. This, however, was an assumption for a deterministic case and not a constraint to be honored by vendor.


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3.4 Solids and Gas Handling

3.4.1 Gas

Gas volume fraction is dependent on pump setting depth and is to be incorporated into the ESP gas handling strategy. There is a gas cap present in portions of the field; however, gas cap (free gas) is not present directly above the majority of the wells. Gas could potentially migrate to producers when drawdown occurs.

3.4.2 Solids

No sand production is predicted for open hole completion as the Ben Nevis Formation consists of very fine grained sandstones which are moderately cemented with primarily calcium carbonate cement and consequently are well lithified. The majority of debris produced to date (observed in separators) is from perforation clean up. Vendor must consider flowback of drill mud on well startup.

3.4.3 Scale Management

The WWR reservoir is associated with a scaling tendency. Scale buildups in wells in the West White Rose reservoir are expected to be made up of mostly CaCO3, with the potential for small volumes of FeCO3 and BaSO4. Scaling was reported (predicted) to be the most severe at the ESP intake and output. This is due to large pressure drop experienced by the fluid when entering the pump and the temperature increase of the fluid when leaving the pump.

3.5 Vendor Deliverables

1) Vendor to provide recommendations for pump/motor configurations for the life of each type well including:

a) Pump/motor used for each of the following discrete production scenarios: Initial production, water cut development and limiting GVF. There is uncertainty associated with PI. Vendor is to consider impacts of high and low

side PI cases. b) Recommended change out frequency due to MTTF/efficiency or changing production

conditions. Identify every recommended pump or motor change out based on the production curve of each well.

c) Production data per well including, but not limited to: Pump and motor selected Frequency Pressure:

o Inflow/outflow performance TDH o Pressure profile

Temperature profile Oil /gas/water rates Setting depth PI

2) Vendor to provide production modelling for each well and note modeling software applied


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3) Vendor to outline pump sizing philosophy during design phase, Husky modeling software availability and vendor modeling approach

4) Vendor to describe limiting factors for pump selection/sizing and outline production ranges that are expected per well with the proposed system

5) Vendor to provide pump and motor curves used in the analysis 6) Vendor to provide detailed pump specifications (impeller/diffuser specs/number of stages etc.) 7) Vendor to provide pump system(s) used per well and redundancy philosophy 8) Vendor to propose gas handling approach and associated equipment 9) Vendor to provide feedback based on the subsurface data provided, as the IPM model is used as a

production tool and has limitations for pump sizing and selection 10) Vendor to provide solids handling strategy considering solids flowback due to perforation debris, mud

flowback or reservoir solids (although not anticipated). Vendor must consider flowback of drill mud on well startup.

4.0 Variable Frequency Drives

4.1 VFD Scope VFDs are to be provided component of the ESP contract (may be sub-contracted), with the intent of driving a systems design approach by having the ESP vendor select the drive system best suited to optimize the performance and reliability of their ESP motor. Each VFD shall include the necessary transformer for phase-shifting and voltage step-down, and all necessary ancillary equipment required for protection, control, and communications. There should be an integrated sinewave filter at the output of each VFD to mitigate harmonic resonance at ESP systems. The proposed VFDs shall meet the detailed requirements specified in this section. The system design shall focus on maximizing ESP lifespan and operability/flexibility.

4.2 Footprint Availability The proposed footprint available per ESP-VFD is 4400mm x 1100mm x 2800mm W x D x H each as shown below. Figure shows the area available for the VFDs. It is planned to install some units during offshore operation, therefore, the vendor shall identify whether the drive can be broken down for shipping and the length of each unit. VFDs shall require no rear access and be suitable for back-back installation. Any clearance requirements shall be provided with the proposal. VFDs shall be designed for bottom entry for incoming and outgoing cable connections.


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(a) (b)

Figure 2: Area Available for VFD Installations in the Medium Voltage Electrical Building: (a) 72W-BD-1400 Level 1, (b) 72W-BD-1400 Level 2

Maximum allowable weight is 7140 kg per drive (per WH-WGP-TQ-HUS-40029), inclusive of any transformers and all accessories. Since weight and size minimization is of considerable importance, the Vendor shall attempt to reduce weight and space requirements wherever possible in detailed design.

4.3 Installation Plan It is currently anticipated that all VFDs will be installed in shipyard. VFDs are required in shipyard by April 1st, 2019 for installation.

4.4 VFD Housing Room Ventilation The VFD will be housed in an enclosed climate controlled building with a design temperature of +5 to 29 degrees Celsius. The vendor shall supply estimated airflow requirements and heat generation figures. The VFD shall be air cooled. It would be preferred that each VFD be provided with a redundant cooling fan, mounted integral to the VFD enclosure. The VFD shall include air-flow pressure switches and temperature detectors to monitor proper operation of the air cooling system, or equivalent protection. If a fan fails, the


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system shall generate an alarm. Provision shall be made, independent of the switchboard room air conditioning, to facilitate the removal of heat/exchange of air related to the cooling of the MV VFD assemblies. A space heater shall be provided for each VFD installation to prevent condensation build up. One space heater, complete with its own thermostat, shall be located in every cabinet of the VFD. All space heaters shall be wired in parallel, with one fused disconnect and power connection block supplied per VFD lineup. Space heaters shall be long life, low current density, 120 VAC, 60 Hertz, single-phase, and the 120VAC power for space heaters shall be supplied from an external source. Space heaters shall have guards to prevent personnel contact with hot surfaces.

4.5 General VFD Requirements The vendor shall ensure that all equipment proposed is not operating at either end of its extreme limits based on these requirements to allow future flexibility. The target design life of each VFD and all surface equipment is 25 years. VFD Equipment shall be electrically certified to Canadian Standards, typically by CSA, ULc, and FMc or via a third party approved by the Standards Council of Canada. Lloyds Register (LR) has been nominated as the Authorized Inspection Authority and Certifying Authority for all equipment on the WWRP. The Supplier shall contact LR to ensure they are aware of the submissions required to obtain certification for installation offshore on the WWRP.

4.5.1 Power Constraints and Downhole Cable Length

The total amount of power available for all ESPs has been estimated to be 7 MW to enable production and drilling operations to run concurrently. Vendors should work within this figure. However, it is important to initially propose the most optimum VFD-ESP combination for reservoir conditions. The Vendor of electrical submersible motors is required to provide the actual motor voltage and full load amperage in order to confirm the calculation of the required surface voltage. For the ESP wells, the downhole cable length is expected to be 3000m from the wellhead to the downhole electrical submersible motor, to an anticipated maximum of 4000m. Surface cable length will be ~100 m. The lengthy downhole cable poses harmonic resonance and motor start-up concerns. VFDs shall be designed to minimize voltage spikes (voltage overshoot) that result from the drive’s pulses interacting with the motor and motor feeder cable. Such voltage overshoot at the motor terminals shall be limited to 2.04 times the rated voltage as specified in NEMA MG, vendor to comment if more stringent limit is recommended. The proposed VFD shall have an integrated sinewave filter at the drive output to mitigate potential harmonic resonance at ESP systems. Each VFD shall provide near sinusoidal voltage and current waveforms to the electrical submersible motor at all speeds and loads.

4.5.2 Power Supply Available for VFDs

The medium voltage electrical supply for each VFD input is 13.8 kVAC, 3-phase, 60 Hz. The VFD vendor is to supply any required step down and phase-shifting transformer within the drive package, which must fit within the specified footprint.


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Dual 120VAC UPS supplies (A & B), from a separate source, will be provided to the drive. UPS switching must be provided within the drive. The transfer time should enable the transfer of the UPS source without shutting down the drive. The vendor shall also provide manual switching to enable selection of either supply for the operation. 600V 3-phase, 60Hz low voltage auxiliary power will be available to power the VFD cooling system. Other control power requirements, except for UPS and anti-condensation heater power, shall be derived from this 600V source. Other control power requirements shall be derived from the 600V source.

4.5.3 HSEQ

Suitable barriers or other protection shall be provided for wiring terminals mounted on hinged panels or doors to prevent accidental personnel contact when the panel or door is opened. Wiring to door mounted devices shall have mechanical protection. Wiring bundles on the rear of doors shall be suitably secured. A Kirk Key interlock shall be provided so that the power cabinet cannot be opened unless the upstream breaker is disconnected and safety-grounding switch is closed. Kirk Key interlocks shall be provided by the MV Switchgear supplier and free issued to the drive manufacturer for installation on the power cubicle access door(s). Also, safety interlocks shall be provided to discharge any medium voltage capacitors integral to the drive power assembly.

4.5.4 VFD Topology

The front end of each VFD shall be either 18 pulse or 24 pulse or higher. The inverter design can be based on either cascaded H-bridge multi-level inverter or neutral-clamped multi-level Pulse Width Modulation (PWM) technology. Bus bars shall be of electro-plated copper, color coded separately for AC and DC systems. All the live parts shall be sleeved/shrouded to ensure complete safety to personnel.

4.5.5 Draft Performance Requirements

The below performance requirements are a draft. ESP vendors are asked to review and provide feedback on the below in the RFI response. VFDs shall be designed to deliver the motor current and torque for the complete speed torque characteristics of the driven pump, with maximum input supply voltage variation of 10%, and frequency variation of 5%. The system shall be suitable for the load characteristics and the operational duty of the driven pump. VFDs shall be capable of withstanding thermal and dynamic stresses and the transient mechanical torque, resulting from short circuit. Any damage resulting from a short circuit or internal fault shall be limited to the component concerned. VFDs shall be suitable for two quadrant operation, and the speed variation shall be 0-120% with speed set

accuracy of 5% or better. Voltage sags of 80% shall not trip the system.


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The VFD shall be capable of providing all motor starting torques and accelerating torques throughout the operating speed range as indicated on the load speed-torque curve profile and on the data sheets of the motor. The vendor shall state proposed operating modes for various operating scenarios, i.e.:

Variable torque changing as a function of speed Constant torque over a specified speed range Constant power over a specified speed range where the torque decreases when speed increases

4.5.6 HMI Control Philosophy

The VFD shall be microprocessor based although during Normal Operation the ESP will be controlled by the platform Integrated Control and Safety System (ICSS). The VFD, Pump Control and Downhole instrumentation shall all communicate with the ICSS via the fewest number of connections, the preferred protocol is Profibus. A hardwired trip from the platform Emergency Shutdown System is required, vendor shall indicate the rampdown time of the drive under emergency conditions. A local pump/drive HMI is required for commissioning and troubleshooting integral to the VFD. Remote monitoring and diagnostics from onshore shall be provided as a functional requirement for the equipment. A connection shall be provided for remote monitoring via the Husky corporate LAN. A HMI with a graphical display shall be provided on the face of the VFD to display operating conditions, fault & alarm indications, and programming information. Trending of parameters both before and after faults/alarms should be available to downloading to a PC.

4.5.7 Monitoring and Feedback

The preference is to monitor each ESP through the platforms main control system (ICSS), the primary control point will also be the CCR via the ICSS. The suppliers may quote as an option for a separate monitoring system if recommended.

4.5.8 Protection and Control

The following protection and control function should be available inside the VFD: Overload protection, Adjustable acceleration/deceleration, Power ride-through, and Ground fault protection,

The VFD design shall be capable of interface with the platform Integrated Control & Safety System (ICSS). Communication protocol shall be Profibus. Signals for control and status for the platform Emergency Shutdown System (ESD) shall be hardwired. ESP vendors are asked to review and provide feedback on the below in the RFI response. The following minimum inputs shall be accepted by VFD:

Remote speed control


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Remote start Run permissive Fault reset Emergency shutdown

The following minimum outputs shall be provided by VFD:

Run status Common alarm Fan failure VFD tripped VFD speed feedback VFD output current

VFD’s shall be capable of being shut down from a remote signal from the ICSS. An emergency shutdown button shall also be provided locally on the VFD. The following protection parameters within the VFD shall be available to be configured as part of motor startup and commissioning:

Maximum output frequency Minimum output frequency Maximum output current during motor operation Current overload Maximum output current during motor starting Maximum output voltage Motor underload Input overvoltage Input undervoltage Input voltage unbalance Short circuit Ground fault

Protection for the drive feeder and the MV step-down transformer is provided by the MV feeder protection relay in the MV switchboard. The secondary leads from the step-down transformer shall be fitted with current transformers to facilitate differential protection. Protection for the drive and the motor load shall be part of the drive assembly. This would include provision for protection against short circuit on the secondary of the drive input power transformer.


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4.6 Medium Voltage Drive Specifications

Medium Voltage Drive

Description Specifications

Power System Technology Voltage Source Microprocessor-based Multi-level switching Cascaded H-bridge multi-level inverter or neutral

clamped multi-level PWM 3 Phase Supply Voltage (kV) 13.8 Input Voltage Tolerance 10 % Supply Frequency (50/60 Hz) 60 Input Frequency Tolerance 5 % Pre-charge DC bus Capacitor Circuit Yes Rectifier Device Diode Inverter Device IGBT Number of Pulses (ea.) 18 or 24 or higher Sine Wave Filter for pure sine wave at the drive output

required

Surface Voltage required (Volt) To be recommended by ESP vendor DC Link Capacitors Yes Input Power Factor 0.98 Approx. Efficiency (%) 96.5 Approx. Voltage Ride Through Duration 3-5 Cycles minimum – ESP vendor to recommend

in RFI limit for percentage of voltage sag Volt Dip/sag Ride-through Ride through greater than or equal to 20% sag.

(i.e. sag to 80% of nominal voltage) Catch Spinning Load Yes Rated Output Amps To be recommended by ESP vendor Speed Range 0 – 120 % Speed Control 5% Frequency Range ESP vendor to recommend in RFI

Environmental Enclosure rating NEMA 1 Humidity (non-condensing) Max 95% - No condensation Noise level at 1 meter distance < 85 dB required Cooling method Forced-air cooling (Internal) Ambient Temperature Operating Range 0 to 40ºC [32ºF to 104ºF] Altitude ~30m above Sea Level Dimensions (H, W, D) Approx. 4400mm x 1100mm x 2800mm W x D x H Motor type Must support both induction motors and

permanent magnet AC motors Weight Maximum allowable weight is 7140 kg per drive

Applicable standards CSA Table 4: Medium Voltage Drive Specifications


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11) Vendor to recommend output voltage and amperage requirements, considering future flexibility 12) Vendor to recommend electric characteristics including harmonic filtering at the drive output 13) Vendor to recommend key specifications and provide feedback on the above specifications 14) Vendor to propose SIT plan. 15) Vendor to propose any required demodulator filter / choke assembly to extract data from the down-

hole equipment that is being super-imposed on the MV power conductors. Shall be integral to drive. 16) GA Drawings 17) Vendor shall supply estimated airflow requirements and heat generation figures 18) Vendor to recommend voltage overshoot control for cable protection 19) State applicable certifications 20) Recommend controller capabilities related to managing potential downhole fault conditions 21) Identify any additional unique features or specifications that are either required or recommended for

the operation of your system 22) Equipment Datasheet

Future Deliverables (EOI Phase):

23) Interface and Connection Schedule 24) Foundation Loading Diagram & Support Details 25) One Line Electrical Diagrams 26) Utilities Schedule 27) Weight Data Sheet 28) Vendor shall indicate the rampdown time of the VFD and ESP under emergency conditions 29) Vendor to propose sparing philosophy 30) As part of the bid proposal, the Vendor shall provide an initial estimate of the weight and Center of

Gravity (COG) of the drive, with a maximum +/-15% tolerance 31) Vendor shall describe their ability to utilize or modify for utilization industry-typical VFDs that have not

been specifically designed/selected for their system.

5.0 Well Architecture

5.1 Well Schematics See below figures as well as Appendix A for draft well schematics showing examples of some possible completions configurations.


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Figure 3: CT Deployed ESP

Figure 4: Wet-Mate ESP, 140mm Tubing


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Figure 5: Wet-Mate ESP, Tapered Tubing

Note that these schematics are examples only; Husky is open to proposals for alternate configurations given that they achieve the key deliverables of this document.

5.2 Pressure Rating Max anticipated shut-in tubing head pressure (SITHP) is 31.0 MPa. Wells are to be designed and tested to minimum 34.5 MPa (5000 psi) to allow a kill margin of 3.5MPa (500 psi). At the time of this writing (post Gate 3 – project sanction), WWRP well designs are not currently required to accommodate hydraulic stimulation. However, during the well design phase, hydraulic stimulation may be a consideration as maintaining the capability (or ability to upgrade) for through tubing hydraulic fracturing (at 44.8 MPa / 6500 psi) is desirable if accomplished without increasing the base cost. Vendor input is requested regarding potential for overpressure from ESPs and any tubing design recommendations or operational recommendations related to ESP generated pressures.


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5.3 Casing Constraints and Anticipated Tubing The production casing preference for all wells is 244mm (9-5/8”), 216mm (8.50”) drift casing. Where required, a 273mm x 244mm tapered casing string can be utilized to accommodate 178mm tubing and associated TRSVs, with the casing crossover at ~900m MD. Consideration may be given to deploying 273mm casing as deep as 3000m MD if required to accommodate ESP designs, however this configuration is not preferred due to casing loading and cementing ECD implications requiring more detailed well-specific assessment.

5.4 Barrier Philosophy The Regulator requirement in accepting an ISO 19906 L2 CGS design w.r.t iceberg impact is for dual well barriers excluding the wellhead. The following barriers are planned to meet this requirement:

5.4.1 Planned Tubing Barriers:

TRSV; Surface controlled downhole lubricator valve (LUBV)

o It is intended to place the LUBV above the TRSV for intervention utilization and protection of the TRSV

5.4.2 Planned Annular Barriers:

Production Packer; Overbalanced brine above packer

o Therefore, annulus may not be utilized for annular hydrocarbon flow

5.5 Required Completion Functionality

Downhole Chemical Injection below ESP (for Scale Inhibition); Pressure and Temperature measurement up and downstream of the pump; Capability to hydrostatically set the production packer, and contingent hydraulic set against a

tailpipe bridge plug; Completion string forces to be anchored by production packer – No PBR or tubing movement

permitted; Intervention access to service the sandface completion: 4.562” through-bore preferred; Ability to maintain (or restore) two barriers between hydrocarbons and personal for all potential

ESP failure / repair scenarios; Ability to remove hydrocarbons from completion string if utilizing completion string as a lubricator

for ESP toolstrings.


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5.6 Controls Passage To allow for control of completions components below the ESP, the system provided shall allow for minimum 1x 3/8” encapsulated DHCI line and minimum 3x (preferentially 5x) 1/4” encapsulated control lines past the ESP. ESP cable mounted external to the completion tubing must be able to fit past any completions components for the casing and tubing sizes identified in the above concept schematics.


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5.7 Other Specifications

Item # Criteria Husky Requirement Reference Document(s) Comments

1. Temperature Rating

Handling: -20 to +35 °C Installed: +4 to 120 °C

2. Minimum Pressure Rating

34.5 MPa (5000 psi) Well pressure rating WREP Subsurface Basis of Design WH-G-99W-G-SP-00003-001 Rev E5

3. Service Requirements

Rated for H2S service to 200 ppm and CO2 to 2.0%. NACE MR0175/ ISO15156 WREP SSBOD

4. Metallurgy Component materials to be equivalent to or better than L-80 13 Chrome tubing. 17-4 PH material is unacceptable.

NA-DAC-RP-0025: “North Amethyst Lower String Completion Metallurgy and Elastomer Review”

5. Seals

- All seals must be suitable for hydrocarbons, CO2, H2S and organic amines.

- Metal-to-metal sealing is preferred where possible. - Tubing-to-Annulus sealing shall be barrier qualified to industry

standards - All sealing components shall be Incoloy or better metallurgy

NA-DAC-RP-0025: “North Amethyst Lower String Completion Metallurgy and Elastomer Review”

6. Erosion

- Components subject to erosive velocities or materials must be constructed of erosion-corrosion resistant materials. Industry practices shall be followed for fluid velocity design and erosion mitigation.

API RP 14E

7. Well Production Life

Well design life is 15 years. Any components permanently installed as an integral part of the completion string shall meet this design life.

8. Connections Shall have premium connections that, where practicable, shall match the tubing connections used in that well. Connections shall be gas tight.

ISO Cal IV

Table 5: Additional Specifications


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5.8 Wellhead Details The platform will utilize conductor sharing for all slots; two 13-3/8” surface casings strings will be landed in each 36" conductor. Wellhead and XMT detailed design work is on-going, both vertical and hybrid horizontal XMTs are under consideration. The XMT will have a 6-3/8” bore and 6500 psi pressure rating. Wellheads are being designed to permit a maximum of 8 penetrations of which 5 are reserved for the following: two down-hole barriers (TRSV and LUBV), CI and DHPTG. It has been identified that in the case of a conventionally deployed ESP cable (external to tubing), the cable will need to be separated into 3 individual wires to pass thru the upper completion tubing hanger.


32) Vendor to provide whole-well schematic(s) of their proposed solutions: a) Indicate tubular sizes and flow paths; b) Vendor free to propose alternate tubing sizes & configurations vs schematics as appropriate

for production, barrier and all other needs; c) Contact Husky for native Visio schematics if desired to use the above template.

33) Vendor to provide expanded schematic of the ESP system showing flow paths; 34) Vendors to assess ID/OD constraints and recommend solutions with IDs/ODs specified, including:

a) Permanent completion string components supplied by Vendor: Max ODs to be specified; Casing size requirement to be specified; Control line bypass to be specified.

b) Intervention Accessibility: Minimum throughbore available for intervention access below the ESP is to be

specified; Minimum allowable tubing ID above the ESP so as to allow for ESP deployment is to

be specified. c) Fluid velocities through any restricted areas to be addressed and be within industry

recommended limits. Note the highest fluid velocities that will occur for the given production rates, the location and any required mitigations.

d) Cable dimensions to be specified: If external to tubing, required casing size to be stated considering cross-coupling

clamps and passage past other components. 35) Vendor to propose cable sizing and protection & detailed justification of conductor sizing; 36) Vendor input is requested regarding potential for overpressure from ESPs and any tubing design

recommendations or operational recommendations related to ESP generated pressures. 37) Vendor to provide recommendations, details and specifications related to the ESP cable feed thru

terminations at surface (wellhead/tubing hanger/XMT) to connect the ESP to the power supply cable from the VFD’s. Due to space limitations and constraints, vendor should endeavor to provide an equipment solution that is as optimized and compact as possible. All surface terminations and connections must have CSA (or equivalent) certification.


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6.0 Mechanical Handling Constraints

6.1 Intervention Capabilities The ability to conduct intervention and/or workover activities concurrent with drilling operations will be critical to deliver the White Rose production profile.

The WWRP shall be designed to permit the following well intervention activities:

Coiled Tubing ESP Deployment, 2-3/8” preferred; Coiled Tubing ESP Intervention – Change out; Coiled Tubing Interventions on 2-3/8” workstring, including but not limited to the following activities:

o Wellbore Cleanout (sand, scale, etc.); o N2 pumping for wellbore cleanout, lifting wellbore fluids; o Jet perforating; o Completion Insertion and Removal under Pressure (CIRP) deployment for perforating; o Pressure deployment using appropriate BOP’s and slick bars; o Data acquisition, PLT, RST and sampling; o Milling/drilling; o Chemical stimulation treatments; o Well isolations, plugging/straddles; o Gas lift valve servicing; o Production tubing/liner repair; o Cement squeezing/plugging; o Shifting sliding sleeves;

Wireline Interventions including but not limited to the following activities: o Logging and data acquisition, USIT, PLT, RST, caliper; o Zonal isolation; o Downhole sampling; o Shifting sliding sleeves; o Re-perforations;

Slickline interventions including but not limited to the following activities: o Downhole safety valve maintenance; o Back pressure valve installation; o Wax removal; o Shifting sliding sleeves; o Drifting; o Isolation/barrier plug intervention; o Memory pressure/temperature gauge surveys; o Gas lift maintenance;

Pumping including but not limited to the following activities: o Well kill/circulating; o Formation fracture (injectivity test); o Chemical squeeze; and

Tree Installation and Removal. Sufficient space shall be provided on the middle deck for equipment and operation of intervention equipment. See Figure for details.


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It is anticipated that the following equipment will be required for intervention operations:

Coiled Tubing Unit and ancillary equipment (power reel, tubing, injector w/ gooseneck, fluid pumps, surface piping, hydraulic power unit, hose reel packs);

Liquid Nitrogen Pump Skid and Storage Tank; Coiled Tubing Jacking Frame; Intervention Blowout Preventer and Well Control Equipment (for coiled tubing and slickline/wireline); Coiled Tubing Reels; Control Cabin w/ Coiled Tubing Data Acquisition equipment; Combination Slickline / Wireline Unit and associated equipment (double drum, sheaves, load cell,

etc.); Work Frames; Intervention Hatch Cover; Provision for a lifting device at the Drill Deck level, with capability to be installed beneath the DES

when necessary, for the deployment of ESP components and support of Wireline operations. The WWRP design will provide for the following to support well interventions:

Deck space with suitable structural design to support the loads of the intervention equipment such as coil tubing and Wireline units;

Suitable middle deck to drilling deck spacing to safely and efficiently deploy intervention equipment and tools;

Mechanical Handling facilities to efficiently move the Coil Tubing Unit and Jacking Frame to permit access to any well slot;

Mechanical Handling facilities for the movement of Coil Tubing Reels; Utility services such as plant air, nitrogen, seawater, drill water and power as required; Base oil and brine supply from WWRP Base Oil and Brine distribution; and Facility for venting hydrocarbon gas and fluids from intervention equipment.

Space for the laying down and storage of equipment baskets (e.g. ESP) shall be considered in the design. The spacing on the middle deck (Top of Steel) to the Drilling Deck (Bottom of Steel deepest beam section) shall provide a minimum spacing of 11.2 meters to permit coiled tubing operations.


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Figure 6: WWRP Intervention Area


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6.2 Deck Weight Limitations The ESP CT drum storage area and Coiled Tubing operations area will have sufficient deck loading capacity to support a 35 mt reel. The ESP cable and reeler located on the DES spooler deck must not exceed 20 mt.

6.3 Crane Limitations The ESP CT drum will be stored on the west end of the driller storage area north as per Figure . The crane capacity to reach this location will be the limiting factor as shown in Figure . The ESP CT drum w/ transport/storage stand and rigging must not exceed 35 mt.

Figure 7: ESP Drums for Workstrings


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Figure 8: Crane Capacity

6.4 Handling Heights ESP’s will be installed from the middle deck intervention area. All ESP sections will require to be installed within the height of this deck. See Figure for details. A lifting device will be available on the above drill deck which will allow the entire height of the middle deck to be utilized for lifting, approximately 11m. An example coiled tubing rig-up in included for illustrative purposes. The ESP pumps will be transported into the well bay area from the MDLA North. The shipping baskets must not exceed 40 feet.


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Figure 9: WWRP Intervention Dimensions Looking North


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Figure 10: WWRP ESP Makeup – Tall Tree


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6.5 Cable and Spooler Constraints The ESP reeler will be located on the Drilling Equipment Set (DES) spooler deck. See Figure & Figure for details. The ESP reeler will be used in conjunction with up to five (5) additional completion reelers. A padeye will be available in the derrick to install the ESP cable sheave. The sheave must be capable of handling the breaking load of the ESP cable. Maximum breaking strength of the ESP cable is to be 24,000lbs.

Figure 11: WWRP Drilling Equipment Set (DES) Spooler Deck

Figure 12: WWRP Drilling Equipment Set (DES) Spooler Deck


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6.6 SIMOPS Drilling/completions operations will be ongoing during installation of ESP on the middle deck.


38) Vendor to provide installation and change-out procedures (operational steps) 39) Vendor to provide BHA lengths and weights for handling 40) Provide cable weights

7.0 Installation and Maintenance

7.1 Requirements

The system shall facilitate rigless installation and replacement of the pump, motor, protector and gas handler;

Ability to monitor cable integrity during deployment. Protection of any permanent completion components for thru-tubing intervention and pumping

operations. The system shall allow the ability to bullhead through the ESP without mechanical intervention.

7.2 Vendor RFI Deliverables

41) Engineering Data Sheets (EDS) for component specifications. 42) Identify any compatibility restrictions between the proposed motor/system and other industry typical

downhole tools. Does the system allow the flexibility to pair with pumps, monitoring and protection tools from other vendors?

43) Vendor to provide a step-by-step sequence of operational steps for both initial installation and future change-out, inclusive of rig-up, rig-down and wellbore access activities from production shut-in to restart. A benchmarked or estimated time shall be assigned to each step.

44) For CT deployed systems, outline how retrieval is affected if there is a leak in the coil? a) How is hydrocarbon ingress into the coil dealt with at surface? b) Would a burst disc in the coil to facilitate circulation be recommended?

45) Vendors shall identify a quality control plan as a part of the bid, including Factory Acceptance Testing (FAT) and Systems Integration Testing (SIT).

a) Discuss access to facilities required to conduct an FAT and/or SIT, and the capabilities of the facilities.

b) Please note ability to test pump stages in gassy conditions. Husky Energy are interested in conducting performance testing using nominated pump stages and advanced gas handling devices in near real well conditions.

c) Please note your company’s ability to conduct full mock up SITs modeling the dimensional limits expected on the platform. This testing would include the entire ESP assembly, length


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of cable, project VFD (from the selected vendor), and wellhead and other components necessary.

46) Vendor to address slack management of cable if deployed inside coil. 47) Vendor to outline protection of any permanent completion components for thru-tubing intervention

operations and potential frac-through operations. 48) Vendor to comment on frac-through capability. 49) Sparing Philosophy. Identify the components that will be required as back-up inventory, considering

all life-of-well production pump/motor configurations identified. Recommend a spares stocking and ownership strategy.

50) Identify the minimum POB required offshore for installation of the system during both the completion tubular running phase, and the well commissioning, well startup and ESP change-out jobs from the intervention deck.

8.0 Reliability & Operability

8.1 Vendor RFI Deliverables

51) Vendor to provide reliability analysis: a) Track history:

Analogous installs & performance of same. Details should include (but not limited to): Project Name and location, operator, installation date, number of wells per platform, production casing & tubing program and brief description of ESP configuration.

Identify any components or sub-components requiring re-design or re-configuration for the WWRP project, and/or any components that do not yet have a field run history in the same size and configuration as required.

b) Failure rates and statistics, to be component specific (i.e. Motor vs. pump vs. cable failures) with root causes identified.

c) Address qualification, reliability and track history of downhole electrical connections & terminations and wellhead penetrations.

52) Please discuss how the system accommodates axial thrust and describe special design criteria or configurations used by your company providing seal section/ protector and thrust bearing performance.

53) Service environment / corrosion mitigation strategy to be addressed, including brine, drill mud and formation fluid compatibilities.

54) For CT deployed systems, what fluid is recommended for inside the coil? 55) Recommended or anticipated change-out frequency based on MTTF expectation for each

component, including motor, pumps, cables, receptacles, gas handlers, protectors, etc. 56) Vendor to propose equipment change out frequency based on corrosion if an applicable concern. 57) Outline what downhole data the system monitors, including environmental data, system data, and

fault condition data. 58) Identify maximum motor operating temperature and cooling method. 59) Identify any potential concerns and mitigations with interference between the ESP power cable and

the DHPTG cable/signal.


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Appendix A – Well Schematics

esp functional specification - eoi rev1 functional...west white rose project functional...

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