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SemCAMS | Operator Specification Manual (November 2016) 1 OPERATOR SPECIFICATION MANUAL
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Page 1: Operator Specification Manual

SemCAMS | Operator Specification Manual (November 2016) 1

OPERATOR

SPECIFICATION

MANUAL

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SemCAMS | Operator Specification Manual (November 2016) 2

Contents

Introduction Document Conventions 5 Definitions 5 Application of Process 6 SemCAMS Need for Information 7

1. Process Milestones and Schedule

1.1. Instruction 8 1.2. Project Stages 8

1.2.1. Stage 1: Initial Contact 8 1.2.2. Stage 2: Commercial and Business Development Negotiations 9 1.2.3. Stage 3: Design and Installation 10 1.2.4. Stage 4: Commissioning and Startup 10 1.2.5. Stage 5: Normal Operations 11

2. Facility and Pipeline Requirements

2.1. Introduction 12 2.2. Stage 3: Design and Installation 12

2.2.1. Gas Quality 13 2.2.2. Liquid Quality 13 2.2.3. Dewpoint Control 13 2.2.4. Chemical Injection Requirements 13 2.2.5. Cathodic Protection 14 2.2.6. Automation for Remote Shutdown Capability 14

2.3. Stage 4: Commissioning and Startup 15 2.4. Stage 5: Normal Operations 15

3. Measurement Requirements

3.1. Introduction 16 3.2. Design and Installation 16

3.2.1. General Requirements 17 3.2.2. Gas Measurement 17

3.2.2.1. Meter Specifications 17 3.2.2.2. Volume Calculations 17 3.2.2.3. Device Installation 17 3.2.2.4. Fuel Gas 18 3.2.2.5. Gas Sampling 19

3.2.3. Liquid Measurement 19 3.2.3.1. Meter Specifications 19 3.2.3.2. Volume Calculations 19 3.2.3.3. Liquid Sampling 20

3.3. Commissioning and Startup 20 3.3.1. Information Required Prior to Startup 20 3.3.2. Site Acceptance Inspection 21

3.4. Normal Operations 21 3.4.1. Gas Meter Calibrations 21 3.4.2. Meter Proving 22 3.4.3. Sampling and Analysis 22 3.4.4. Changes Impacting Measurement and Allocations 24

3.4.4.1. EMF Information Updates 25

4. Reporting and Allocation Requirements 4.1. Introduction 26 4.2. Fixed Data Requirements 26

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4.2.1. Working Interest Ownership 26 4.2.2. Take-in-Kind (TIK) Directions from Product Owner 29

4.3. Daily Confirmation and Allocation Process 30 4.4. Daily Volumetric Reporting – Data Requirements 31 4.5. Schedule or Unscheduled Plant to Plant Reroute Process 32 4.6. Monthly Allocation Process 33 4.7. AER Volumetric Reporting 34

Appendix

1. K3 Gas Gathering System A. KBS-110 North West Wapiti Pipeline 36 B. KBS-116 North West Wapiti Loop Pipeline 38 C. KBS-120 Wapiti Pipeline 40 D. KBS-130 Simonette Pipeline 42 E. KBS-140 Kaybob West Pipeline 44 F. KBS-150 Fir Pipeline 46 G. KBS-160/161 Gregg Lakes Pipeline 48 H. KBS-170 Tower Creek Pipeline 50 I. KBS-180 Obed Pipeline 52 J. KBS-211 Treestone Pipeline 54 K. KBS-220 Winterburn Pipeline 56

2. Pine Creek Gas Gathering System

A. PCK-110 Oldman Pipeline 59 B. PCK-111 Nordegg 8” Pipeline 61 C. PCK-112 Nordegg 6” Pipeline 63 D. PCK-130 Pine Creek South High Pressure (Wet) Pipeline 65 E. PCK-134 Pine Creek South High Pressure (Dry) Pipeline 67 F. PCK-135 Pine Creek South Low Pressure Pipeline 69 G. PCK-140 Jackfish North Pipeline 71 H. PCK-141 Jackfish South Pipeline 73 I. PCK-142 Pine Creek North Pipeline 75 J. PCK-145 Fir Interconnect Pipeline 77 K. PCK-150 North West Pine Pipeline 79 L. PCK-180 Pine Creek 14” Sales Pipeline 81

3. KA Amalgamated Gas Gathering System

A. KAY-110 Tony Creek Pipeline 84 B. KAY-111 Tony Creek Extension Pipeline 86 C. KAY-140 KA North Pipeline 88 D. KAY-150 KA Condensate (HVP) Pipeline 90 E. KAY-160 Spotter Pipeline 92 F. KAY-210 Dunvegan Pipeline 94 G. KAY-211 Dunvegan Extension Pipeline 96 H. KAY-220 Bigstone NGL (HVP) Pipeline 98 I. KAY-230 C-Pool Pipeline 100 J. KAY-250 Southwest Gas Gathering System 102 K. KAY-260 East Viking Pipeline 104

4. West Fox Creek Gas Gathering System A. KAY-270 West Fox Creek North Pipeline 107 B. KAY-271 West Fox Creek North (06-35 Lateral) Pipeline 109

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C. KAY-272 West Fox Creek North (06-27 Lateral) Pipeline 111 D. KAY-273 West Fox Creek North East Pipeline 113 E. KAY-280 West Fox Creek South Pipeline 115 F. KAY-281 West Fox Creek South (06-35 Lateral) Pipeline 117 G. KAY-282 West Fox Creek South (08-03 Suction) Pipeline 119 H. KAY-283 West Fox Creek South (08-03 Discharge) Pipeline 121 I. KAY-284 West Fox Creek (10-22 Lateral) Pipeline 123

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Introduction

A Customer Tie-in Process for SemCAMS is required to ensure a common and consistent application of design, operation and measurement philosophy throughout various gas gathering and processing facilities owned by SemCAMS. This document identifies those policies, processes, procedures and standards for the design, operation, accurate measurement and reporting incumbent on Owners of facilities at the Acceptance Points and it may be implemented as a Letter of Agreement.

Document Conventions

This document and the process it describes are managed as part of the SemCAMS Measurement Integrity Process (MIP). The MIP has been undertaken by SemCAMS to outline policies, processes and standards to ensure measurement and allocation is handled consistently and equitably throughout the plants and gathering systems that SemCAMS owns and/or operates. Updates to this document will be created as the need arises and Customers can request updates directly from the contacts listed in section 2 of this document.

Definitions

Throughout this document, specific terms are used in SemCAMS business processes. These terms are bolded and italicized as they are used throughout this document. The definitions of these terms are provided as follows.

CSO (Common Stream Operator) – Company that is responsible for submitting daily estimates of gas production to the sales transportation pipeline companies on behalf of all the shippers at each sales meter station.

Customer – Any company or party that has ownership or interest in an Acceptance Point that feeds into a SemCAMS operated facility.

EFM (Electronic Flow Measurement) – Any combination of devices used to calculate gas or liquid volumes in a microprocessor based computation device. EFM may or may not include the ability for remote communication/configuration. Customer is directed to the appropriate pipeline specific requirements in Section 3 of this document.

Gathered Volume – Volume received into a SemCAMS gathering system for an acceptance point.

Volume is to include gas equivalent of any condensate that is recombined with the gas and is still present in the product stream at the SemCAMS plant inlet.

Volume is to be net of any self fuel or flare / vent taken downstream of the physical measurement (within the confines of the Customers facility or reporting battery / compressor station).

For effluent metered locations volume provided to SemCAMS will have had effluent factor applied and volume prorated back from a sufficient group metering location (see Prorated Group Allocation Point).

For non-SCADA entities volume may be estimated for the purpose of “daily volumetric reporting1”

1 Refer to Section 4 of this document.

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Product Stream Analysis – Component analysis data (to C7+) for product(s) measured at an acceptance point.

Gas analysis to C7+ component

Where condensate is recombined with gas require liquid hydrocarbon analysis to C7+ component, molar mass of the grouped fraction (C7+) and daily gas and liquid volumes corresponding to the date the product samples were taken.

SemCAMS to perform recombination calculations for the Gathered Volume as required.

Acceptance point – A meter owned and operated by SemCAMS, or by a company with which SemCAMS does business and is used to measure product (by component) entering a SemCAMS pipeline or gas processing facility. An Acceptance Point meter includes those which:

Determine the allocation of product to customers,

Determine the volume of product entering a gathering system or gas plant. Acceptance points are broken down further into the following types:

i. Measured Well Head – Acceptance point is at a well head employing two or three phase separation.

• SemCAMS allocation is from plant inlet (or other SemCAMS operated intermediate entity) directly to well head Gathered Volume and Product Stream Analysis.

ii. Custody Group Allocation Point (CGAP) – Acceptance Point is at a group metering location employing two or three phase separation.

• SemCAMS allocation is from plant inlet (or other SemCAMS operated intermediate entity) directly to groups Gathered Volume and Product Stream Analysis.

• Customer is responsible for allocation to entities in front of this Acceptance Point.

iii. Prorated Group Allocation Point (PGAP) – Acceptance Point is at the physical wells in front of a group metering location based on pro-ration of the Gathered Volume measured at the group metering location.

• SemCAMS allocation is from plant inlet (or other SemCAMS operated intermediate entity) to each wells prorated share of the groups Gathered Volume and each wells Product Stream Analysis (volume at group point is considered the “receipt volume” but analysis data for the purpose of allocation is from the individual wells).

• Group metering location employs two or three phase separation.

• Product stream analysis for the group metering location is used only for the volume calculations performed at the group location not for allocation.

• Must be applied to all effluent measured wells. • Will be applied to “measured wells” where customer provides a Gathered Volume

from a known group metering location or shows fuel / flare / vent common to all upstream wells.

Tie-In Point – Physical connection to a pipeline system (either producer owned or owned by SemCAMS).

Application of the Process

This process is to be applied for all Customer entities that will be connected as Acceptance Points into a SemCAMS system. The Customer is responsible to ensure all expectations detailed in this document have been met. Any exceptions to the standards specified in this document must be

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approved by SemCAMS prior to installation. SemCAMS would expect that Customer’s will follow the process for entities that are connected as a Tie-In Point upstream of existing Custody Group Allocation Acceptance Points but will not enforce the measurement requirements as listed in Chapter 4 of this document. All measurement requirements for entities in front of Custody Group Allocation Acceptance Points are to be determined by the operator of the Acceptance Point.

SemCAMS Need for Information

As the CSO of the West Whitecourt, Kaybob Amalgamated, West Fox Creek and Kaybob 3 gas plants and their associated gathering systems, SemCAMS is responsible for both daily and monthly allocation of sales gas and by-products to the producers (Customers). To carry out these tasks effectively, SemCAMS requires accurate production, ownership and marketing information in a timely fashion from the Customers. For this reason, this process applies not only to Acceptance Points but to entities attached upstream of the CGAP. By collecting information on these points, SemCAMS is able to be proactive in managing the allocation system.

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1 Process Milestones and Schedule

1.1 Introduction

This section provides the generic sequence of events for the tie-in of an Acceptance Point to a SemCAMS facility. The Customer is referred to the specific chapters of this document for the key criteria pertaining to each stage.

1.2 Project Stages

From the standpoint of the Customer, the process of connecting to a SemCAMS system or plant can be broken into the 5 basic stages as shown here:

Stage

Description

1 Initial Contact

2 Commercial and Business Development Negotiations

3 Design and Installation

4 Commissioning and Start Up

5 Normal Operations

In each of these stages there is a need for open lines of communication between the Customer and the SemCAMS Field Business Development/Measurement Specialist (refer to Table 1.1: of this document). In some stages a level of signoff is required by SemCAMS prior to progression to the next stage. This is not intended to hinder the Customer but rather to ensure that a level of consistency be maintained throughout gathering systems that SemCAMS is responsible for allocating sales products within. Attention to these details prior to start up should minimize the need for future re-work of allocation and costly production outages to revise equipment to meet the required standards.

The generic details of each stage are included in this section of the document. Specific requirements for each stage are provided in the other sections of this document.

1.2.1 Stage 1: Initial Contact

This stage is considered the kick-off stage for the potential acceptance point tie-in. Preliminary information is gathered but the Customer may still be assessing the economics of production or considering alternate gathering and processing avenues.

This section provides the Customer the details of information required by SemCAMS to commence initial planning to determine the potential for the Customer to connect to one of the SemCAMS facilities. It also provides the Customer with contact information for the key field business development personnel for each of the processing facilities that SemCAMS operates.

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Responsible Event Trigger Action (s)

Customers Representative

Well discovery or re-direct

Complete SemCAMS “Customer New Well/Facility Form” and email completed form to appropriate SemCAMS Field Business Development Measurement personnel listed in Table 1.1.

Customers Representative

Confirmation of facility/well approval

Complete SemCAMS “Customer New Well/Facility Form” and email completed form to appropriate SemCAMS Field Business Development Measurement personnel listed in Table 1.1.

Table 1.1: Contact Information

Title Name Contact Information

Field Business Development / Measurement Supervisor

Ben Johnston

Office: (780) 725-4013

[email protected]

Field Measurement Integrity Team John Hanson Office: (780) 725-4007

[email protected]

Field Measurement Integrity Team Josh Doran Office: (780) 725-4009

[email protected]

Field Measurement / Analysis Measurement Integrity Administrator

Fax: (780) 723-3260

[email protected]

1.2.2 Stage 2: Commercial and Business Development Negotiations

Prerequisite – All aspects of stage 1 must be completed prior to the kickoff of this stage.

This section provides the Customer with key details pertaining to requirements that must be met with regard to agreements and contracts. The SemCAMS Field Business Development will provide the required contact names for other SemCAMS representatives as required.

The following are the basic contract requirements for each standard2 entity:

For Measured Well Head Acceptance Points, each working interest owner must have a transportation agreement in place for all SemCAMS and third party pipelines the production will be flow lined through.

For Measured Well Head Acceptance Points, each working interest owner must have a processing agreement in place for the SemCAMS facility that will process the gathered products.

2 A “standard” entity would include a well or acceptance point with only one delivery pipeline connected to it. If there is a potential that production can split and/or re-route to alternate facilities for gathering or fuel supply than SemCAMS needs to be advised of this during this stage.

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For Custody Group Allocation and Prorated Group Allocation Acceptance Points each working interest owner for each well upstream of the Acceptance Point must have a transportation agreement in place for all SemCAMS and third party pipelines the production will be flowing through.

For Custody Group Allocation and Prorated Group Allocation Acceptance Points, each working interest owner for each well upstream of the Acceptance Point must have a processing agreement in place for the SemCAMS facility that will process the gathered products.

Appropriate road use agreements are in place.

Other areas to be considered during this stage and prior to construction include:

If pipeline being connected to can re-route production to an alternate system / plant then all of the contracts listed above must also be in place for the alternate system/plant.

Source of fuel for proposed entity and agreements in place to cover?

Marketing agreements in place for each working interest owner for the saleable products (outlet of gas plant)?

Water handling and disposal agreements in place?

Cathodic protection requirements (refer to Section 2.2.5 of this document).

1.2.3 Stage 3: Design and Installation

This stage involves the design and physical construction of the Acceptance Point facility. The majority of Stage 2 should be complete prior to this stage. This section provides the Customer with the expectations that must be met for the appropriate design and installation of the Acceptance Point.

A SemCAMS representative must be included in a design review meeting prior to construction. SemCAMS encourages the Customer to work proactively with the relevant SemCAMS Field Business Development during this stage.

1.2.4 Stage 4: Commissioning and Startup

During or immediately following this stage, SemCAMS reserves the right to conduct an inspection of the Customer’s Acceptance Point facility. Any major deficiencies identified during the inspection must be corrected by the Customer within the specified time frame. Failure to do so will result in shut in of the acceptance point. The following must be in place 5 days prior to start up:

New Well Tie-In Form submitted to SemCAMS Field Business Development Supervisor.

All Transportation and Processing agreements must be in place.

Take in Kind Notices (TIK) in place for all product owners with the CSO.

SemCAMS Notice of Agent Agreement form in place.

Transportation Service Provider (TSP) nominations must be in place for all product owners.

Process in place for daily production reporting to CSO.

SemCAMS Field Business Development Supervisor approval to start up.

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Note: SemCAMS will not grant approval for a facility startup within the last 3 days of a calendar month.

1.2.5 Stage 5: Normal Operations

This stage begins immediately following startup of the Acceptance Point. During this phase, SemCAMS reserves the right to conduct site inspections to ensure compliance with this process upon appropriate notification.

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2 Facility and Pipeline Requirements

2.1 Introduction

This section details the pipeline related requirements that the Customer is to meet when directly tying into a SemCAMS pipeline for the stages of the process that are applicable.

2.2 Stage 3 - Design and Installation

The Customer is asked to ensure their facilities comply with the following SemCAMS requirements as failure to meet these requirements may result in a delay for permission to start up:

Refer to the SemCAMS Pipeline Tie-in specifications for specific engineering design and operating specifications pertaining to pipeline(s) delivering product for processing at the;

1. K3 Gas Plant (Appendix 1 & 2)

2. KA Amalgamated Gas Plant (Appendix 3)

3. West Fox Creek Plant (Appendix 4)

4. West Whitecourt Plant (Field Business Development Supervisor will provide upon request)

The metering facility design must meet the specifications outlined in the Section 3 of this document.

The Customer’s design review will include a SemCAMS representative. The design review will include (but not be limited to):

Ownership break / lease management responsibility

Block valve, check valve, spec blind, local pressure indicator

Future blinded tee connection

Cathodic protection and isolation

Emergency shutdown devices and set points

Piping codes and standard engineering practices

Piping configuration / layout / plot plan

Chemical injection and corrosion monitoring equipment

Automation and measurement requirements

Shutdown key (refer to Schedules in the SemCAMS Pipeline Tie-in specifications)

The Customer will contact SemCAMS Gas Control (780-712-5082) prior to entering any SemCAMS facility,

The Customer is required to contact SemCAMS and obtain permission at least 72 hours prior to requested start-up.

The Customer will supply required Emergency Response Plan information to SemCAMS for updating of the SemCAMS ERP.

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2.2.1 Gas Quality

The gas entering a receipt point must meet the following criteria:

free of oxygen,

CO2 content must be less than 2%. If the CO2 content exceeds 2%, the Customer will be responsible for any penalties incurred.

2.2.2 Liquid Quality

Injection of free hydrocarbon liquids must be approved by SemCAMS. Hydrocarbon liquids must be free of the following:

Oxygen, water, paraffin, solids and work-over fluids

Injection of free water must be approved by SemCAMS

Customer facilities that require BS&W control incorporated in their design the following:

BS&W probe if condensate is approved to be injected into SemCAMS pipeline.

Condensate BS&W maximum limit to be determined jointly by the Customer and SemCAMS engineering/operations prior to start up.

Automatic shutdown set points for BS&W.

All Customers gas/condensate shall be free from substances in such quantities that may obstruct, damage or be detrimental to the operation of the pipeline.

Note: If injection of free hydrocarbon liquids or free water is to be considered an analysis must be forwarded to SemCAMS and approved prior to injection. The sample must be analyzed and be within specification for phosphorus (<1.5ppm) and olefin (<1%WT) readings.

2.2.3 Dew Point Control

Customer facilities that require dew point control (refer to Schedules in the SemCAMS Pipeline Tie-in specifications) must incorporate in their design the following:

Gas dew point analyzer required at all dehydration facilities

Dew point limit of –10º Celsius

Automatic shutdown set points for dew point

2.2.4 Chemical Injection Requirements

SemCAMS pipeline systems have pipeline specific requirements pertaining to chemical injection (refer to Schedules in the SemCAMS Pipeline Tie-in specifications). Customer injected chemicals must be compatible with SemCAMS existing chemical programs and meet specific minimum rate injections. SemCAMS Pipeline Asset Integrity Team must review and approve chemicals and injection rates. The following conditions apply:

No sulphur dispersants chemical will be accepted into SemCAMS Pipelines. The Customer will ensure equipment is in place to eliminate the possibility of sulphur dispersant entering the SemCAMS pipeline.

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No Methanol to be introduced into high pressure sour pipelines systems without prior approval from SemCAMS Pipeline Supervisor.

Batch Treatment of Customer pipelines during normal operation SemCAMS must be notified in advance, this should include batch chemical type, size and schedule.

Under no circumstances will Nitrogen be allowed into the SemCAMS operating pipeline.

2.2.5 Cathodic Protection

SemCAMS maintains cathodic protection to protect pipelines owned and operated by SemCAMS. SemCAMS presently performs monthly rectifier checks together with an annual survey to ensure adequate protection is being supplied and maintained throughout the system.

SemCAMS could provide coverage to the Customer’s pipeline subject to receipt and agreement by the Customer of the following conditions:

SemCAMS preferred vendor will perform an initial evaluation of the Customer owned pipeline to determine protection requirements. Cathodic protection requirements include protecting the pipeline only and do not include any well bore protection that may be required.

On determining pipeline protection requirements, SemCAMS is prepared to provide the following:

• If initial protection requirements determine that SemCAMS existing rectifier can provide adequate protection levels without modifications or upgrades, SemCAMS will provide protection to the Customer’s pipeline, providing an insulation kit is installed downstream of the wellhead and wellhead facilities to isolate them from the pipeline. There will be no guarantee or liability on SemCAMS part.

If during the life of the project any cathodic upgrades were required in order to continue protecting the Customer’s pipeline, the Customer would be responsible for their share of upgrade costs. SemCAMS does not indemnify Customer in any way for the installation of any requested Cathodic Protection, specifically in respect of any damage which may occur as a result of the installation.

• If initial protection requirements determined that SemCAMS existing rectifier cannot provide adequate protection levels without equipment upgrades or modifications, SemCAMS would still be willing to provide protection, with the Customer being responsible for upgrade costs. As stated above, there will be no guarantee or liability on SemCAMS behalf.

If during the life of the project any cathodic upgrades were required in order to continue protecting the Customer’s pipeline, the Customer would be responsible for their share of upgrade costs.

In accepting any of the above protection conditions, the Customer accepts that the SemCAMS preferred vendor would directly bill the Customer for cathodic protection services provided on the Customer’s pipeline.

In either case an insulation kit(s) will be installed at location. Should cathodic protection be supplied the insulating kit will be jumper - bonded.

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2.2.6 Automation for Remote Shut Down Capability

Where automation is to be installed to enable SemCAMS remote shut down capability of an Acceptance Point, SemCAMS will advise the Customer what equipment will need to be installed to ensure compatibility with existing SemCAMS infrastructure. This will depend on which pipeline system the Acceptance Point is being connected to (refer to the SemCAMS Pipeline Tie-in specifications found in the Appendix).

2.3 Stage 4 – Commissioning and Startup

SemCAMS Pipeline Supervisor will review the Customers commissioning and startup procedures prior online production.

All initial liquid volumes (fractionation fluids, hydro test liquids, batch chemicals etc.) will not be accepted into the SemCAMS pipeline without approval of the SemCAMS Pipeline Supervisor.

All new pipelines will be hydro-tested, cleaned, purged and leak checked.

All ESD controls and automation equipment will be function tested prior to startup.

The Customer will supply P&ID’s, metering schematics, quality control and other documentation as applicable.

During or immediately following this stage, SemCAMS reserves the right to conduct an inspection of the Customer’s Acceptance Point facility. Any major deficiencies identified during the inspection must be corrected by the Customer within the specified time frame. Failure to do so will result in shut in of the Acceptance Point.

2.3.1 Automation for Remote Shut Down Capability

Where automation has been installed to enable SemCAMS remote shut down capability of an Acceptance Point, a SemCAMS representative will be present during commissioning to ensure functionality of the system. SemCAMS commissioning arrangements will be made by the SemCAMS Pipeline Supervisor.

2.4 Stage 5 – Normal Operations

Customer will be responsible for the following during normal operations of the Tie-In Point,

Maintenance of the site in an environmentally conscience way.

Maintenance and operation of their ESD valve and associated equipment.

Installation and monitoring of their corrosion equipment.

Customer and SemCAMS to share corrosion monitoring, cathodic protection and other pertinent data to ensure appropriate management of the Tie-In Point and shared facilities.

Maintain communication with SemCAMS gas control (780-712-5082) with regards to production information, process upsets and emergency conditions.

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3 Measurement Requirements

3.1 Introduction

This section details the Customer measurement requirements for all Acceptance Points entering a system or plant operated by SemCAMS. The standards specified by SemCAMS shall be met for all new facilities. These standards defined meet or exceed regulatory and industry standards. For the purposes of this document the Alberta Energy Regulators (AER) Directive 17, Measurement Requirements for Upstream Oil and Gas Operations will be referred to as AER D-17.

3.2 Design and Installation

3.2.1 General Requirements

The policy requirements to be adhered to are as follows:

All measurement installations and procedures will meet or exceed AER D-17 specifications.

The measurement system should have the capability of providing automated daily volumes to SemCAMS, either via a secure website or via connection to the SemCAMS SCADA system.

Volumes and energy will be reported in SI units to 1 decimal place,

Gas volumes will be calculated at base conditions of 101.325 kPa and 15 °C. Liquid volumes will be calculated at base conditions of zero kPag or the equilibrium vapour pressure (whichever is higher) and 15 °C.

The atmospheric pressure used in the volume calculation shall be based on actual elevation and must be determined by using certified government topographical maps or GPS. The atmospheric pressure is based on the following:

Elevation in meters: 101.325-(0.0113 x elevation) kPa

All fuel and continuous flare volumes that are greater than 500 m3 per day will be metered. Where estimates are used for determining fuel or flare volumes, the methodology including all calculations must be provided to SemCAMS prior to startup and when any changes are made.

Customer will annually provide SemCAMS with a current measurement schematic that meets the requirements set out in AER D-17 Section 1.9. Schematic basics include:

• Measurement points with identification numbers used for accounting (gas meters, liquid meters, storage tanks, separators, compressors, major process equipment).

• Physical sight configuration and flow directions, identification and location of liquids that are recombined with the gas.

• Fuel, flare or vent take-off points with indication of estimated or metered volumes.

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3.2.2 Gas Measurement

Gas measurement at Acceptance Points into a gas gathering system or plant operated by SemCAMS is to be designed and installed according to the following standards. All measurement points shall be continuously and accurately measured or estimated where permitted in AER D-17. Monthly gas and liquid volumes shall be reported to one decimal place. All volumes shall be reported at standard conditions as outlined in AER D-17 Section 4 and Section 3.2 of this document.

3.2.2.1 Meter Specifications

In addition to the requirements set out in AER D-17 the following details highlight specifications for gas and liquid measurement equipment being tied into SemCAMS:

All gas Acceptance Points will require EFM (Electronic Flow Measurement). Chart recorders are not acceptable.

All gas and liquid Acceptance Points must meet the accuracy requirements set out in the AER D-17 Section 1.8.2. for Gas Systems. This is typically 3.0% for well gas and 2.0% for well condensate.

When orifice meter runs are used they should be installed in the vertical position to reduce errors caused by liquid buildup upstream of the orifice plate. See Figure 3.1 of this document.

Meters must be installed as per manufacturer’s recommendation to meet accuracy requirements. Meter must have sufficient unobstructed straight upstream and downstream pipe diameters.

Orifice plate beta ratio, (Orifice plate inside diameter divided by outside diameter) should be maintained within a range of 0.2 to 0.6.

All installations shall be designed so that each sensor will operate at a point greater than 10% of the calibrated span under normal operating conditions.

3.2.2.2 Volume Calculations

The following details the expectations for gas volume calculations:

Shall meet the requirements set out in AER D-17 Section 4.3.2 – “Volumetric Calculations”

Calculation performance evaluations must be conducted as outlined in AER D-17 Section 4.3.6.2 – ‘Performance Evaluation’, results must be sent to SemCAMS. Generally flow calculations are required to fall within +/- 0.25% of a known test case or standalone flow calculation program.

3.2.2.3 Device Installation

Transmitter installation requirements are identified as follows and in Figure 3.1:

All sensing lines should be dedicated and short coupled, recommended one meter (1 m) or less.

All sensing lines will be sloped toward the primary device, the recommended minimum slope is 3 cm per 30 cm of length (1:10 slope).

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The manifold will be a five (5) valve manifold.

The sensing lines should have a minimum nominal diameter of ½ inch.

The main line isolation valves to the manifold will be fully ported with a nominal diameter consistent with the sensing lines.

Temperature transmitters/RTD probes should be installed with flexible armored cable enabling the RTD to be easily removed from the thermowell for calibration procedures.

Figure 3.1 Gas Meter Installation

3.2.2.4 Fuel Gas

For all upstream properties tying into SemCAMS with an annual average fuel gas usage of greater than 0.5 E3M3/day; a meter capable of continuous measurement must be installed. For volumes less than 0.5 E3M3/day an engineering estimate may be used.

All reported fuel gas volumes must be corrected to standard conditions as outlined Section 4.2.1 of this document.

EFM

Capillary Line Signal Line

Electronic Signal

DP 100

P 100

T 100

Blowdown

Meter

Run

Capped isolation valves installed on unused source connections for potential future use.

1/2" stainless steel tubing tubing length = <1 meter slope down from transmitters

to fitting 3 cm per 30 cm length

mount transmitters higher than orifice fitting and on

stand-alone support structure

five valve manifold

1/2" full port ball valves

(typ.)

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3.2.2.5 Gas Sampling

The following details the expectations for gas sample points:

Sample probes shall be installed at each Acceptance Point.

The sample point must be located where a sample representative of the gas flowing through the acceptance point meter can be obtained.

The sample probe shall be installed into the center third of the pipe.

The sample probe should be installed vertically at the top of a straight run of horizontal pipe.

Where the gas is at or near its hydrocarbon dew point, the sample point should be located upstream of the orifice meter run and at least 5 pipe diameters downstream of any flow disturbing elements (such as elbows, tees, valves etc.).

Where the gas is not near its hydrocarbon dew point the sample point can be either upstream or downstream of the meter run and avoidance of flow disturbing devices is less critical.

The sample point should be indoors and not make use of excessive tubing to make sample point accessible.

3.2.3 Liquid Measurement

SemCAMS requires measurement of all liquids recombined with the gas stream at an Acceptance Point and delivered to a SemCAMS plant.

3.2.3.1 Meter Specifications

The following details the specifications for liquid measurement equipment:

Liquid meters will be installed and operated in accordance with AER D-17 requirements and manufacturers specifications.

A strainer will be located upstream of meters that are sensitive to solids/stream particulates.

Where condensate volumes exceed 2 m3/day, proving taps will be installed to allow for inline proving.

3.2.3.2 Volume Calculations

The following details the requirements for liquid volume calculations:

All liquid volumes will be corrected to 15 °C using one of the 3 methods listed below and the applicable temperature compensation method listed in Table ,

• Temperature is measured continuously and CTL (Correction for the effect of Temperature on Liquid) calculated by EFM or;

• Determine a temperature compensated meter factor / k-factor at time of proving by temperature compensating the proving volume or;

• Take temperature reading at time of manual meter reading and apply CTL.

Most hydrocarbon liquids in the gathering system are at or near the equilibrium vapour pressure. Therefore, CPL (Correction for the effect of Pressure on Liquid)

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is not required. Each installation shall be reviewed to determine if CPL is required.

Table 3.1: Standards for Calculating CTL and CPL

Standard Product and Density Range

CTL (Correction for the effect of Temperature on Liquid)

IP Table 54 Light Hydrocarbon Liquids (500.0 – 653.0 kg/m3)

API MPMS 11.1 Crude Oil, Refined Products and Lubricating Oils

(611.6 – 1163.85 kg/m3)

CPL (Correction for the effect of Pressure on Liquid)

API MPMS 12.2.2M Light Hydrocarbon Liquids (350.0 – 637.0 kg/m3)

API MPMS 11.1 Crude Oil, Refined Products and Lubricating Oils

(611.6 – 1163.85 kg/m3)

3.2.3.3 Liquid Sampling

The following details the expectations for liquid sampling:

Sample probes shall be installed at each Acceptance Point.

The sample point must be located where a sample representative of the liquid flowing through the acceptance point meter can be obtained.

The sample probe shall be installed into the center third of the pipe.

The sample probe should be installed horizontally, on the side of a straight run of horizontal pipe.

Sample points must not be located where vapor breakout is likely, such as downstream of pressure reducing components (such as orifice plates, flow conditioners, turbine, PD or Coriolis mass meters, control valves etc.) or where the stream temperature has increased.

For separator applications, the sample point must be located between the separator outlet and the level control valve, upstream of the meter.

3.3 Commissioning and Startup

This section provides the Customer with the details of what information is required and what actions must be complete prior to SemCAMS allowing activation of an Acceptance Point.

3.3.1 Information Required Prior to Startup

The following information must be submitted electronically to the SemCAMS Field Business Development Supervisor (refer to Section 2 of this document) prior to activation of the Acceptance Point:

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Gas and condensate (if condensate recombined with gas) analysis3.

Calibration/inspection forms for the primary meter, secondary and tertiary devices including the orifice plate where applicable.

Process flow diagram (or measurement schematic) of each Acceptance Point.

EFM performance evaluation documentation as per AER D-17. The following method is preferred for EFM performance evaluation: Evaluate the EFM calculation accuracy with a flow checking program. A snapshot of the instantaneous flow parameters and factors, flow rates and configuration information is to be taken from the EFM and input into the checking program. The volumetric flow rate obtained in the snapshot must agree to +0.25% of the flow rate recorded by the flow checking program.

Details of estimations used for fuel gas consumption.

3.3.2 Site Acceptance Inspection

SemCAMS personnel will perform an initial inspection of each Customer’s Acceptance Point prior to commissioning the measurement point. The Customer will be provided a copy of the completed inspection report. Facilities, which do not meet the SemCAMS Acceptance Point specifications, will not be allowed entry into the SemCAMS system until the deficiencies are corrected and the Acceptance Point has been re-inspected.

3.4 Normal Operations

This section provides the Customer with the details of ongoing responsibilities pertaining to measurement at an Acceptance Point.

SemCAMS reserves the right to inspect the Acceptance Point measurement equipment at any reasonable time and with prior notice to the Customer. This is done to ensure general compliance with SemCAMS measurement requirements and to ensure the data being used in our allocation system is current. Where a Customer’s facility is not in compliance with SemCAMS expectations or current regulatory requirements and the non-compliance may result in the miss-allocation of products, SemCAMS will take appropriate actions.

IMPORTANT: Electronic Copies of completed calibration reports, proving reports, EFM Performance Evaluation, and analysis data for all Acceptance Points and Tie-In Points are to be sent to:

SemCAMS Attention: Measurement Integrity Administrator P.O. Box 6328, Edson, Alberta, T7E 1T8 Fax: 780-723-3260 [email protected]

3.4.1 Gas Meter Calibration

SemCAMS expectations pertaining to gas meter calibration are as follows:

3 For effluent measured wells a ‘typical’ analysis can be provided until a well test is completed and individual gas and condensate samples can be taken.

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For group points, provide SemCAMS a schedule for calibration to allow SemCAMS the opportunity to witness calibrations.

Calibration will include validation of signals from transmitters to the flow computation device.

Calibration will include validation of all fixed meter data configured in the device performing the volumetric calculations.

Calibration of Acceptance Point meters is to be performed prior to startup and then at the frequencies listed in Table :

Table 3.2: Calibration Frequency Requirements

Acceptance Point Type Frequency Well Head Every 12 months

Group Acceptance Point (Prorated or Custody) Every 6 months

3.4.2 Meter Proving

SemCAMS expectations pertaining to liquid meter proving are as follows:

For group points, provide SemCAMS a schedule for meter proving to allow SemCAMS the opportunity to witness.

Meter proving to be done in situ unless average daily volume is less than or equal to 2 m3/day.

Proving of Acceptance Point meters is to be performed within 30 days after commissioning and then at the frequencies listed in Table :

Table 3.3: Meter Proving Frequency Requirements

Service Frequency Condensate Every 12 months

Water Every 12 months

3.4.3 Sampling and Analysis

SemCAMS requires accurate analysis data for all production streams to ensure product allocation is accurate and equitable.

SemCAMS expectations of the Customer for ongoing sampling and analysis are as follows:

SemCAMS must receive the required analyses 5 working days before the end of the month the analysis should be effective to allow for internal validation and system transfers.

• SemCAMS has implemented a comprehensive Field Data Capture system (FDC). This system is setup to receive analysis data electronically. SemCAMS

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requires Upstream Operators and/or Upstream Licensees to provide their well and group point analysis data electronically.

• An automated data export in a PGAS compatible formatted file has been developed by several data providers. This transfer of data through a SemCAMS secure ftp server was implemented to improve data flow and data integrity. It is the customer’s responsibility to arrange with their data service provider(s) if approval is required prior to the transfer of analyses to SemCAMS.

• Authorization is required for currently producing wells and group points tied into SemCAMS facilities along with any future well or group point tie-ins where SemCAMS requires compositional analysis for product allocation. Refer to the Authorization for Release of Analyses Data Form.

The gas sampling equipment and procedures must follow the requirements in API MPMS 14.1 (February 2006) and GPA 2166-05.

The hydrocarbon liquid sampling equipment and procedures must follow the requirements in GPA 2174-93 or the evacuated cylinder method referenced in GPA 2166-05.

For gas analysis, if H2S (hydrogen sulfide) is present, an on-site Tutwiler or stain tube test, depending on concentration, shall be conducted to obtain the H2S content,

Where condensate is recombined with the gas, both gas and liquid samples must be taken on the same day and during normal flowing conditions.

Where condensate is recombined with the gas, separate gas and condensate volumes must be provided with the analysis for the purpose of calculating the recombined analysis. Total monthly gas (103m3) and liquid (m3) volumes for the month in which the samples were taken are required.

For effluent metered wells, gas and liquid samples are to be collected during the effluent test. Copies of the lab analysis reports and the completed effluent test results are to be provided to SemCAMS.

Samples are to be analyzed by a recognized third party laboratory.

Gas and liquid must be analyzed to C7+.

SemCAMS will review all supplied analysis to ensure that the following acceptance criteria is met. If the analysis data does not meet the acceptance criteria then the analysis will be rejected and the Customer will be asked to provide new analysis data.

Acceptance Criteria:

• Analysis received within 365 days of the sample date on the analysis report.

• For gas analysis, “as received” pressure of sample must be within 20% of the “as sampled” pressure.

• Must be less than 30 days between “date sampled” and “date reported”.

• For acceptance points that deliver both gas and condensate, gas and condensate analysis along with daily volumes as per AER D-17 Section 4.3.3 item 7 must be received.

• Analysis report includes the full and correct UWI of the well sampled,

• Reports must be legible.

• Must not be rejected by the lab performing the analysis.

• Customer’s responsibility is to ensure SemCAMS receives analyses for all producing wells.

Samples are to be taken at the frequencies provided in Table 3.4:

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Table 3.4: Gas and Condensate Sampling Frequency Requirements

Acceptance Point Type Initial Production Period Ongoing Production Period Well • Within first calendar month of production.

SemCAMS must receive analysis 5

working days prior to month end

• Second sample required after 6 months of production

Note: These initial requirements will also apply to any wells that are recompleted to a different zone, where multiple zones are commingled downhole, or where any other changes occur that would have a significant impact on the well composition.

• As per Regulatory Requirements

Custody Group Allocation Point (CGAP)

• As per Regulatory requirements • Every 30 Days

Prorated Group Allocation Point (PGAP)

• As per Regulatory requirements • Every 30 Days

Flow Splitter • Same as Custody Group Allocation Point • Same as Custody Group Allocation Point

When uncertainty or requirements cannot be met, Customer must consider more frequent sampling, proportional samplers, or chromatographs.

The gas and liquid analysis must be updated when operating conditions are significantly altered (e.g. addition/removal of compression or line-heating, addition/removal of production sources in a common stream, wellbore recompletion

3.4.4 Changes Impacting Measurement and Allocation

Within the course of operations of the Acceptance Point, modifications will be required to the equipment or the data being used to calculate volumes. In most cases it is up to the Customer to ensure adequate records are retained to satisfy regulatory requirements with regard to these changes. SemCAMS needs to be made aware of changes that impact product allocation immediately following the change and in some cases prior to the change being made.

The key areas requiring notification to SemCAMS include:

Modification to condensate handling at site. At Acceptance Points where condensate can be either recombined with the gas or diverted to tank by the operation of a valve, SemCAMS must be advised in advance when this valve will be operated4. The Customer is asked to contact the appropriate Field Business Development Supervisor (as listed in section 2 of this document) when a change is made.

Modification to water handling at site. At Acceptance Points where water can be either recombined with the gas or diverted to tank by the operation of a valve, SemCAMS must be advised in advance when this valve will be operated. The Customer is asked to contact the appropriate Field Business Development Supervisor when a change is made.

3.4.4.1 EFM Information Updates

Although no notification is required to SemCAMS, the following data must be updated in the EFM as required and audit logs retained as per AER D-17.

4 Prior written approval must be in place from time of initial tie-in allowing recombination of liquids.

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Table 3.5: EFM Update Timing

Data Update

Orifice plate size Immediately following change

Transmitter range Immediately following change

Meter/K Factor Immediately following prove

Gas Composition As soon as possible following receipt of analysis

Liquid Density (where EFM is performing CTL and CPL calculations)

As soon as possible following receipt of analysis

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4 Reporting and Allocation Requirements

4.1 Introduction

any different parties can be involved in the movement of natural gas across a particular location. The Common Stream Operator (CSO) of the affected location, using the predetermined allocation methodology agreed to by the parties involved, performs allocations.

As the CSO of the West Whitecourt, Kaybob Amalgamated, West Fox Creek and Kaybob 3 gas plants and many of the associated gathering systems, SemCAMS is responsible for both daily and monthly allocation of sales gas and by-products to Customers. Daily confirmations and allocations are provided by the CSO on an estimated basis throughout the current month. Final month end allocations are provided by the CSO on an accounting basis after the close of the current production month.

It is SemCAMS responsibility to equitably allocate sales products back to the Customer based on the Customer or operator provided Gathered Volumes and Product Stream Analysis. To carry out these tasks effectively, SemCAMS requires accurate and timely production, ownership and Take-In-Kind (TIK) information from the Customers. For this reason, this process applies not only to Acceptance Points but to entities attached upstream of Custody Group Allocation Points.

The Customer is responsible for ensuring all expectations detailed in this document have been met prior to start up and flow of production and the commencement of the allocation process. To ensure the accuracy of daily and monthly allocations, it is imperative that every Customer have the following in place:

Required tie in and measurement conditions as outlined in Section 2. In addition to meeting the operational tie in and measurement needs, the required New Well Form is the base document that activates SemCAMS internal daily and monthly allocation set up. The submission of this document to the SemCAMS Field Business Development Supervisor prior to start up is critical to the success of the daily and monthly allocation process.

Required gathering and processing agreement conditions as outlined in Chapter 1.2.2. It is essential that every Customer have all required gathering and processing agreements in place prior to start up and the commencement of the daily confirmation and allocation process. In the event a Customer has production that is not covered under an appropriate agreement and the required tie in and measurement conditions SemCAMS has the right to bill the Customer directly for any re-work costs associated with the re-allocation of plant sales products.

4.2 Fixed Data Requirements

4.2.1 Working Interest Ownership

Timely working interest ownership notification is required for the allocation process. Ownership change is defined as but not limited to physical Unique Well Identifier (UWI) ownership and corporate (merger, acquisition, amalgamation, corporate structure change) ownership.

There are 2 basic types of working interest ownership data that affect the allocations process:

Legal property ownership as it relates to the actual working interest in a UWI, units, pools or facilities.

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Corporate ownership as it relates to a company’s legal identification.

Correct ownership information must be in place prior to physical flow of the product in order for the data processes to correctly capture that ownership for the daily and monthly allocation process. Ownership of new property’s or changes to the ownership of an existing property can create unique fixed data issues if the ownership information is not received prior to the real time physical flow of the associated product.

Natural gas is allocated and sold on the futures market daily and proper ownership data must be attached to that product before that product can be properly allocated to the Transportation Service Provider (TSP). Timing of the receipt of this information is critical to the CSO. If new or changed working interest ownership is not in place before the product is sold daily, the ownership change is pushed into the month end production accounting process which can result in additional transportation costs and negative market implications due to fluctuating natural gas prices.

Note: New or changed working interest information must be received by SemCAMS Joint Interest Administration/Daily CSO five business days before the start of the physical production month. Any ownership information submitted after the start of the physical production month will not be applied to the daily or monthly allocation process until the 1st day of the following production month.

There is a proactive set-up requirement associated with the daily allocation of the physical product. Working interest information is required for the CSO to ensure all associated downstream requirements are in place prior to the commencement of flow or change in ownership of existing properties. If TSP transportation and sales arrangements are not in place, the daily flowing sales gas product cannot be allocated. Flowing product without timely ownership notice jeopardizes not only the owner’s real time daily allocations but allocations of the entire common stream.

Whether it is a regulatory, TSP or financial, the monthly calculation, shipment and sale of natural gas and associated product are based on the calendar month. In addition, most if not all daily and monthly database systems are not designed to accommodate changes in fixed data within the same calendar month. Proactive ownership notice allows for the proper set up of all daily allocation requirements of real time sale of natural gas and the proper validation and set up in all associated production accounting and financial systems.

Working interest ownership must be provided in writing by all product owners to SemCAMS Joint Interest Administration/Daily CSO.

SemCAMS Joint Interest Administration/Daily CSO will only accept written working interest information from the owner of the product. Notice must be on corporate letterhead (PDF file via email, fax or mail) with the following information:

Full legal name of company - the current ownership environment often has a parent company with many subsidiaries. Different properties are often attached to different subsidiaries.

Corporate contact information – operations, joint venture, marketing and production accounting. Even if the working interest owner of the product does not operate the property, contact information is necessary to fulfill other requirements such as gathering and processing agreements, TIK direction or the need to communicate with the owner for property specific common stream issues.

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Agent – if product owner chooses to appoint a third party to communicate with the CSO, including the authority, without limitation, to provide and receive instruction and notice on all TSP business and contractual matters, product owner must provide written instructions identifying the third party and the limit of their authority.

Product owner is required to provide this instruction via SemCAMS Notice of Agent Agreement Form. SemCAMS will not take direction from an Agent without written notice from the product owner via the Notice of Agent Agreement Form.

Working interest ownership information must correspond to the production accounting identity at the Acceptance Point into SemCAMS systems (UWI, custody group allocation point and prorated group allocation point).

UWI’s - Surface locations no longer suffice as property identifiers for working interest information. Many zones have different working interests therefore all ownership must be reported at the UWI level. The Well Operator must provide property ownership information to SemCAMS in writing.

Any change/addition to a downhole location (interval, event sequence) requires new property ownership documentation regardless of past association with the surface or previous downhole location. SemCAMS cannot and will not “assume” ownership. Producer operator should include this requirement in their discussions with their working interest partners to avoid take-in-kind issues.

Corporate Ownership Change effective dates will be the 1st day of the next physical production month following receipt of the official copy of the “Certificate of Amendment” along with a letter from your company to SemCAMS Joint Interest Administration requesting that all records be changed to reflect the new company name.

Retroactive ownership directions will not be accepted. Whether it is a simple one UWI transaction or a more complex merger/acquisition, natural gas must be allocated, shipped and sold daily per SemCAMS current production month product ownership information. It is physically impossible to retrieve daily allocated, shipped and sold product if new product owner directs a retroactive effective date. In addition, the production accounting amendment process may not be able to comply with the new owners TIK directions if the new owner does not have TSP arrangements in place during the physical production month.

Deferring the physical allocation ownership change to the start of the next production month creates order and gives all parties affected by the merger/acquisition, including the CSO, adequate time to set up the proper processes.

Divesting product owner must maintain all required TSP arrangements until the 1st day of the next physical production month following receipt of the “Certificate of Amendment”.

Natural gas that has flowed and been allocated daily to the previous owners shipper cannot be recalled regardless of what the ownership ‘paper’ says. Previous owners also often remove their transportation contracts before the new owner has shipper arrangements in place. Production must be shut in if the CSO cannot allocate the flowing product to the sales pipeline.

Again, production accounting databases are not designed to split the same product between multiple owners/shippers within the same production month cycle. The allocation process is based on the calendar month and change in ownership must follow that design. Complying with

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this requirement not only makes the data management of the change financially clear, it eliminates unnecessary allocation issues among the entire common stream.

4.2.2 Take-In-Kind (TIK) Directions from Product Owner

The CSO requires instructions from the product owner regarding their contractual arrangements with the TSP in order to properly allocate sales gas to the correct TSP, Shipper and associated Shipper contract. This direction is to include Customers pooled general contract volumes as well as any dedicated or contract specific requirements.

TIK directions must be submitted to the daily CSO and Production Accounting via SemCAMS Notice of Take In Kind Form by the working interest owner of the product. TIK directions will not be accepted from a Shipper or Agent without the corresponding Notice of Agent Agreement Form from the product owner stating the individual or company is authorized to act on their behalf.

TIK directions must be received by the daily CSO five business days before the start of the physical production month. If TIK directions are not received the working interest owner will be deemed as not TIK and their product will be allocated to the well operator for the entire physical production month and subsequent production accounting process.

Nominations

In order for product to be allocated to a sales pipeline, product owner must have transportation arrangements in place via the shipper contract nominations process prior to commencement of flow. The nomination process is the way in which those who want to transport natural gas request space on downstream pipelines. Nominations are notices to TSP of how much gas the Shipper wishes to transport, where the gas will be entering the pipeline system (acceptance point), and where it will be delivered (delivery point).

The North American Gas Industry Standards Board (NAGISB) business practices standards define:

A procedure and timetable for nominating gas on all transportation service providers, ensuring a seamless process for scheduling transportation service throughout North America even when more than one pipeline must be used to get the gas to its destinations.

How and when transportation service providers should respond to Shippers with scheduled quantities, which are agreements on the quantity of gas scheduled to flow,

Confirmations, which the owners and/or operators of the gas transaction points and facilities (SemCAMS Plants) involved in the nomination, send to the transportation service provider to confirm the quantities and dates specified in the nominations.

NAGISB standards specify that a standard gas day which is basically an accounting period that identifies when gas flows begins, as 9 a.m. to 9 a.m., central clock time.

Shipper nominates quantity, receipt and delivery point to TSP,

TSP responds to shipper,

Shipper notifies CSO, receipt of delivery owners,

CSO, receipt or delivery owners confirms to TSP quantities, dates and times.

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SemCAMS is CSO at three plants that are dually connected to Alliance Pipeline (APL) and TransCanada Pipeline (TCPL). As APL rigidly adheres to the NAGISB business standards, K3, KA and WWP plants regularly follow the NAGISB Timely Cycle and ID1 Cycle nomination standards Monday to Friday, excluding stat holidays. Timely Cycle on Friday will be used to set flow rates for Saturday, Sunday and Monday. ID1 Cycle on Monday will be the first cycle to be confirmed after each weekend. Should there be operational issues, the CSO may at their discretion submit ID2. ID3 and/or Evening Cycle.

The CSO (unless they are a product owner with TSP arrangements) cannot nominate gas. Shippers nominate and the CSO responds to the Shipper nomination with a confirmation based on estimated sales for the gas day. SemCAMS requires all producers have Priority 1 nominations with APL or TCPL. SemCAMS also requires all producers have a minimum nomination on APL or TCPL as Priority 2 pipeline provider. This allows the transition of gas during operational impacts.

Timely Nomination (Timely Cycle) – nominations under this cycle will be for the next gas day commencing at 9:00 AM CCT. Shipper nominations must be in before 1:00 PM CCT for gas to be scheduled. Daily CSO must confirm shipper nominations or provide estimated confirmations if CSO sales estimates differ from Shipper nominated volumes by 1:30 PM CCT to complete the cycle process.

Evening Nomination (Evening Cycle) – this cycle can be used to fine-tune the nominations from the Timely nomination cycle. Nominations under this cycle are for the next gas day commencing at 9:00 AM CCT. SemCAMS does not routinely support this cycle unless there is a plant operational justification.

First Intra-day Nomination (ID1 Cycle) – gas scheduled under this cycle is for today’s gas day (same day). Shipper nominations under this cycle are to be submitted by 10:00 AM CCT for an effective time of 2:00 PM CCT. Shipper nominations and/or CSO confirmations under this cycle can be used to correct or change any volumes due to upstream production changes, operational curtailments, increased Authorized Overrun Service (AOS), unexpected outages, etc. CSO must confirm shipper nominations or provide estimated confirmation if CSO sales estimates differ from Shipper nominations by 10:30 PM CCT to complete this cycle.

Second Intra-day Nomination (ID3 Cycle) – this is an additional cycle in which to change nominations for the same gas day. Nominations under this cycle are due by 2:30 PM CCT. CSO must confirm shipper nominations or provide estimated confirmation by 3:00 PM CCT to complete this cycle. SemCAMS does not routinely support this cycle unless there is a plant operational justification.

Third Intra-day Nomination (ID3 Cycle) – this is the last cycle in which to change nominations for the same gas day. Nominations under this cycle are due by 7:00 PM CCT. CSO must confirm shipper nominations or provide estimated confirmation by 7:30 PM CCT to complete this cycle. SemCAMS does not routinely support this cycle unless there is a plant operational justification.

4.3 Daily Confirmation and Allocation Process

As the CSO, it is SemCAMS responsibility to equitably allocate sales products back to the Customer based on the Customer working interest, gathered volumes, product stream analysis and TIK directions. SemCAMS performs this role in two capacities; daily and monthly.

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The daily allocation process involves the forecasting (confirmation) and allocation of sales gas back to Customer provided Gathered Volumes in accordance with their shipper nominations on a daily basis. SemCAMS provides this service on behalf of each Customer in order to comply with their daily sales contract obligations.

The daily Gathered Volumes provided by the Customer are used by the CSO for two purposes:

As an estimate to calculate each Customer forecasted sales volumes for the next day’s sales pipeline confirmations. For the purpose of calculating an estimated sales volume, the CSO applies an estimated shrinkage (calculated by well/entity from the two month’s previous monthly allocation process) to the gathered volume provided by the Customer.

As an actual to revise the forecast made on the previous day (APL only).

Refer to Table 4.2 for a visual example of this process.

Month to date cumulative balancing is done throughout the physical production month for Customers. This is accomplished by continually refreshing the 1-31 day revised sales estimates, comparing sales estimates to the previously scheduled sales pipeline volumes and adjusting forward day confirmations to reduce month to date cumulative shipper differentials.

Note: It is imperative that all parties understand that sales gas volumes are allocated on a daily basis to meet the needs of the Customers sales pipeline contractual obligations. To effectively perform this task, SemCAMS requires accurate and representative gathered volumes (by owner/entity) in a timely manner, on a daily basis.

4.4 Daily Volumetric Reporting – Data Requirements

Acting as the CSO, SemCAMS requires daily volumetric reporting for each acceptance point on a daily basis. It is the responsibility of the Customer to provide the volume data requested via web based reporting, email or fax. As the daily reporting needs vary with the type of acceptance point, the expectations for each are outlined below:

Type of Receipt Point Daily Data Expectations Measured Well Head/UWI Gathered volume for previous day on a daily basis by 11:00 local

Alberta time to daily CSO at processing plant.

Daily CSO will not confirm or allocate sales volumes for new production until the operator provides a gathered volume report with hours online.

Requires advance notification for future change in ownership, working interest, dedication, special marketing arrangement or shipper driven change five business days prior to the start of the physical production month.

Prorated Group Allocation Point Gathered Volume for previous day by well/UWI on a daily basis by 11:00 local Alberta time to daily CSO at processing plant.

Daily CSO will not confirm or allocate sales volumes for new production until the operator provides a gathered volume report with hours online.

Require advance notification for future change in ownership, working interest, dedication, special marketing arrangement or shipper driven change five business days prior to the start of the

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physical production month.

Custody Group Allocation Point Gathered Volume for previous day by owner / working interest and by customer driven marketing arrangement on a daily basis by 11:00 local Alberta time to daily CSO at processing plant.

Daily reports to be up to date with regard to owner / working interest and by any Customer driven special TSP contractual arrangements.

Daily CSO will not confirm or allocate sales volumes for new production until the operator provides a gathered volume report with hours online.

Operator reported gathered and sales estimates vs. actual must be with +/- 3%.

Require advance notification for future change in ownership, working interest, dedication, special marketing arrangement or shipper driven change five business days prior to the start of the physical production month.

4.5 Scheduled or Unscheduled Plant to Plant Reroute Process

Due to the temporary nature of the reroutes, certain processes need to be defined in order for the sales gas and product to be properly allocated to the Customer at the both plants:

TSP arrangements must be in place on APL or TCPL at the receiving plant in order for the CSO to allocate sales gas to the sales pipeline. The TSP will not accept nominations at a meter station after the physical production month has closed therefore the CSO cannot comply with the product owners TIK directions daily or via the production accounting month end process if transportation is not in place at the receiving plant.

If working interest owner TIK arrangements are not in place at the receiving plant prior to the commencement of the rerouted flows, the CSO will allocate their share of sales gas and product to the operator at the acceptance point into SemCAMS system for the remainder of the reroute/production month in the daily and monthly allocation process.

Working interest owners of re-route volumes must provide written working interests per production identifier and TIK directions to SemCAMS Joint Interest Admin/Daily CSO of the receiving plant prior to the start of the re-route.

Reroute operator will report daily gathered volumes to the originating or “home” plant and SemCAMS will be responsible for ensuring the reroute plant daily CSO receives the gathered data for the daily allocation process. Both plant daily CSO’s will co-ordinate and calculate and record all operator reported rerouted gathered data (including first and last day reroute gathered volumes) for daily and monthly allocation purposes.

Customer production accounting will provide reroute gathered volumes at both plants to SemCAMS production accounting for month end allocations. The final month end Customer submitted month end production accounting identifier gathered volumes for each plant must remain within +/- 3% of the gathered volumes used in the daily allocation process.

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The following information provides a verbal description of terms used and what is presented in Table 4.1:

Note: In the example in Table 4.1, the end of the 4th production day has taken place and the 5th production day is just beginning.

Production Day (PD) – represents the physical gas day, the 2nd PD ends on the morning of the 3rd calendar day (at the Customers “day end” time – “day end” time should be set to 09:00 CCT to correspond with industry standards).

Gathered Volume – from Customer, represents volume for the production day after it has ended. This is considered an actual for the PD.

Forecasted Sales Volume – by daily CSO, gathered volume from previous production day adjusted for shrinkage (in this example 30% shrinkage estimated based on two months previous actual) is used to estimate (confirm) the sales volume for the next day. i.e. Confirmed Sales Volume for the 3rd PD is based on Gathered Volume for 2nd PD – Refer to solid arrows.

Allocated Sales Volume – by daily CSO, gathered volume for completed PD are adjusted for shrinkage (see description above) and prorated to total actual sales for that PD. This value effectively overwrites the Confirmed Sales Volume for the completed PD but is shown separately for clarity. i.e. Allocated Sales Volume for the 4th PD is based on Gathered Volume for the 4th PD – Refer to dotted arrows.

Table 4.1: Daily Allocation Process - Example

Production Day (PD) 2 3 4 5

Gathered Volume (e3m3) 120 110 205 Future6

Forecasted Sales Volume (e3m3) N/A7 84

(120 x 0.7)

77

(110 x 0.7) 05

Allocated Sales Volume (e3m3) N/A7

71

(110 x 0.7 then prorated to total sales for day)

12

(20 x 0.7 then prorated to total

sales for day)

Future6

4.6 Monthly Allocation Process

The monthly allocation process involves the allocation of all plant sales products, inventories and shrinkages to each Acceptance Point on a molecular basis using the month end actual Gathered Volumes as provided by the Customer. Because this process is being done on a molecular level it is imperative that the Customer provide up to date and representative component analysis data for each Acceptance Point. Refer to Section 2 of the Operator Specification Manual for sampling requirements.

The allocation for each facility is completed per the latest accepted version of the CO&O agreement for the applicable facility. In general, the monthly allocation takes place in two steps: Acceptance Points adjusted to plant inlets then sales to adjusted Acceptance Points.

5 Receipt point went down early in day of 4th PD – will be down for 2 days for maintenance. Forecasted Sales Volume for the 5th PD adjusted to 0 e3m3 based on this knowledge. 6 Volume cannot be determined until completion of 5th PD. 7 Volumes for the 2nd PD are omitted as they are not required in this example.

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Monthly Allocation – Data Requirements

To perform the monthly allocation of sales products accurately, SemCAMS requires month end volumetric data that has been validated by the Customer prior to submission. It is the responsibility of the Customer to provide a Gathered Volume for each Acceptance Point by noon on the fourth working day of the month following. Any cost associated with rework required as a result of the use of the daily volumes will be borne by the Customer(s) that did not provide month end actual volumes.

4.7 AER Volumetric Reporting

AER volumetric reporting data provided by the Customer will typically also be used for sales product component allocation at month end. It is the responsibility of the Customer to ensure AER volumetric data is accurate and reported appropriately. SemCAMS reserves the right to audit producer reporting practices to ensure current AER guidelines and expectations are met (i.e. the proration of production to effluent wells). SemCAMS will take all appropriate measures to ensure Customer reporting practices do not cause incorrect allocation of products within a given gathering system. Where an audit or review is performed on a Customer measurement facility and / or Customer reporting practice and timely resolution of the issues is not forthcoming, SemCAMS will seek the involvement of the AER.

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Appendix 1:

K3 GAS GATHERING SYSTEM

SPECIFICATIONS

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A. KBS-110 NORTH WEST WAPITI PIPELINE

GENERAL DESCRIPTION

The North West Wapiti Pipeline is an 8” pipeline which transports High Pressure Dry Sour Gas 50 Kilometers from 15-09-069-09W6 to the Gold Creek Compressor Station located at 11-26-067-05W6. ESD Valve Stations and Tie-in points are installed along the length at several locations.

PIPELINE SPECIFICATIONS:

PIPELINE STATIC DATA

Pipeline Substance High Pressure Dehydrated Sour Gas

Pipeline License # 35136 Line 3 License H2S 30 %

Pipeline Diameter 8” (219.1mm) Pipeline Length 49.6 km

Maximum Operating Pres. 14,600 kPag Normal Operating Pres. 8700 – 12,500 kPag

ANSI Rating 900 RTJ

TIE-IN / ESD LOCATIONS

STN 00 15-09-069-09W6 ESD Valve Station

STN 01 16-35-068-09W6 ESD Valve Station

STN 02 12-30-068-08W6 ESD Valve Station

STN 03 05-20-068-08W6 ESD Valve Station

STN 04 08-22-068-08W6 ESD Valve Station

STN 05 15-07-068-07W6 ESD Valve Station

STN 06 02-03-068-07W6 ESD Valve Station

STN 07 16-31-067-06W6 ESD Valve Station

STN 08 05-02-068-06W6 ESD Valve Station

STN 09 05-06-068-05W6 ESD Valve Station

STN 10 16-32-067-05W6 ESD Valve Station

STN 11 08-33-067-05W6 ESD Valve Station

STN 12 11-26-067-05W6 ESD Valve Station

FACILITY AND PIPELINE TIE-IN SPECIFICATIONS:

1: FACILITY REQUIREMENTS

Dehydration REQUIRED

Dewpoint Monitoring REQUIRED

Condensate BS&W Monitoring NONE

SCADA Monitoring REQUIRED

1.1: FACILITY CONTROL AND MEASUREMENT REQUIREMENTS

Dehydration Glycol / Mole Sieve

Maximum Sales Gas Temperature 50°C

Dewpoint Continues Monitoring Shut-in -10°C

BS&W Continues Monitoring Shut-in/Diversion N/A

Metering – Gas Production EFM

Metering – Condensate Production N/A

Metering – Fuel Gas (site supplied) EFM Metered or Estimate

Metering – Fuel Gas (external ) NOT REQUIRED

2: PIPELINE TIE-IN REQUIREMENTS

ESD Valve REQUIRED

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Check Valve REQUIRED Insulating Kit REQUIRED Future Connection REQUIRED Corrosion Monitoring Coupon REQUIRED Corrosion Inhibitor Injection REQUIRED

Type Baker Hughes CGW 4048

Methanol NONE

Sulphur Dispersants - Solvents NONE

Operational Liquids NONE (Solvents / Frac. Fluids / PL Initial Batch / …)

Operational Gasses NONE (N2 / CO2 / Air / … )

Water NONE

2.2: PIPELINE TIE-IN CONTROL AND MEASUREMENT REQUIREMENTS

Pressure Monitoring REQUIRED ESD Valve Position REQUIRED Remote ESD REQUIRED ESD – Local PSHH (High Pressure Shutdown Device) REQUIRED ESD – Local PSLL (Low Pressure Shutdown Device) REQUIRED

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B. KBS-116 NORTH WEST WAPITI LOOP PIPELINE

GENERAL DESCRIPTION

The North West Wapiti Loop Pipeline is an 8” pipeline which transports High Pressure Dry Sour Gas 35 Kilometers from 01-22-068-08W6 to 11-26-067-05W6. ESD Valve Stations and Tie-in points are installed along the length at several locations.

PIPELINE SPECIFICATIONS:

PIPELINE STATIC DATA

Pipeline Substance High Pressure Dehydrated Sour Gas

Pipeline License # 35136 Line 7 License H2S 30 %

Pipeline Diameter 8” (219.1mm) Pipeline Length 35.452 km

Maximum Operating Pres. 14,600 kPag Normal Operating Pres. 10,000 – 12,800 kPag

ANSI Rating 900 RTJ

TIE-IN / ESD LOCATIONS

STN 01 01-22-068-08W6 ESD Valve Station – North West Wapiti Interconnect

STN 02 16-07-068-07W6 ESD Valve Station

STN 03 02-03-068-07W6 ESD Valve Station

STN 04 16-31-067-06W6 ESD Valve Station

STN 05 04-02-068-06W6 ESD Valve Station

STN 06 05-06-068-05W6 ESD Valve Station

STN 07 10-32-067-05W6 ESD Valve Station

STN 08 12-26-067-05W6 ESD Valve Station

FACILITY AND PIPELINE TIE-IN SPECIFICATIONS:

1: FACILITY REQUIREMENTS

Dehydration REQUIRED

Dewpoint Monitoring REQUIRED

Condensate BS&W Monitoring NONE

SCADA Monitoring REQUIRED

1.1: FACILITY CONTROL AND MEASUREMENT REQUIREMENTS

Dehydration Glycol / Mole Sieve

Maximum Sales Gas Temperature 50°C

Dewpoint Continues Monitoring Shut-in -10°C

BS&W Continues Monitoring Shut-in/Diversion N/A

Metering – Gas Production EFM

Metering – Condensate Production N/A

Metering – Fuel Gas (site supplied) EFM Metered or Estimate

Metering – Fuel Gas (external ) NOT REQUIRED

2: PIPELINE TIE-IN REQUIREMENTS

ESD Valve REQUIRED Check Valve REQUIRED Insulating Kit REQUIRED Future Connection REQUIRED Corrosion Monitoring Coupon REQUIRED Corrosion Inhibitor Injection REQUIRED

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Type Baker Hughes CGW 4048

Methanol NONE

Sulphur Dispersants - Solvents NONE

Operational Liquids NONE (Solvents / Frac. Fluids / PL Initial Batch / …)

Operational Gasses NONE (N2 / CO2 / Air / … )

Water NONE

2.2: PIPELINE TIE-IN CONTROL AND MEASUREMENT REQUIREMENTS

Pressure Monitoring REQUIRED ESD Valve Position REQUIRED Remote ESD REQUIRED ESD – Local PSHH (High Pressure Shutdown Device) REQUIRED ESD – Local PSLL (Low Pressure Shutdown Device) REQUIRED

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C. KBS-120 WAPITI PIPELINE

GENERAL DESCRIPTION

The Wapiti Pipeline is a 12” pipeline which transports High Pressure Dry Sour Gas 68.4 Kilometers from 11-26-067-05W6 to the Simonette Pipeline 12-16-064-26W6 then to the SemCAMS K3 Gas Processing Plant located at 03-15-59-18W5. ESD Valve Stations and Tie-in points are installed along the length at several locations.

PIPELINE SPECIFICATIONS:

PIPELINE STATIC DATA

Pipeline Substance High Pressure Dehydrated Sour Gas

Pipeline License # 35136 Line 1 & 2 License H2S 30 %

Pipeline Diameter 12” (323.9mm) Pipeline Length 68.4 km

Maximum Operating Pres. 14,600 kPag Normal Operating Pres. 10,000 – 12,800 kPag

ANSI Rating 900 RTJ

TIE-IN / ESD LOCATIONS

STN 01 11-26-067-05W6 ESD Valve Station

STN 02 07-23-067-05W6 ESD Valve Station

STN 03 01-14-067-05W6 ESD Valve Station

STN 04 03-07-067-04W6 ESD Valve Station

STN 05 13-20-066-04W6 ESD Valve Station

STN 05A 11-21-066-04W6 ESD Valve Station

STN 06 01-07-066-03W6 ESD Valve Station

STN 617 05-34-065-03W6 ESD Valve Station

STN 07 09-30-065-02W6 ESD Valve Station

STN 08 05-01-065-02W6 ESD Valve Station

STN 09 04-25-064-01W6 ESD Valve Station

STN 10 16-17-064-26W5 ESD Valve Station – Transition to Simonette Pipeline

FACILITY AND PIPELINE TIE-IN SPECIFICATIONS:

1: FACILITY REQUIREMENTS

Dehydration REQUIRED

Dewpoint Monitoring REQUIRED

Condensate BS&W Monitoring NONE

SCADA Monitoring REQUIRED

1.1: FACILITY CONTROL AND MEASUREMENT REQUIREMENTS

Dehydration Glycol / Mole Sieve

Maximum Sales Gas Temperature 50°C

Dewpoint Continues Monitoring Shut-in -10°C

BS&W Continues Monitoring Shut-in/Diversion N/A

Metering – Gas Production EFM

Metering – Condensate Production N/A

Metering – Fuel Gas (site supplied) EFM Metered or Estimate

Metering – Fuel Gas (external ) NOT REQUIRED

2: PIPELINE TIE-IN REQUIREMENTS

ESD Valve REQUIRED Check Valve REQUIRED

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Insulating Kit REQUIRED Future Connection REQUIRED Corrosion Monitoring Coupon REQUIRED Corrosion Inhibitor Injection REQUIRED

Type Baker Hughes CGW 4048

Methanol NONE

Sulphur Dispersants - Solvents NONE

Operational Liquids NONE (Solvents / Frac. Fluids / PL Initial Batch / …)

Operational Gasses NONE (N2 / CO2 / Air / … )

Water NONE

2.2: PIPELINE TIE-IN CONTROL AND MEASUREMENT REQUIREMENTS

Pressure Monitoring REQUIRED ESD Valve Position REQUIRED Remote ESD REQUIRED ESD – Local PSHH (High Pressure Shutdown Device) REQUIRED ESD – Local PSLL (Low Pressure Shutdown Device) REQUIRED

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D. KBS-130 SIMONETTE PIPELINE

GENERAL DESCRIPTION

The Simonette Pipeline is a 12” pipeline which transports High Pressure Dry Sour Gas 114 Kilometers from 16-17-64-26W5 to the SemCAMS K3 Gas Processing Plant located at 03-15-59-18W5. ESD Valve Stations and Tie-in points are installed along the length at several locations. Interconnection with other pipeline systems and processing plants are utilized to re-route gas from one system / plant to another as required.

PIPELINE SPECIFICATIONS:

PIPELINE STATIC DATA

Pipeline Substance High Pressure Dehydrated Sour Gas

Pipeline License # 28053 Line 3, 37823 Line 1 License H2S 30 %

Pipeline Diameter 12” (323.9mm) Pipeline Length 114 km

Maximum Operating Pres. 14,600 / 12,600 kPag Normal Operating Pres. 7200 – 12,800 kPag

ANSI Rating 900 RTJ

TIE-IN / ESD LOCATIONS

STN 1 16-17-064-26W5 ESD Valve Station

STN 112 03-02-064-26W5 Full Encirclement Saddle – Tapped

STN 2 03-17-063-25W5 ESD Valve Station

STN 213 07-08-063-25W5 Full Encirclement Saddle – Tapped

STN 3 11-20-062-24W5 ESD Valve Station

STN 4 02-26-061-24W5 ESD Valve Station

STN 415 16-16-061-23W5 Full Encirclement Saddle – Untapped

STN 5 15-05-061-22W5 ESD Valve Station

STN 6 11-17-060-21W5 ESD Valve Station

STN 617 12-25-059-21W5 Full Encirclement Saddle – Untapped

STN 7 10-13-059-21W5 ESD Valve Station – Greenbank Interconnect

STN 8 14-04-059-19W5 ESD Valve Station

STN 9 03-15-059-18W5 ESD Valve Station

FACILITY AND PIPELINE TIE-IN SPECIFICATIONS:

1: FACILITY REQUIREMENTS

Dehydration REQUIRED

Dewpoint Monitoring REQUIRED

Condensate BS&W Monitoring NONE

SCADA Monitoring REQUIRED

1.1: FACILITY CONTROL AND MEASUREMENT REQUIREMENTS

Dehydration Glycol / Mole Sieve

Maximum Sales Gas Temperature 50°C

Dewpoint Continues Monitoring Shut-in -10°C

BS&W Continues Monitoring Shut-in/Diversion N/A

Metering – Gas Production EFM

Metering – Condensate Production N/A

Metering – Fuel Gas (site supplied) EFM Metered or Estimate

Metering – Fuel Gas (external ) NOT REQUIRED

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2: PIPELINE TIE-IN REQUIREMENTS

ESD Valve REQUIRED Check Valve REQUIRED Insulating Kit REQUIRED Future Connection REQUIRED Corrosion Monitoring Coupon REQUIRED Corrosion Inhibitor Injection REQUIRED

Type Baker Hughes CGW 4048

Methanol NONE

Sulphur Dispersants - Solvents NONE

Operational Liquids NONE (Solvents / Frac. Fluids / PL Initial Batch / …)

Operational Gasses NONE (N2 / CO2 / Air / … )

Water NONE

2.2: PIPELINE TIE-IN CONTROL AND MEASUREMENT REQUIREMENTS

Pressure Monitoring REQUIRED ESD Valve Position REQUIRED Remote ESD REQUIRED ESD – Local PSHH (High Pressure Shutdown Device) REQUIRED ESD – Local PSLL (Low Pressure Shutdown Device) REQUIRED

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E. KBS-140 KAYBOB WEST PIPELINE

GENERAL DESCRIPTION

The Kaybob West Pipeline is a 12” Pipeline which transports High Pressure Dry Sour Gas 67 Kilometers from 07-16-59-35W5 to the SemCAMS K3 Gas Processing Plant located at 03-15-59-18W5. ESD Valve Stations and Tie-in points are installed along the length at several locations. Interconnection with other pipeline systems and processing plants are utilized to re-route gas from one system / plant to another as required.

PIPELINE SPECIFICATIONS:

PIPELINE STATIC DATA

Pipeline Substance High Pressure Dehydrated Sour Gas

Pipeline License # 28053 Line 1 License H2S 30 %

Pipeline Diameter 12” (323.9mm) Pipeline Length 67 km

Maximum Operating Pres. 12,600 kPag Normal Operating Pres. 7200 – 8500 kPag

ANSI Rating 900 RTJ

TIE-IN / ESD LOCATIONS

STN 1 07-16-059-24 ESD Valve Station

STN 2 16-18-059-23 ESD Valve Station

STN 223 14-17-059-22W5 ESD Valve Station

STN 3 11-14-059-22 ESD Valve Station

STN 314 09-18-059-22 Full Encirclement Saddle – Tapped

STN 4 10-13-059-21 ESD Valve Station – Interconnect (Simonette/Spotter)

STN 415 10-18-059-20 Full Encirclement Saddle – Tapped

STN 425 16-09-059-20 Full Encirclement Saddle – Untapped

STN 5 14-04-059-19 ESD Valve Station

STN 6 03-15-059-18 ESD Valve Station

FACILITY AND PIPELINE TIE-IN SPECIFICATIONS:

1: FACILITY REQUIREMENTS

Dehydration REQUIRED

Dewpoint Monitoring REQUIRED

Condensate BS&W Monitoring REQUIRED

SCADA Monitoring REQUIRED

1.1: FACILITY CONTROL AND MEASUREMENT REQUIREMENTS

Dehydration Glycol / Mole Sieve

Maximum Sales Gas Temperature 50°C

Dewpoint Continues Monitoring Shut-in -10°C

BS&W Continues Monitoring Shut-in/Diversion TBD (Requires review)

Metering – Gas Production EFM

Metering – Condensate Production EFM

Metering – Fuel Gas (site supplied) EFM Metered or Estimate

Metering – Fuel Gas (external ) NOT REQUIRED

2: PIPELINE TIE-IN REQUIREMENTS

ESD Valve REQUIRED Check Valve REQUIRED

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Insulating Kit REQUIRED Future Connection REQUIRED Corrosion Monitoring Coupon REQUIRED Corrosion Inhibitor Injection REQUIRED

Type Baker Hughes CGW 4048

Methanol NONE

Sulphur Dispersants - Solvents NONE

Operational Liquids NONE (Solvents / Frac. Fluids / PL Initial Batch / …)

Operational Gasses NONE (N2 / CO2 / Air / … )

Water NONE

2.2: PIPELINE TIE-IN CONTROL AND MEASUREMENT REQUIREMENTS

Pressure Monitoring REQUIRED ESD Valve Position REQUIRED Remote ESD REQUIRED ESD – Local PSHH (High Pressure Shutdown Device) REQUIRED ESD – Local PSLL (Low Pressure Shutdown Device) REQUIRED

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F. KBS-150 FIR PIPELINE

GENERAL DESCRIPTION

The Fir Pipeline is a 10” pipeline which transports High Pressure Dry Sour Gas 42 Kilometers from 15-32-58-21W5 to the SemCAMS K3 Gas Processing Plant located at 03-15-59-18W5. Isolation Valve Stations and Tie-in points are installed along the length at several locations. Interconnection with other pipeline systems and processing plants are utilized to re-route gas from one system / plant to another as required.

PIPELINE SPECIFICATIONS:

PIPELINE STATIC DATA

Pipeline Substance High Pressure Dehydrated Sour Gas

Pipeline License # 11706 Line 1,2,3 License H2S 3 %

Pipeline Diameter 10” (273.1mm) Pipeline Length 42 km

Maximum Operating Pres. 11,840 kPag Normal Operating Pres. 7200 – 8000 kPag

ANSI Rating 900 RTJ

TIE-IN / ESD LOCATIONS

STN 0 15-32-58-21W5 Manual Block Valve

STN 1 01-01-59-21W5 Manual Block Valve

STN 112 06-05-59-20W5 Full Encirclement Saddle – Tapped & Fir-Spotter Interconnect

STN 2 03-12-59-20W5 Manual Block Valve

STN 3 12-03-59-19W5 ESD Valve Station – Athabasca River West

STN 4 10-03-59-19W5 ESD Valve Station – Athabasca River East

STN 5 04-15-59-18W5 Manual Block Valve

FACILITY AND PIPELINE TIE-IN SPECIFICATIONS:

1: FACILITY REQUIREMENTS

Dehydration REQUIRED

Dewpoint Monitoring REQUIRED

Condensate BS&W Monitoring REQUIRED

SCADA Monitoring REQUIRED

1.1: FACILITY CONTROL AND MEASUREMENT REQUIREMENTS

Dehydration Glycol / Mole Sieve

Maximum Sales Gas Temperature 50°C

Dewpoint Continues Monitoring Shut-in -10°C

BS&W Continues Monitoring Shut-in/Diversion TBD (Requires review)

Metering – Gas Production EFM

Metering – Condensate Production EFM

Metering – Fuel Gas (site supplied) EFM Metered or Estimate

Metering – Fuel Gas (external ) NOT REQUIRED

2: PIPELINE TIE-IN REQUIREMENTS

ESD Valve REQUIRED Check Valve REQUIRED Insulating Kit REQUIRED Future Connection REQUIRED Corrosion Monitoring Coupon REQUIRED

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Corrosion Inhibitor Injection REQUIRED

Type NALCO Champion R-2378

Methanol NONE

Sulphur Dispersants - Solvents NONE

Operational Liquids NONE (Solvents / Frac. Fluids / PL Initial Batch / …)

Operational Gasses NONE (N2 / CO2 / Air / … )

Water NONE

2.2: PIPELINE TIE-IN CONTROL AND MEASUREMENT REQUIREMENTS

Pressure Monitoring REQUIRED ESD Valve Position REQUIRED Remote ESD REQUIRED ESD – Local PSHH (High Pressure Shutdown Device) REQUIRED ESD – Local PSLL (Low Pressure Shutdown Device) REQUIRED

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G. KBS-160/161 GREGG LAKES PIPELINE

GENERAL DESCRIPTION

The Gregg Lakes Pipeline is an 8”/10” pipeline which transports High Pressure Dry Sour Gas 65 Km from 13-12-053-01W6 to the Obed 12” pipeline at 05-31-054-22W5 then to the SemCAMS K3 Gas Processing Plant located at 03-15-059-18W5. ESD Valve Stations and Tie-in points are installed along the length at several locations.

PIPELINE SPECIFICATIONS:

PIPELINE STATIC DATA

Pipeline Substance High Pressure Dehydrated Sour Gas

Pipeline License # 32989 Line 1 48765 Line 1,2 32990 Line 1

License H2S 24 %

Pipeline Diameter 8’’(219.1mm) 10”(273.1mm) Pipeline Length 64.8 km

Maximum Operating Pres. 13,800 kPag Normal Operating Pres. 8000 – 9800 kPag

ANSI Rating 900 RTJ

TIE-IN / ESD LOCATIONS

STN 01 13-12-053-01W6 ESD Valve Station

STN 02 09-06-054-26W5 ESD Valve Station

STN 213 12-05-054-26W5 Full Encirclement Saddle – Tapped

STN 223 03-04-054-26W5 Full Encirclement Saddle – Tapped

STN 03 01-05-054-26W5 ESD Valve Station

STN 04 10-34-053-26W5 ESD Valve Station

STN 05 07-35-053-26W5 ESD Valve Station

STN 06 04-31-053-25W5 ESD Valve Station – 8” To 10” Transition

STN 617 15-11-054-25W5 Full Encirclement Saddle – Untapped

STN 07 16-10-054-24W5 ESD Valve Station

STN 08 05-31-054-22W5 ESD Valve Station

FACILITY AND PIPELINE TIE-IN SPECIFICATIONS:

1: FACILITY REQUIREMENTS

Dehydration REQUIRED

Dewpoint Monitoring REQUIRED

Condensate BS&W Monitoring REQUIRED

SCADA Monitoring REQUIRED

1.1: FACILITY CONTROL AND MEASUREMENT REQUIREMENTS

Dehydration Glycol / Mole Sieve

Maximum Sales Gas Temperature 50°C

Dewpoint Continues Monitoring Shut-in -10°C

BS&W Continues Monitoring Shut-in/Diversion TBD (Requires review)

Metering – Gas Production EFM

Metering – Condensate Production EFM

Metering – Fuel Gas (site supplied) EFM Metered or Estimate

Metering – Fuel Gas (external ) NOT REQUIRED

2: PIPELINE TIE-IN REQUIREMENTS

ESD Valve REQUIRED

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Check Valve REQUIRED Insulating Kit REQUIRED Future Connection REQUIRED Corrosion Monitoring Coupon REQUIRED Corrosion Inhibitor Injection REQUIRED

Type Baker Hughes CGW 4048

Methanol NONE

Sulphur Dispersants - Solvents NONE

Operational Liquids NONE (Solvents / Frac. Fluids / PL Initial Batch / …)

Operational Gasses NONE (N2 / CO2 / Air / … )

Water NONE

2.2: PIPELINE TIE-IN CONTROL AND MEASUREMENT REQUIREMENTS

Pressure Monitoring REQUIRED ESD Valve Position REQUIRED Remote ESD REQUIRED ESD – Local PSHH (High Pressure Shutdown Device) REQUIRED ESD – Local PSLL (Low Pressure Shutdown Device) REQUIRED

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H. KBS-170 TOWER CREEK PIPELINE

GENERAL DESCRIPTION

The Tower Creek Pipeline is a 8” pipeline which transports High Pressure Dry Sour Gas 17 Km from 15-15-55-27W5 to the Gregg Lakes 8” pipeline at 09-06-054-26W5 then to the SemCAMS K3 Gas Processing Plant located at 03-15-059-18W5. ESD Valve Stations and Tie-in points are installed along the length at several locations.

PIPELINE SPECIFICATIONS:

PIPELINE STATIC DATA

Pipeline Substance High Pressure Dehydrated Sour Gas

Pipeline License # 48765 Line 1 License H2S 24 %

Pipeline Diameter 8’’(219.1mm) Pipeline Length 16.99 km

Maximum Operating Pres. 13,800 kPag Normal Operating Pres. 8000 – 9800 kPag

ANSI Rating 900 RTJ

TIE-IN / ESD LOCATIONS

STN 01 15-15-055-27W5 ESD Valve Station

STN 02 08-33-054-27W5 ESD Valve Station

STN 03 15-14-054-27W5 ESD Valve Station

STN 04 01-13-054-27W5 ESD Valve Station

STN 05 09-06-054-26W5 ESD Valve Station – ‘Y’ Lateral Tie-in to Gregg Lakes Pipeline

FACILITY AND PIPELINE TIE-IN SPECIFICATIONS:

1: FACILITY REQUIREMENTS

Dehydration REQUIRED

Dewpoint Monitoring REQUIRED

Condensate BS&W Monitoring REQUIRED

SCADA Monitoring REQUIRED

1.1: FACILITY CONTROL AND MEASUREMENT REQUIREMENTS

Dehydration Glycol / Mole Sieve

Maximum Sales Gas Temperature 50°C

Dewpoint Continues Monitoring Shut-in -10°C

BS&W Continues Monitoring Shut-in/Diversion TBD (Requires review)

Metering – Gas Production EFM

Metering – Condensate Production EFM

Metering – Fuel Gas (site supplied) EFM Metered or Estimate

Metering – Fuel Gas (external ) NOT REQUIRED

2: PIPELINE TIE-IN REQUIREMENTS

ESD Valve REQUIRED Check Valve REQUIRED Insulating Kit REQUIRED Future Connection REQUIRED Corrosion Monitoring Coupon REQUIRED Corrosion Inhibitor Injection REQUIRED

Type Baker Hughes CGW 4048

Methanol NONE

Sulphur Dispersants - Solvents NONE

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Operational Liquids NONE (Solvents / Frac. Fluids / PL Initial Batch / …)

Operational Gasses NONE (N2 / CO2 / Air / … )

Water NONE

2.2: PIPELINE TIE-IN CONTROL AND MEASUREMENT REQUIREMENTS

Pressure Monitoring REQUIRED ESD Valve Position REQUIRED Remote ESD REQUIRED ESD – Local PSHH (High Pressure Shutdown Device) REQUIRED ESD – Local PSLL (Low Pressure Shutdown Device) REQUIRED

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I. KBS-180 OBED PIPELINE

GENERAL DESCRIPTION

The Obed Pipeline is a 12” pipeline which transports High Pressure Dry Sour Gas 72 Km from 05-31-054-22W5 to the SemCAMS K3 Gas Processing Plant located at 03-15-059-18W5. ESD Valve Stations and Tie-in points are installed along the length at several locations.

PIPELINE SPECIFICATIONS:

PIPELINE STATIC DATA

Pipeline Substance High Pressure Dehydrated Sour Gas

Pipeline License # 22836 Line 1 License H2S 30.8 %

Pipeline Diameter 12’’(323.1mm) Pipeline Length 72.2 km

Maximum Operating Pres. 13,800 kPag Normal Operating Pres. 7000 – 9800 kPag

ANSI Rating 900 RTJ

TIE-IN / ESD LOCATIONS

STN 00 05-31-054-22W5 ESD Valve Station

STN 01 01-32-054-22W5 ESD Valve Station

STN 02 14-34-054-22W5 ESD Valve Station

STN 03 09-02-055-22W5 ESD Valve Station

STN 04 05-12-055-22W5 ESD Valve Station

STN 05 03-13-055-22W5 ESD Valve Station

STN 06 12-18-055-21W5 ESD Valve Station

STN 07 05-28-055-21W5 ESD Valve Station

STN 08 10-32-055-20W5 ESD Valve Station

STN 09 13-18-056-19W5 ESD Valve Station

STN 10 03-16-057-19W5 ESD Valve Station

STN 11 07-03-058-19W5 ESD Valve Station – Pine Creek Interconnect

STN 12 04-04-059-18W5 ESD Valve Station

STN 13 03-15-059-18W5 ESD Valve Station

FACILITY AND PIPELINE TIE-IN SPECIFICATIONS:

1: FACILITY REQUIREMENTS

Dehydration REQUIRED

Dewpoint Monitoring REQUIRED

Condensate BS&W Monitoring REQUIRED

SCADA Monitoring REQUIRED

1.1: FACILITY CONTROL AND MEASUREMENT REQUIREMENTS

Dehydration Glycol / Mole Sieve

Maximum Sales Gas Temperature 50°C

Dewpoint Continues Monitoring Shut-in -10°C

BS&W Continues Monitoring Shut-in/Diversion TBD (Requires review)

Metering – Gas Production EFM

Metering – Condensate Production EFM

Metering – Fuel Gas (site supplied) EFM Metered or Estimate

Metering – Fuel Gas (external ) NOT REQUIRED

2: PIPELINE TIE-IN REQUIREMENTS

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ESD Valve REQUIRED Check Valve REQUIRED Insulating Kit REQUIRED Future Connection REQUIRED Corrosion Monitoring Coupon REQUIRED Corrosion Inhibitor Injection REQUIRED

Type Baker Hughes CGW 4048

Methanol NONE

Sulphur Dispersants - Solvents NONE

Operational Liquids NONE (Solvents / Frac. Fluids / PL Initial Batch / …)

Operational Gasses NONE (N2 / CO2 / Air / … )

Water NONE

2.2: PIPELINE TIE-IN CONTROL AND MEASUREMENT REQUIREMENTS

Pressure Monitoring REQUIRED ESD Valve Position REQUIRED Remote ESD REQUIRED ESD – Local PSHH (High Pressure Shutdown Device) REQUIRED ESD – Local PSLL (Low Pressure Shutdown Device) REQUIRED

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J. KBS-211 TREESTONE PIPELINE

GENERAL DESCRIPTION

The Treestone Pipeline is a 10” pipeline which transports Wet Sweet Gas 9.4 Km from 04-25-058-19W5 to the SemCAMS K3 Gas Processing Plant located at 03-15-059-18W5. Tie-in points are installed along the length at several locations.

PIPELINE SPECIFICATIONS:

PIPELINE STATIC DATA

Pipeline Substance Low Pressure Wet Sweet Gas

Pipeline License # 34680 Line 1 License H2S 0 %

Pipeline Diameter 10’’ (273.1mm) Pipeline Length 9.41 km

Maximum Operating Pres. 6890 kPag Normal Operating Pres. 1800 – 2500 kPag

ANSI Rating 600 RF

TIE-IN / ESD LOCATIONS

STN 01 04-25-058-19W5 Manual Block Valve

STN 02 12-25-058-19W5 Hot Tap

STN 03 13-04-059-19W5 Hot Tap

STN 04 06-09-059-18W5 Hot Tap STN 05 10-09-059-18W5 Hot Tap STN 06 01-16-059-18W5 Hot Tap

STN 07 05-15-059-18W5 Manual Block Valve

FACILITY AND PIPELINE TIE-IN SPECIFICATIONS:

1: FACILITY REQUIREMENTS

Dehydration NOT REQUIRED

Dewpoint Monitoring NOT REQUIRED

Condensate BS&W Monitoring NOT REQUIRED

SCADA Monitoring REQUIRED

1.1: FACILITY CONTROL AND MEASUREMENT REQUIREMENTS

Dehydration N/A

Maximum Sales Gas Temperature 50°C

Dewpoint Continues Monitoring Shut-in N/A

BS&W Continues Monitoring Shut-in/Diversion N/A

Metering – Gas Production EFM

Metering – Condensate Production EFM

Metering – Fuel Gas (site supplied) EFM Metered or Estimate

Metering – Fuel Gas (external ) NOT REQUIRED

2: PIPELINE TIE-IN REQUIREMENTS

ESD Valve REQUIRED Check Valve REQUIRED Insulating Kit REQUIRED Future Connection REQUIRED Corrosion Monitoring Coupon NOT REQUIRED Corrosion Inhibitor Injection REQUIRED

Type Baker Hughes CRW 9852 mixed 2% by Volume

Methanol Inhibited Methanol

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Sulphur Dispersants - Solvents NONE

Operational Liquids NONE (Solvents / Frac. Fluids / PL Initial Batch / …)

Operational Gasses NONE (N2 / CO2 / Air / … )

Water NONE

2.2: PIPELINE TIE-IN CONTROL AND MEASUREMENT REQUIREMENTS

Pressure Monitoring RECOMMENDED ESD Valve Position RECOMMENDED Remote ESD RECOMMENDED ESD – Local PSHH (High Pressure Shutdown Device) REQUIRED ESD – Local PSLL (Low Pressure Shutdown Device) REQUIRED

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K. KBS-220 WINTERBURN PIPELINE

GENERAL DESCRIPTION

The Winterburn Pipeline is a 10” pipeline which transports Wet Sweet Gas 13.68 Km from 07-23-059-17W5 to the SemCAMS K3 Gas Processing Plant located at 03-15-059-18W5. Tie-in points are installed along the length at several locations.

PIPELINE SPECIFICATIONS:

PIPELINE STATIC DATA

Pipeline Substance Low Pressure Wet Sweet Gas

Pipeline License # 45076 Line 1 License H2S 0.9 %

Pipeline Diameter 10’’ (273.1mm) Pipeline Length 13.68 km

Maximum Operating Pres. 7720 kPag Normal Operating Pres. 900 – 1100 kPag

ANSI Rating 600 RF

TIE-IN / ESD LOCATIONS

STN 01 07-23-059-17W5 Manual Block Valve

STN 02 06-21-059-17W5 Manual Block Valve

STN 213 05-19-059-17W5 Hot Tap

STN 03 02-15-059-18W5 Manual Block Valve

STN 04 03-15-059-18W5 Manual Block Valve

FACILITY AND PIPELINE TIE-IN SPECIFICATIONS:

1: FACILITY REQUIREMENTS

Dehydration NOT REQUIRED

Dewpoint Monitoring NOT REQUIRED

Condensate BS&W Monitoring NOT REQUIRED

SCADA Monitoring REQUIRED

1.1: FACILITY CONTROL AND MEASUREMENT REQUIREMENTS

Dehydration N/A

Maximum Sales Gas Temperature 50°C

Dewpoint Continues Monitoring Shut-in N/A

BS&W Continues Monitoring Shut-in/Diversion N/A

Metering – Gas Production EFM

Metering – Condensate Production EFM

Metering – Fuel Gas (site supplied) EFM Metered or Estimate

Metering – Fuel Gas (external ) NOT REQUIRED

2: PIPELINE TIE-IN REQUIREMENTS

ESD Valve REQUIRED

Check Valve REQUIRED

Insulating Kit REQUIRED

Future Connection REQUIRED

Corrosion Monitoring Coupon NOT REQUIRED

Corrosion Inhibitor Injection REQUIRED

Type Baker Hughes CGW 4048

Methanol Inhibited Methanol

Sulphur Dispersants - Solvents NONE

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Operational Liquids NONE (Solvents / Frac. Fluids / PL Initial Batch / …)

Operational Gasses NONE (N2 / CO2 / Air / … )

Water NONE

2.2: PIPELINE TIE-IN CONTROL AND MEASUREMENT REQUIREMENTS

Pressure Monitoring RECOMMENDED ESD Valve Position RECOMMENDED Remote ESD RECOMMENDED ESD – Local PSHH (High Pressure Shutdown Device) REQUIRED ESD – Local PSLL (Low Pressure Shutdown Device) REQUIRED

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Appendix 2:

PINE CREEK GAS GATHERING

SYSTEM SPECIFICATIONS

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A. PCK-110 OLDMAN PIPELINE

GENERAL DESCRIPTION

The Oldman Pipeline is a 6” pipeline which transports High Pressure Dry Sour Gas 18 Kilometers from 14-24-056-21W5 to 13-21-057-19W5. Valve Stations and Tie-in points are installed along the length at several locations.

PIPELINE SPECIFICATIONS:

PIPELINE STATIC DATA

Pipeline Substance High Pressure Dehydrated Sour Gas

Pipeline License # 45108 Line 1,2 License H2S 0.95 %

Pipeline Diameter 6” (168.3mm) Pipeline Length 18 km

Maximum Operating Pres. 9930 kPag Normal Operating Pres. 3000 – 4000 kPag

ANSI Rating 600 RTJ

TIE-IN / ESD LOCATIONS

STN 01 14-24-056-21W5 ESD Valve Station

STN 02 16-29-056-20W5 Manual Block Valve

STN 03 10-13-057-20W5 Manual Block Valve

STN 04 13-21-057-19W5 ESD Valve Station – Nordegg 6 Pipeline Transition

FACILITY AND PIPELINE TIE-IN SPECIFICATIONS:

1: FACILITY REQUIREMENTS

Dehydration REQUIRED

Dewpoint Monitoring REQUIRED

Condensate BS&W Monitoring REQUIRED

SCADA Monitoring REQUIRED

1.1: FACILITY CONTROL AND MEASUREMENT REQUIREMENTS

Dehydration Glycol / Mole Sieve

Maximum Sales Gas Temperature 50°C

Dewpoint Continues Monitoring Shut-in -10°C

BS&W Continues Monitoring Shut-in/Diversion TBD

Metering – Gas Production EFM

Metering – Condensate Production EFM

Metering – Fuel Gas (site supplied) EFM Metered or Estimate

Metering – Fuel Gas (external ) NOT REQUIRED

2: PIPELINE TIE-IN REQUIREMENTS

ESD Valve REQUIRED Check Valve REQUIRED Insulating Kit REQUIRED Future Connection REQUIRED Corrosion Monitoring Coupon REQUIRED Corrosion Inhibitor Injection REQUIRED

Type NALCO Champion R-2378

Methanol NONE

Sulphur Dispersants - Solvents NONE

Operational Liquids NONE (Solvents / Frac. Fluids / PL Initial Batch / …)

Operational Gasses NONE (N2 / CO2 / Air / … )

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Water NONE

2.2: PIPELINE TIE-IN CONTROL AND MEASUREMENT REQUIREMENTS

Pressure Monitoring REQUIRED ESD Valve Position REQUIRED Remote ESD REQUIRED ESD – Local PSHH (High Pressure Shutdown Device) REQUIRED ESD – Local PSLL (Low Pressure Shutdown Device) REQUIRED

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B. PCK-111 NORDEGG 8” PIPELINE

GENERAL DESCRIPTION

The Nordegg 8” Pipeline is an 8” pipeline which transports High Pressure Dehydrated Sour Gas 4.25 kilometers from 13-21-057-19W5 to the Pine Creek Central Site facility at 03-03-058-19W5.

PIPELINE SPECIFICATIONS:

PIPELINE STATIC DATA

Pipeline Substance High Pressure Dehydrated Sour Gas

Pipeline License # 45106 Line 1 License H2S 3.9 %

Pipeline Diameter 8” (219.1mm) Pipeline Length 4.25 km

Maximum Operating Pres. 9930 kPag Normal Operating Pres. 1500 – 2200 kPag

ANSI Rating 600 RTJ

TIE-IN / ESD LOCATIONS

STN 01 13-21-057-19W5 ESD Valve Station

STN 02 03-03-058-19W5 ESD Valve Station

FACILITY AND PIPELINE TIE-IN SPECIFICATIONS:

1: FACILITY REQUIREMENTS

Dehydration REQUIRED

Dewpoint Monitoring REQUIRED

Condensate BS&W Monitoring REQUIRED

SCADA Monitoring REQUIRED

1.1: FACILITY CONTROL AND MEASUREMENT REQUIREMENTS

Dehydration Glycol / Mole Sieve

Maximum Sales Gas Temperature 50°C

Dewpoint Continues Monitoring Shut-in -10°C

BS&W Continues Monitoring Shut-in/Diversion TBD

Metering – Gas Production EFM

Metering – Condensate Production EFM

Metering – Fuel Gas (site supplied) EFM Metered or Estimate

Metering – Fuel Gas (external ) NOT REQUIRED

2: PIPELINE TIE-IN REQUIREMENTS

ESD Valve REQUIRED Check Valve REQUIRED Insulating Kit REQUIRED Future Connection REQUIRED Corrosion Monitoring Coupon REQUIRED Corrosion Inhibitor Injection REQUIRED

Type NALCO Champion R-2378

Methanol NONE

Sulphur Dispersants - Solvents NONE

Operational Liquids NONE (Solvents / Frac. Fluids / PL Initial Batch / …)

Operational Gasses NONE (N2 / CO2 / Air / … )

Water NONE

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2.2: PIPELINE TIE-IN CONTROL AND MEASUREMENT REQUIREMENTS

Pressure Monitoring REQUIRED ESD Valve Position REQUIRED Remote ESD REQUIRED ESD – Local PSHH (High Pressure Shutdown Device) REQUIRED ESD – Local PSLL (Low Pressure Shutdown Device) REQUIRED

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C. PCK-112 NORDEGG 6” PIPELINE

GENERAL DESCRIPTION

The Nordegg 6” Pipeline is an 6” pipeline which transports High Pressure Dehydrated Sour Gas 4.38 kilometers from 13-21-057-19W5 to the Pine Creek Central Site facility at 03-03-058-19W5.

PIPELINE SPECIFICATIONS:

PIPELINE STATIC DATA

Pipeline Substance High Pressure Dehydrated Sour Gas

Pipeline License # 45106 Line 2 License H2S 3.9 %

Pipeline Diameter 6” (168.3mm) Pipeline Length 4.38 km

Maximum Operating Pres. 9930 kPag Normal Operating Pres. 1500 – 2200 kPag

ANSI Rating 600 RTJ

TIE-IN / ESD LOCATIONS

STN 01 13-21-057-19W5 ESD Valve Station

STN 02 03-03-058-19W5 ESD Valve Station

FACILITY AND PIPELINE TIE-IN SPECIFICATIONS:

1: FACILITY REQUIREMENTS

Dehydration REQUIRED

Dewpoint Monitoring REQUIRED

Condensate BS&W Monitoring REQUIRED

SCADA Monitoring REQUIRED

1.1: FACILITY CONTROL AND MEASUREMENT REQUIREMENTS

Dehydration Glycol / Mole Sieve

Maximum Sales Gas Temperature 50°C

Dewpoint Continues Monitoring Shut-in -10°C

BS&W Continues Monitoring Shut-in/Diversion TBD

Metering – Gas Production EFM

Metering – Condensate Production EFM

Metering – Fuel Gas (site supplied) EFM Metered or Estimate

Metering – Fuel Gas (external ) NOT REQUIRED

2: PIPELINE TIE-IN REQUIREMENTS

ESD Valve REQUIRED Check Valve REQUIRED Insulating Kit REQUIRED Future Connection REQUIRED Corrosion Monitoring Coupon REQUIRED Corrosion Inhibitor Injection REQUIRED

Type NALCO Champion R-2378

Methanol NONE

Sulphur Dispersants - Solvents NONE

Operational Liquids NONE (Solvents / Frac. Fluids / PL Initial Batch / …)

Operational Gasses NONE (N2 / CO2 / Air / … )

Water NONE

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2.2: PIPELINE TIE-IN CONTROL AND MEASUREMENT REQUIREMENTS

Pressure Monitoring REQUIRED ESD Valve Position REQUIRED Remote ESD REQUIRED ESD – Local PSHH (High Pressure Shutdown Device) REQUIRED ESD – Local PSLL (Low Pressure Shutdown Device) REQUIRED

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D. PCK-130 PINE CREEK SOUTH HIGH PRESSURE (WET) PIPELINE

GENERAL DESCRIPTION

The Pine Creek South High Pressure (Wet) Pipeline is a 8” pipeline which transports High Pressure Sour Gas 12.3 kilometers from 12-18-056-19W5 to the Twin Dehydration facility at 11-14-057-19W5. ESD Valve Stations and Tie-in points are installed along the length at several locations.

PIPELINE SPECIFICATIONS:

PIPELINE STATIC DATA

Pipeline Substance High Pressure Sour Gas

Pipeline License # 45114 Line 11 License H2S 40 %

Pipeline Diameter 8” (219.1mm) Pipeline Length 12.32 km

Maximum Operating Pres. 14,790 kPag Normal Operating Pres. 3500 – 4200 kPag

ANSI Rating 900 RTJ

TIE-IN / ESD LOCATIONS

STN 01 12-18-056-19W5 ESD Valve Station

STN 112 10-19-056-19W5 Underground Tee

STN 02 06-29-056-19W5 ESD Valve Station

STN 213 07-32-056-19W5 Underground Tee

STN 03 10-04-057-19W5 ESD Valve Station

STN 04 10-10-057-19W5 ESD Valve Station

STN 05 11-14-057-19W5 ESD Valve Station

FACILITY AND PIPELINE TIE-IN SPECIFICATIONS:

1: FACILITY REQUIREMENTS

Dehydration NOT REQUIRED

Dewpoint Monitoring NOT REQUIRED

Condensate BS&W Monitoring NOT REQUIRED

SCADA Monitoring REQUIRED

1.1: FACILITY CONTROL AND MEASUREMENT REQUIREMENTS

Dehydration N/A

Maximum Sales Gas Temperature 50°C

Dewpoint Continues Monitoring Shut-in N/A

BS&W Continues Monitoring Shut-in/Diversion N/A

Metering – Gas Production EFM

Metering – Condensate Production EFM

Metering – Fuel Gas (site supplied) EFM Metered or Estimate

Metering – Fuel Gas (external ) NOT REQUIRED

2: PIPELINE TIE-IN REQUIREMENTS

ESD Valve REQUIRED Check Valve REQUIRED Insulating Kit REQUIRED Future Connection REQUIRED Corrosion Monitoring Coupon REQUIRED

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Corrosion Inhibitor Injection REQUIRED

Type NALCO Champion RN-220

Methanol Inhibited Methanol

Sulphur Dispersants - Solvents NONE

Operational Liquids NONE (Solvents / Frac. Fluids / PL Initial Batch / …)

Operational Gasses NONE (N2 / CO2 / Air / … )

Water NONE

2.2: PIPELINE TIE-IN CONTROL AND MEASUREMENT REQUIREMENTS

Pressure Monitoring REQUIRED ESD Valve Position REQUIRED Remote ESD REQUIRED ESD – Local PSHH (High Pressure Shutdown Device) REQUIRED ESD – Local PSLL (Low Pressure Shutdown Device) REQUIRED

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E. PCK-134 PINE CREEK SOUTH HIGH PRESSURE (DRY) PIPELINE

GENERAL DESCRIPTION

The Pine Creek South High Pressure (Dry) Pipeline is a 8” & 10” pipeline which transports High Pressure Dry Sour Gas 6.8 kilometers from 11-14-057-19W5 to Pine Creek Central Site facility at 03-03-058-19W5. ESD Valve Stations and Tie-in points are installed along the length at several locations.

PIPELINE SPECIFICATIONS:

PIPELINE STATIC DATA

Pipeline Substance High Pressure Dehydrated Sour Gas

Pipeline License # 45114 Line 1,2 45104 Line 1

License H2S 40 %

Pipeline Diameter 10” (273.1mm) 8” (219.1mm)

Pipeline Length 6.8 km

Maximum Operating Pres. 9930 kPag Normal Operating Pres. 3500 – 4200 kPag

ANSI Rating 600 RTJ

TIE-IN / ESD LOCATIONS

STN 01 11-14-057-19W5 ESD Valve Station

STN 02 10-23-057-19W5 Manual Isolation Valve

STN 213 12-26-057-19W5 Hot Tap

STN 223 04-35-057-19W5 Hot Tap - Interconnect

STN 03 03-03-058-19W5 ESD Valve Station

FACILITY AND PIPELINE TIE-IN SPECIFICATIONS:

1: FACILITY REQUIREMENTS

Dehydration REQUIRED

Dewpoint Monitoring REQUIRED

Condensate BS&W Monitoring REQUIRED

SCADA Monitoring REQUIRED

1.1: FACILITY CONTROL AND MEASUREMENT REQUIREMENTS

Dehydration Glycol / Mole-Sieve

Maximum Sales Gas Temperature 50°C

Dewpoint Continues Monitoring Shut-in -10°C

BS&W Continues Monitoring Shut-in/Diversion TBD

Metering – Gas Production EFM

Metering – Condensate Production EFM

Metering – Fuel Gas (site supplied) EFM Metered or Estimate

Metering – Fuel Gas (external ) NOT REQUIRED

2: PIPELINE TIE-IN REQUIREMENTS

ESD Valve REQUIRED Check Valve REQUIRED Insulating Kit REQUIRED Future Connection REQUIRED Corrosion Monitoring Coupon REQUIRED

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Corrosion Inhibitor Injection REQUIRED

Type NALCO Champion R-2378

Methanol NONE

Sulphur Dispersants - Solvents NONE

Operational Liquids NONE (Solvents / Frac. Fluids / PL Initial Batch / …)

Operational Gasses NONE (N2 / CO2 / Air / … )

Water NONE

2.2: PIPELINE TIE-IN CONTROL AND MEASUREMENT REQUIREMENTS

Pressure Monitoring REQUIRED ESD Valve Position REQUIRED Remote ESD REQUIRED ESD – Local PSHH (High Pressure Shutdown Device) REQUIRED ESD – Local PSLL (Low Pressure Shutdown Device) REQUIRED

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F. PCK-135 PINE CREEK SOUTH LOW PRESSURE PIPELINE

GENERAL DESCRIPTION

The Pine Creek South Low Pressure (Dry) Pipeline is a 6”, 8” & 10” pipeline which transports Dehydrated Sour Gas 6.7 kilometers from 11-14-057-19W5 to Pine Creek Central Site facility at 03-03-058-19W5. ESD Valve Stations and Tie-in points are installed along the length at several locations.

PIPELINE SPECIFICATIONS:

PIPELINE STATIC DATA

Pipeline Substance Low Pressure Dehydrated Sour Gas

Pipeline License # 45114 Line 5,6,7 License H2S 40 %

Pipeline Diameter 6” (168.3mm) 8” (219.1mm) 10” (273.1mm)

Pipeline Length 6.7 km

Maximum Operating Pres. 9930 kPag Normal Operating Pres. 1500 – 2200 kPag

ANSI Rating 600 RTJ

TIE-IN / ESD LOCATIONS

STN 01 11-14-057-19W5 ESD Valve Station

STN 02 10-23-057-19W5 Manual Isolation Valve

STN 03 04-35-057-19W5 ESD Valve Station

STN 04 03-03-058-19W5 ESD Valve Station

PCK-230 09-11-057-19W5 Manual Isolation Valve – 09-11 to 11-14 Lateral (P/L Lic # 45107 Line 1)

PCK-220 10-10-057-19W5 Manual Isolation Valve – 10-10 to 11-14 Lateral (P/L Lic # 45109 Line 1)

PCK-231 03-24-057-19W5 Manual Isolation Valve – 03-24 to 10-23 Lateral (P/L Lic # 45110 Line 1)

FACILITY AND PIPELINE TIE-IN SPECIFICATIONS:

1: FACILITY REQUIREMENTS

Dehydration REQUIRED

Dewpoint Monitoring REQUIRED

Condensate BS&W Monitoring REQUIRED

SCADA Monitoring REQUIRED

1.1: FACILITY CONTROL AND MEASUREMENT REQUIREMENTS

Dehydration Glycol / Mole-Sieve

Maximum Sales Gas Temperature 50°C

Dewpoint Continues Monitoring Shut-in -10°C

BS&W Continues Monitoring Shut-in/Diversion TBD

Metering – Gas Production EFM

Metering – Condensate Production EFM

Metering – Fuel Gas (site supplied) EFM Metered or Estimate

Metering – Fuel Gas (external ) NOT REQUIRED

2: PIPELINE TIE-IN REQUIREMENTS

ESD Valve REQUIRED Check Valve REQUIRED Insulating Kit REQUIRED

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Future Connection REQUIRED Corrosion Monitoring Coupon REQUIRED Corrosion Inhibitor Injection REQUIRED

Type NALCO Champion R-2378

Methanol NONE

Sulphur Dispersants - Solvents NONE

Operational Liquids NONE (Solvents / Frac. Fluids / PL Initial Batch / …)

Operational Gasses NONE (N2 / CO2 / Air / … )

Water NONE

2.2: PIPELINE TIE-IN CONTROL AND MEASUREMENT REQUIREMENTS

Pressure Monitoring REQUIRED ESD Valve Position REQUIRED Remote ESD REQUIRED ESD – Local PSHH (High Pressure Shutdown Device) REQUIRED ESD – Local PSLL (Low Pressure Shutdown Device) REQUIRED

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G. PCK-140 JACKFISH NORTH PIPELINE

GENERAL DESCRIPTION

The Jackfish North Pipeline is a 6” pipeline which transports Sour Gas 17 kilometers from 14-35-061-22W5 to 11-36-059-21W5. Manual Valve Risers and Tie-in points are installed along the length at several locations.

PIPELINE SPECIFICATIONS:

PIPELINE STATIC DATA

Pipeline Substance Sour Gas

Pipeline License # 6616 Line 16,18,26,28 License H2S 18.9 %

Pipeline Diameter 6” (168.3mm) Pipeline Length 17.06 km

Maximum Operating Pres. 13,960 kPag Normal Operating Pres. 1500 – 2200 kPag

ANSI Rating 900 RTJ

TIE-IN / ESD LOCATIONS

STN 01 14-35-061-22W5 Manual Isolation Valve

STN 02 13-25-060-22W5 Manual Isolation Valve

STN 03 02-25-060-22W5 Manual Isolation Valve

STN 04 01-25-060-22W5 Manual Isolation Valve

STN 05 06-19-060-21W5 Manual Isolation Valve

STN 06 11-17-060-21W5 Manual Isolation Valve

STN 07 02-10-060-21W5 Manual Isolation Valve

STN 08 11-02-060-21W5 Manual Isolation Valve

STN 09 11-36-059-21W5 Manual Isolation Valve – Transition to Jackfish South Pipeline

FACILITY AND PIPELINE TIE-IN SPECIFICATIONS:

1: FACILITY REQUIREMENTS

Dehydration NOT REQUIRED

Dewpoint Monitoring NOT REQUIRED

Condensate BS&W Monitoring NOT REQUIRED

SCADA Monitoring REQUIRED

1.1: FACILITY CONTROL AND MEASUREMENT REQUIREMENTS

Dehydration N/A

Maximum Sales Gas Temperature 50°C

Dewpoint Continues Monitoring Shut-in N/A

BS&W Continues Monitoring Shut-in/Diversion N/A

Metering – Gas Production EFM

Metering – Condensate Production EFM

Metering – Fuel Gas (site supplied) EFM Metered or Estimate

Metering – Fuel Gas (external ) NOT REQUIRED

2: PIPELINE TIE-IN REQUIREMENTS

ESD Valve REQUIRED Check Valve REQUIRED Insulating Kit REQUIRED Future Connection REQUIRED Corrosion Monitoring Coupon REQUIRED Corrosion Inhibitor Injection REQUIRED

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Type NALCO Champion RN-357

Methanol Inhibited Methanol

Sulphur Dispersants - Solvents NONE

Operational Liquids NONE (Solvents / Frac. Fluids / PL Initial Batch / …)

Operational Gasses NONE (N2 / CO2 / Air / … )

Water NONE

2.2: PIPELINE TIE-IN CONTROL AND MEASUREMENT REQUIREMENTS

Pressure Monitoring REQUIRED ESD Valve Position REQUIRED Remote ESD REQUIRED ESD – Local PSHH (High Pressure Shutdown Device) REQUIRED ESD – Local PSLL (Low Pressure Shutdown Device) REQUIRED

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H. PCK-141 JACKFISH SOUTH PIPELINE

GENERAL DESCRIPTION

The Jackfish South Pipeline is a 6” pipeline which transports Sour Gas 1.35 kilometers from 11-02-060-21W5 to 15-25-059-21W5. Manual Valve Risers and Tie-in points are installed along the length at several locations.

PIPELINE SPECIFICATIONS:

PIPELINE STATIC DATA

Pipeline Substance Sour Gas

Pipeline License # 45121 Line 2 License H2S 18.9 %

Pipeline Diameter 6” (168.3mm) Pipeline Length 1.35 km

Maximum Operating Pres. 13,960 kPag Normal Operating Pres. 3500 – 5000 kPag

ANSI Rating 900 RTJ

TIE-IN / ESD LOCATIONS

PCK-141 11-36-059-21W5 Jackfish North Pipeline Transition – Manual Isolation Valve

PCK-141 15-25-059-21W5 Manual Isolation Valve – Pine Creek North Pipeline Transition

FACILITY AND PIPELINE TIE-IN SPECIFICATIONS:

1: FACILITY REQUIREMENTS

Dehydration NOT REQUIRED

Dewpoint Monitoring NOT REQUIRED

Condensate BS&W Monitoring NOT REQUIRED

SCADA Monitoring REQUIRED

1.1: FACILITY CONTROL AND MEASUREMENT REQUIREMENTS

Dehydration N/A

Maximum Sales Gas Temperature 50°C

Dewpoint Continues Monitoring Shut-in N/A

BS&W Continues Monitoring Shut-in/Diversion N/A

Metering – Gas Production EFM

Metering – Condensate Production EFM

Metering – Fuel Gas (site supplied) EFM Metered or Estimate

Metering – Fuel Gas (external ) NOT REQUIRED

2: PIPELINE TIE-IN REQUIREMENTS

ESD Valve REQUIRED Check Valve REQUIRED Insulating Kit REQUIRED Future Connection REQUIRED Corrosion Monitoring Coupon REQUIRED Corrosion Inhibitor Injection REQUIRED

Type NALCO Champion RN-357

Methanol Inhibited Methanol

Sulphur Dispersants - Solvents NONE

Operational Liquids NONE (Solvents / Frac. Fluids / PL Initial Batch / …)

Operational Gasses NONE (N2 / CO2 / Air / … )

Water NONE

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2.2: PIPELINE TIE-IN CONTROL AND MEASUREMENT REQUIREMENTS

Pressure Monitoring REQUIRED ESD Valve Position REQUIRED Remote ESD REQUIRED ESD – Local PSHH (High Pressure Shutdown Device) REQUIRED ESD – Local PSLL (Low Pressure Shutdown Device) REQUIRED

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I. PCK-142 PINE CREEK NORTH PIPELINE

GENERAL DESCRIPTION

The Pine Creek North Pipeline is a 8” pipeline which transports Sour Gas 16.28 kilometers from 15-25-059-21W5 to the Happy Face Dehydration Facility at 09-22-058-20W5. Manual Valve Risers and Tie-in points are installed along the length at several locations.

PIPELINE SPECIFICATIONS:

PIPELINE STATIC DATA

Pipeline Substance Sour Gas

Pipeline License # 45121 Line 1 License H2S 18.9 %

Pipeline Diameter 8” (219.1mm) Pipeline Length 16.28 km

Maximum Operating Pres. 13,960 kPag Normal Operating Pres. 3500 – 5000 kPag

ANSI Rating 900 RTJ

TIE-IN / ESD LOCATIONS

STN 01 15-25-059-21W5 Jackfish South Pipeline Transition – Manual Isolation Valve

STN 02 06-19-059-20W5 Manual Isolation Valve

STN 03 10-17-059-20W5 Manual Isolation Valve

STN 04 10-04-059-20W5 ESD Valve Station

STN 05 16-28-058-20W5 Manual Isolation Valve

STN 06 09-22-058-20W5 Manual Isolation Valve

FACILITY AND PIPELINE TIE-IN SPECIFICATIONS:

1: FACILITY REQUIREMENTS

Dehydration NOT REQUIRED

Dewpoint Monitoring NOT REQUIRED

Condensate BS&W Monitoring NOT REQUIRED

SCADA Monitoring REQUIRED

1.1: FACILITY CONTROL AND MEASUREMENT REQUIREMENTS

Dehydration N/A

Maximum Sales Gas Temperature 50°C

Dewpoint Continues Monitoring Shut-in N/A

BS&W Continues Monitoring Shut-in/Diversion N/A

Metering – Gas Production EFM

Metering – Condensate Production EFM

Metering – Fuel Gas (site supplied) EFM Metered or Estimate

Metering – Fuel Gas (external ) NOT REQUIRED

2: PIPELINE TIE-IN REQUIREMENTS

ESD Valve REQUIRED Check Valve REQUIRED Insulating Kit REQUIRED Future Connection REQUIRED Corrosion Monitoring Coupon REQUIRED Corrosion Inhibitor Injection REQUIRED

Type NALCO Champion RN-357

Methanol Inhibited Methanol

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Sulphur Dispersants - Solvents NONE

Operational Liquids NONE (Solvents / Frac. Fluids / PL Initial Batch / …)

Operational Gasses NONE (N2 / CO2 / Air / … )

Water NONE

2.2: PIPELINE TIE-IN CONTROL AND MEASUREMENT REQUIREMENTS

Pressure Monitoring REQUIRED ESD Valve Position REQUIRED Remote ESD REQUIRED ESD – Local PSHH (High Pressure Shutdown Device) REQUIRED ESD – Local PSLL (Low Pressure Shutdown Device) REQUIRED

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J. PCK-145 FIR INTERCONNECT PIPELINE

GENERAL DESCRIPTION

The Fir Interconnect Pipeline is a 4” pipeline which transports Sour Gas 6.54 kilometers from 03-12-058-20W5 to the Happy Face Dehydration Facility at 09-22-058-20W5. Manual Valve Risers and Tie-in points are installed along the length at several locations.

PIPELINE SPECIFICATIONS:

PIPELINE STATIC DATA

Pipeline Substance Sour Gas

Pipeline License # 19721 Line 2 45119 Line 5,6,7

License H2S 1.43 % 22 %

Pipeline Diameter 4” (114.3mm) Pipeline Length 6.54 km

Maximum Operating Pres. 13,960 kPag Normal Operating Pres. 3500 – 5000 kPag

ANSI Rating 900 RTJ

TIE-IN / ESD LOCATIONS

STN 01 03-12-058-20W5 Fir Pipeline Interconnect – Manual Isolation Valve

STN 02 16-27-058-20W5 Manual Isolation Valve

STN 03 12-26-058-20W5 Hot Tap

STN 04 05-26-058-20W5 Manual Isolation Valve

STN 05 09-22-058-20W5 Manual Isolation Valve

FACILITY AND PIPELINE TIE-IN SPECIFICATIONS:

1: FACILITY REQUIREMENTS

Dehydration NOT REQUIRED

Dewpoint Monitoring NOT REQUIRED

Condensate BS&W Monitoring NOT REQUIRED

SCADA Monitoring REQUIRED

1.1: FACILITY CONTROL AND MEASUREMENT REQUIREMENTS

Dehydration N/A

Maximum Sales Gas Temperature 50°C

Dewpoint Continues Monitoring Shut-in N/A

BS&W Continues Monitoring Shut-in/Diversion N/A

Metering – Gas Production EFM

Metering – Condensate Production EFM

Metering – Fuel Gas (site supplied) EFM Metered or Estimate

Metering – Fuel Gas (external ) NOT REQUIRED

2: PIPELINE TIE-IN REQUIREMENTS

ESD Valve REQUIRED Check Valve REQUIRED Insulating Kit REQUIRED Future Connection REQUIRED Corrosion Monitoring Coupon REQUIRED Corrosion Inhibitor Injection REQUIRED

Type NALCO Champion RN-357

Methanol Inhibited Methanol

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Sulphur Dispersants - Solvents NONE

Operational Liquids NONE (Solvents / Frac. Fluids / PL Initial Batch / …)

Operational Gasses NONE (N2 / CO2 / Air / … )

Water NONE

2.2: PIPELINE TIE-IN CONTROL AND MEASUREMENT REQUIREMENTS

Pressure Monitoring REQUIRED ESD Valve Position REQUIRED Remote ESD REQUIRED ESD – Local PSHH (High Pressure Shutdown Device) REQUIRED ESD – Local PSLL (Low Pressure Shutdown Device) REQUIRED

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K. PCK-150 NORTH WEST PINE PIPELINE

GENERAL DESCRIPTION

The North West Pine Pipeline is a 8” & 10” pipeline which transports High Pressure Dry Sour Gas 13.58 kilometers from 09-22-058-20W5 to Pine Creek Central Site facility at 03-03-058-19W5. ESD Valve Stations and Tie-in points are installed along the length at several locations.

PIPELINE SPECIFICATIONS:

PIPELINE STATIC DATA

Pipeline Substance High Pressure Dehydrated Sour Gas

Pipeline License # 51474 Line 1,2,3,4 45114 Line 4,10

License H2S 30 % 40 %

Pipeline Diameter 6” (168.3mm) 8” (219.1mm)

Pipeline Length 13.58 km

Maximum Operating Pres. 17,240 kPag Normal Operating Pres. 3500 – 4200 kPag

ANSI Rating 900 RTJ

TIE-IN / ESD LOCATIONS

STN 01 09-22-058-20W5 ESD Valve Station

STN 02 09-15-058-20W5 Manual Isolation Valve

STN 03 01-14-058-20W5 Manual Isolation Valve

STN 04 04-18-058-19W5 Manual Isolation Valve

STN 05 10-17-058-19W5 ESD Valve Station

STN 516 06-16-058-19W5 Hot Tap

STN 06 08-16-058-19W5 Manual Isolation Valve

STN 617 03-15-058-19W5 Underground Tee

STN 627 02-10-058-19W5 Underground Tee

STN 07 03-03-058-19W5 ESD Valve Station

FACILITY AND PIPELINE TIE-IN SPECIFICATIONS:

1: FACILITY REQUIREMENTS

Dehydration REQUIRED

Dewpoint Monitoring REQUIRED

Condensate BS&W Monitoring REQUIRED

SCADA Monitoring REQUIRED

1.1: FACILITY CONTROL AND MEASUREMENT REQUIREMENTS

Dehydration Glycol / Mole-Sieve

Maximum Sales Gas Temperature 50°C

Dewpoint Continues Monitoring Shut-in -10°C

BS&W Continues Monitoring Shut-in/Diversion TBD

Metering – Gas Production EFM

Metering – Condensate Production EFM

Metering – Fuel Gas (site supplied) EFM Metered or Estimate

Metering – Fuel Gas (external ) NOT REQUIRED

2: PIPELINE TIE-IN REQUIREMENTS

ESD Valve REQUIRED Check Valve REQUIRED

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Insulating Kit REQUIRED Future Connection REQUIRED Corrosion Monitoring Coupon REQUIRED Corrosion Inhibitor Injection REQUIRED

Type NALCO Champion R-2378

Methanol NONE

Sulphur Dispersants - Solvents NONE

Operational Liquids NONE (Solvents / Frac. Fluids / PL Initial Batch / …)

Operational Gasses NONE (N2 / CO2 / Air / … )

Water NONE

2.2: PIPELINE TIE-IN CONTROL AND MEASUREMENT REQUIREMENTS

Pressure Monitoring REQUIRED ESD Valve Position REQUIRED Remote ESD REQUIRED ESD – Local PSHH (High Pressure Shutdown Device) REQUIRED ESD – Local PSLL (Low Pressure Shutdown Device) REQUIRED

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L. PCK-180 PINE CREEK SALES PIPELINE

GENERAL DESCRIPTION

The Pine Creek Sales Pipeline is a 14” pipeline which transports High Pressure Dry Sour Gas 42 kilometers from Central Site 03-03-058-19W5 to West Whitecourt Gas Plant at 03-17-060-15W5. ESD Valve Stations and Tie-in points are installed along the length at several locations.

PIPELINE SPECIFICATIONS:

PIPELINE STATIC DATA

Pipeline Substance High Pressure Dehydrated Sour Gas

Pipeline License # 3191 Line 1,3,5,7,9,10 License H2S 25.6 %

Pipeline Diameter 14” (355.6mm) Pipeline Length 42 km

Maximum Operating Pres. 14,130 kPag Normal Operating Pres. 5500 – 7500 kPag

ANSI Rating 900 RTJ

TIE-IN / ESD LOCATIONS

STN 01 03-03-058-19W5 ESD Valve Station

STN 02 07-17-058-18W5 ESD Valve Station

STN 213 11-25-058-18W5 Manual Isolation Valve – Interconnect

STN 03 16-03-059-17W5 ESD Valve Station

STN 04 16-27-059-16W5 ESD Valve Station

STN 05 03-07-060-15W5 ESD Valve Station

STN 06 03-17-060-15W5 ESD Valve Station

FACILITY AND PIPELINE TIE-IN SPECIFICATIONS:

1: FACILITY REQUIREMENTS

Dehydration REQUIRED

Dewpoint Monitoring REQUIRED

Condensate BS&W Monitoring REQUIRED

SCADA Monitoring REQUIRED

1.1: FACILITY CONTROL AND MEASUREMENT REQUIREMENTS

Dehydration Glycol / Mole-Sieve

Maximum Sales Gas Temperature 50°C

Dewpoint Continues Monitoring Shut-in -10°C

BS&W Continues Monitoring Shut-in/Diversion TBD

Metering – Gas Production EFM

Metering – Condensate Production EFM

Metering – Fuel Gas (site supplied) EFM Metered or Estimate

Metering – Fuel Gas (external ) NOT REQUIRED

2: PIPELINE TIE-IN REQUIREMENTS

ESD Valve REQUIRED Check Valve REQUIRED Insulating Kit REQUIRED Future Connection REQUIRED Corrosion Monitoring Coupon REQUIRED Corrosion Inhibitor Injection REQUIRED

Type NALCO Champion R-2378

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Methanol NONE

Sulphur Dispersants - Solvents NONE

Operational Liquids NONE (Solvents / Frac. Fluids / PL Initial Batch / …)

Operational Gasses NONE (N2 / CO2 / Air / … )

Water NONE

2.2: PIPELINE TIE-IN CONTROL AND MEASUREMENT REQUIREMENTS

Pressure Monitoring REQUIRED ESD Valve Position REQUIRED Remote ESD REQUIRED ESD – Local PSHH (High Pressure Shutdown Device) REQUIRED ESD – Local PSLL (Low Pressure Shutdown Device) REQUIRED

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Appendix 3:

KA AMALGAMATED GAS

GATHERING SYSTEM

SPECIFICATIONS

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A. KAY-110 TONY CREEK PIPELINE

GENERAL DESCRIPTION

The Tony Creek Pipeline is a 8” Pipeline which transports High Pressure Wet Sour Gas 15 Kilometers from 07-22-061-21W5 to the Kaybob Amalgamated Gas Plant at 01-12-062-20W5. Valve Stations and Tie-in points are installed along the length at several locations.

PIPELINE SPECIFICATIONS:

PIPELINE STATIC DATA

Pipeline Substance High Pressure Wet Sour Gas

Pipeline License # 49591 Line 1,2,3,4,5,6 License H2S 20 %

Pipeline Diameter 8” (219.1mm) Pipeline Length 15.5 km

Maximum Operating Pres. 9930 kPag Normal Operating Pres. 6500 – 7500 kPag

ANSI Rating 600 RTJ

TIE-IN / ESD LOCATIONS

STN 01 07-22-061-21W5 ESD Valve Station

STN 02 01-25-061-20W5 ESD Valve Station

STN 03 14-27-061-20W5 ESD Valve Station

STN 04 13-01-062-20W5 ESD Valve Station

FACILITY AND PIPELINE TIE-IN SPECIFICATIONS:

1: FACILITY REQUIREMENTS

Dehydration NOT REQUIRED

Dewpoint Monitoring NOT REQUIRED

Condensate BS&W Monitoring NOT REQUIRED

SCADA Monitoring REQUIRED

1.1: FACILITY CONTROL AND MEASUREMENT REQUIREMENTS

Dehydration N/A

Maximum Sales Gas Temperature 50°C

Dewpoint Continues Monitoring Shut-in N/A

BS&W Continues Monitoring Shut-in/Diversion N/A

Metering – Gas Production EFM

Metering – Condensate Production N/A

Metering – Fuel Gas (site supplied) EFM Metered or Estimate

Metering – Fuel Gas (external ) NOT REQUIRED

2: PIPELINE TIE-IN REQUIREMENTS

ESD Valve REQUIRED Check Valve REQUIRED Insulating Kit REQUIRED Future Connection REQUIRED Corrosion Monitoring Coupon REQUIRED Corrosion Inhibitor Injection REQUIRED

Type NALCO Champion RN-357C

Methanol Inhibited Methanol

Sulphur Dispersants - Solvents NONE

Operational Liquids NONE (Solvents / Frac. Fluids / PL Initial Batch / …)

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Operational Gasses NONE (N2 / CO2 / Air / … )

Water NONE

2.2: PIPELINE TIE-IN CONTROL AND MEASUREMENT REQUIREMENTS

Pressure Monitoring REQUIRED ESD Valve Position REQUIRED Remote ESD REQUIRED ESD – Local PSHH (High Pressure Shutdown Device) REQUIRED ESD – Local PSLL (Low Pressure Shutdown Device) REQUIRED

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B. KAY-111 TONY CREEK EXTENSION PIPELINE

GENERAL DESCRIPTION

The Tony Creek Extension Pipeline is a 8” Pipeline which transports High Pressure Dry Sour Gas 11 Km from 07-10-061-22W5 to the SemCAMS Tony Creek Pipeline GGS located at 07-22-061-21W5. Valve Stations and Tie-in points are installed along the length at several locations. Interconnection with other pipeline systems and processing plants has been utilized to re-route gas from one system / plant to another as required.

PIPELINE SPECIFICATIONS:

PIPELINE STATIC DATA

Pipeline Substance High Pressure Dry Sour Gas

Pipeline License # 45112 Line 1 License H2S 20 %

Pipeline Diameter 8” (219.1mm) Pipeline Length 11 km

Maximum Operating Pres. 9930 kPag Normal Operating Pres. 6500 – 7500 kPag

ANSI Rating 600 RF

TIE-IN / ESD LOCATIONS

STN 01 02-10-061-22W5 ESD Valve Station

STN 02 07-22-061-21W5 ESD Valve Station

FACILITY AND PIPELINE TIE-IN SPECIFICATIONS:

1: FACILITY REQUIREMENTS

Dehydration REQUIRED

Dewpoint Monitoring REQUIRED

Condensate BS&W Monitoring REQUIRED

SCADA Monitoring REQUIRED

1.1: FACILITY CONTROL AND MEASUREMENT REQUIREMENTS

Dehydration Glycol / Mole-Sieve

Maximum Sales Gas Temperature 50°C

Dewpoint Continues Monitoring Shut-in -10°C

BS&W Continues Monitoring Shut-in/Diversion TBD

Metering – Gas Production EFM

Metering – Condensate Production EFM

Metering – Fuel Gas (site supplied) EFM Metered or Estimate

Metering – Fuel Gas (external ) NOT REQUIRED

2: PIPELINE TIE-IN REQUIREMENTS

ESD Valve REQUIRED Check Valve REQUIRED Insulating Kit REQUIRED Future Connection REQUIRED Corrosion Monitoring Coupon REQUIRED Corrosion Inhibitor Injection REQUIRED

Type NALCO Champion R-2378

Methanol NONE

Sulphur Dispersants - Solvents NONE

Operational Liquids NONE (Solvents / Frac. Fluids / PL Initial Batch / …)

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Operational Gasses NONE (N2 / CO2 / Air / … )

Water NONE

2.2: PIPELINE TIE-IN CONTROL AND MEASUREMENT REQUIREMENTS

Pressure Monitoring REQUIRED ESD Valve Position REQUIRED Remote ESD REQUIRED ESD – Local PSHH (High Pressure Shutdown Device) REQUIRED ESD – Local PSLL (Low Pressure Shutdown Device) REQUIRED

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C. KAY-140 KA NORTH PIPELINE

GENERAL DESCRIPTION

The KA North Pipeline is a 10” pipeline which transports High Pressure Dry Sour Gas 15 km from07-14-063-20W5 to the KA Gas Plant located at 01-12-062-20W5. ESD Valve Stations and Tie-in points are installed along the length at several locations.

PIPELINE SPECIFICATIONS:

PIPELINE STATIC DATA

Pipeline Substance High Pressure Dry Sour Gas

Pipeline License # 55852 Line 1,2,3,4,5,6,7 License H2S 1.5 %

Pipeline Diameter 10” (273.1mm) Pipeline Length 15 km

Maximum Operating Pres. 13,100 kPag Normal Operating Pres. 5000 – 9000 kPag

ANSI Rating 900 RTJ

TIE-IN / ESD LOCATIONS

STN 01 07-14-063-20W5 ESD Valve Station

STN 02 07-10-062-20W5 ESD Valve Station

STN 03 01-33-062-20W5 ESD Valve Station

STN 04 10-22-062-20W5 ESD Valve Station

STN 05 04-23-062-20W5 ESD Valve Station

STN 06 10-14-062-20W5 ESD Valve Station

STN 07 10-11-062-20W5 ESD Valve Station

STN 08 04-12-062-20W5 ESD Valve Station

FACILITY AND PIPELINE TIE-IN SPECIFICATIONS:

1: FACILITY REQUIREMENTS

Dehydration REQUIRED

Dewpoint Monitoring REQUIRED

Condensate BS&W Monitoring REQUIRED

SCADA Monitoring REQUIRED

1.1: FACILITY CONTROL AND MEASUREMENT REQUIREMENTS

Dehydration Glycol / Mole-Sieve

Maximum Sales Gas Temperature 50°C

Dewpoint Continues Monitoring Shut-in -10

BS&W Continues Monitoring Shut-in/Diversion TBD

Metering – Gas Production EFM

Metering – Condensate Production EFM

Metering – Fuel Gas (site supplied) EFM Metered or Estimate

Metering – Fuel Gas (external ) NOT REQUIRED

2: PIPELINE TIE-IN REQUIREMENTS

ESD Valve REQUIRED Check Valve REQUIRED Insulating Kit REQUIRED Future Connection REQUIRED Corrosion Monitoring Coupon REQUIRED Corrosion Inhibitor Injection REQUIRED

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Type NALCO Champion R-2378

Methanol NONE

Sulphur Dispersants - Solvents NONE

Operational Liquids NONE (Solvents / Frac. Fluids / PL Initial Batch / …)

Operational Gasses NONE (N2 / CO2 / Air / … )

Water NONE

2.2: PIPELINE TIE-IN CONTROL AND MEASUREMENT REQUIREMENTS

Pressure Monitoring REQUIRED ESD Valve Position REQUIRED Remote ESD REQUIRED ESD – Local PSHH (High Pressure Shutdown Device) REQUIRED ESD – Local PSLL (Low Pressure Shutdown Device) REQUIRED

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D. KAY-150 KA CONDENSATE (HVP) PIPELINE

GENERAL DESCRIPTION

The KA Condensate (HVP) Pipeline is a 6” Pipeline which transports Hydrocarbon Liquids C5+ Product 9.3 Kilometers from 15-28-062-20W5 to the SemCAMS Kaybob Gas Plant located at 03-12-062-20W5. ESD Valve Stations and Tie-in points are installed along the length at several locations.

PIPELINE SPECIFICATIONS:

PIPELINE STATIC DATA

Pipeline Substance Hydrocarbon Liquids C5+ (HVP)

Pipeline License # 56997 Line 1 License H2S 2 %

Pipeline Diameter 6” (168.3mm) Pipeline Length 9.3 km

Maximum Operating Pres. 4960 kPag Normal Operating Pres. 3500 – 4500 kPag

ANSI Rating 300 RF

TIE-IN / ESD LOCATIONS

STN 01 15-28-062-20W5 ESD Valve Station

STN 02 01-33-062-20W5 ESD Valve Station

STN 03 10-22-062-20W5 ESD Valve Station

STN 04 10-14-062-20W5 ESD Valve Station

STN 05 10-11-062-20W5 ESD Valve Station

STN 06 08-12-062-20W5 Manual Isolation Valve

STN 07 04-12-062-20W5 ESD Valve Station

FACILITY AND PIPELINE TIE-IN SPECIFICATIONS:

1: FACILITY REQUIREMENTS

Dehydration NOT REQUIRED

Dewpoint Monitoring NOT REQUIRED

Condensate BS&W Monitoring REQUIRED

SCADA Monitoring REQUIRED

1.1: FACILITY CONTROL AND MEASUREMENT REQUIREMENTS

Dehydration N/A

Maximum Sales Gas Temperature 50°C

Dewpoint Continues Monitoring Shut-in N/A

BS&W Continues Monitoring Shut-in/Diversion TBD

Metering – Gas Production N/A

Metering – Condensate Production EFM

Metering – Fuel Gas (site supplied) NOT REQUIRED

Metering – Fuel Gas (external ) NOT REQUIRED

2: PIPELINE TIE-IN REQUIREMENTS

ESD Valve REQUIRED Check Valve REQUIRED Insulating Kit REQUIRED Future Connection REQUIRED Corrosion Monitoring Coupon REQUIRED Corrosion Inhibitor Injection NOT REQUIRED (Batch Only)

Type NALCO Champion

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Methanol NONE

Sulphur Dispersants - Solvents NONE

Operational Liquids NONE (Solvents / Frac. Fluids / PL Initial Batch / …)

Operational Gasses NONE (N2 / CO2 / Air / … )

Water NONE

2.2: PIPELINE TIE-IN CONTROL AND MEASUREMENT REQUIREMENTS

Pressure Monitoring REQUIRED ESD Valve Position REQUIRED Remote ESD REQUIRED ESD – Local PSHH (High Pressure Shutdown Device) REQUIRED ESD – Local PSLL (Low Pressure Shutdown Device) REQUIRED

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E. KAY-160 SPOTTER PIPELINE

GENERAL DESCRIPTION

The Spotter Pipeline is a 10” pipeline which transports High Pressure Dry Sour Gas 64 km from 03-36-056-22W5 to the KA Gas Plant located at 01-12-062-20W5. ESD Valve Stations and Tie-in points are installed along the length at several locations.

PIPELINE SPECIFICATIONS:

PIPELINE STATIC DATA

Pipeline Substance High Pressure Dry Sour Gas

Pipeline License # 34025 Line 1 License H2S 31 %

Pipeline Diameter 10” (273.1mm) Pipeline Length 63.85 km

Maximum Operating Pres. 10,200 kPag Normal Operating Pres. 5000 – 9000 kPag

ANSI Rating 600 RTJ

TIE-IN / ESD LOCATIONS

STN 01 03-36-056-22W5 Manual Block Valve

STN 02 06-34-057-21W5 ESD Valve Station

STN 03 06-18-058-20W5 ESD Valve Station

STN 04 05-19-058-20W5 ESD Valve Station

STN 415 06-05-059-20W5 K3 Fir Pipeline Interconnect

STN 05 15-17-059-20W5 ESD Valve Station

STN 06 13-16-060-20W5 ESD Valve Station

STN 07 08-35-060-20W5 ESD Valve Station

STN 08 05-30-060-19W5 ESD Valve Station

STN 09 04-12-062-20W5 ESD Valve Station

FACILITY AND PIPELINE TIE-IN SPECIFICATIONS:

1: FACILITY REQUIREMENTS

Dehydration REQUIRED

Dewpoint Monitoring REQUIRED

Condensate BS&W Monitoring REQUIRED

SCADA Monitoring REQUIRED

1.1: FACILITY CONTROL AND MEASUREMENT REQUIREMENTS

Dehydration Glycol / Mole-Sieve

Maximum Sales Gas Temperature 50°C

Dewpoint Continues Monitoring Shut-in -10

BS&W Continues Monitoring Shut-in/Diversion TBD

Metering – Gas Production EFM

Metering – Condensate Production EFM

Metering – Fuel Gas (site supplied) EFM Metered or Estimate

Metering – Fuel Gas (external ) NOT REQUIRED

2: PIPELINE TIE-IN REQUIREMENTS

ESD Valve REQUIRED Check Valve REQUIRED Insulating Kit REQUIRED Future Connection REQUIRED

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Corrosion Monitoring Coupon REQUIRED Corrosion Inhibitor Injection REQUIRED

Type NALCO Champion R-2378

Methanol NONE

Sulphur Dispersants - Solvents NONE

Operational Liquids NONE (Solvents / Frac. Fluids / PL Initial Batch / …)

Operational Gasses NONE (N2 / CO2 / Air / … )

Water NONE

2.2: PIPELINE TIE-IN CONTROL AND MEASUREMENT REQUIREMENTS

Pressure Monitoring REQUIRED ESD Valve Position REQUIRED Remote ESD REQUIRED ESD – Local PSHH (High Pressure Shutdown Device) REQUIRED ESD – Local PSLL (Low Pressure Shutdown Device) REQUIRED

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F. KAY-210 DUNVEGAN PIPELINE

GENERAL DESCRIPTION

The Dunvegan Sweet Gas Pipeline is a 10” Pipeline which transports High Pressure Dry Sweet Gas 25 Km from 07-10-061-22W5 (Dunvegan Extension) to the SemCAMS KA Gas Plant located at 01-12-062-20W5. Valve Stations and Tie-in points are installed along the length at several locations. Interconnection with other pipeline systems and processing plants has been utilized to re-route gas from one system / plant to another as required.

PIPELINE SPECIFICATIONS:

PIPELINE STATIC DATA

Pipeline Substance High Pressure Dry Sweet Gas

Pipeline License # 27531 Line 1 License H2S 0 %

Pipeline Diameter 10” (273.1mm) Pipeline Length 25 km

Maximum Operating Pres. 12,000 kPag Normal Operating Pres. 6500 – 7500 kPag

ANSI Rating 900 RTJ

TIE-IN / ESD LOCATIONS

STN 01 07-10-061-22W5 Manual Block Valve

STN 112 05-11-061-22W5 Manual Block Valve

STN 02 07-22-061-21W5 Surface Riser

STN 03 01-25-061-21W5 Surface Riser

STN 04 11-35-061-20W5 Surface Riser

STN 05 13-01-062-20W5 Manual Block Valve

STN 06 04-12-062-20W5 Manual Block Valve

FACILITY AND PIPELINE TIE-IN SPECIFICATIONS:

1: FACILITY REQUIREMENTS

Dehydration REQUIRED

Dewpoint Monitoring REQUIRED

Condensate BS&W Monitoring REQUIRED

SCADA Monitoring REQUIRED

1.1: FACILITY CONTROL AND MEASUREMENT REQUIREMENTS

Dehydration Glycol / Mole-Sieve

Maximum Sales Gas Temperature 50°C

Dewpoint Continues Monitoring Shut-in -10

BS&W Continues Monitoring Shut-in/Diversion TBD

Metering – Gas Production EFM

Metering – Condensate Production EFM

Metering – Fuel Gas (site supplied) EFM Metered or Estimate

Metering – Fuel Gas (external ) NOT REQUIRED

2: PIPELINE TIE-IN REQUIREMENTS

ESD Valve REQUIRED Check Valve REQUIRED Insulating Kit REQUIRED Future Connection REQUIRED Corrosion Monitoring Coupon NOT REQUIRED Corrosion Inhibitor Injection REQUIRED

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Type NALCO Champion

Methanol NONE

Sulphur Dispersants - Solvents NONE

Operational Liquids NONE (Solvents / Frac. Fluids / PL Initial Batch / …)

Operational Gasses NONE (N2 / CO2 / Air / … )

Water NONE

2.2: PIPELINE TIE-IN CONTROL AND MEASUREMENT REQUIREMENTS

Pressure Monitoring REQUIRED ESD Valve Position REQUIRED Remote ESD REQUIRED ESD – Local PSHH (High Pressure Shutdown Device) REQUIRED ESD – Local PSLL (Low Pressure Shutdown Device) REQUIRED

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G. KAY-211 DUNVEGAN EXTENSION PIPELINE

GENERAL DESCRIPTION

The Dunvegan Extension Sweet Gas Pipeline is an 8” which transports High Pressure Dry Sweet Gas 5 Kilometers from 15-24-060-22W5 to the 07-10-062-22W5 (Dunvegan Shallow Gas Pipeline). Valve Stations and Tie-in points are installed along the length at several locations. Interconnection with other pipeline systems and processing plants has been utilized to re-route gas from one system / plant to another as required.

PIPELINE SPECIFICATIONS:

PIPELINE STATIC DATA

Pipeline Substance High Pressure Dry Sweet Gas

Pipeline License # 45559 Line 1 License H2S 0 %

Pipeline Diameter 8” (219.1mm) Pipeline Length 5 km

Maximum Operating Pres. 12,000 kPag Normal Operating Pres. 6500 – 7500 kPag

ANSI Rating 900 RTJ

TIE-IN / ESD LOCATIONS

STN 01 15-24-060-22W5 Manual Block Valve

STN 02 02-10-061-22W5 Manual Block Valve

FACILITY AND PIPELINE TIE-IN SPECIFICATIONS:

1: FACILITY REQUIREMENTS

Dehydration REQUIRED

Dewpoint Monitoring REQUIRED

Condensate BS&W Monitoring REQUIRED

SCADA Monitoring REQUIRED

1.1: FACILITY CONTROL AND MEASUREMENT REQUIREMENTS

Dehydration Glycol / Mole-Sieve

Maximum Sales Gas Temperature 50°C

Dewpoint Continues Monitoring Shut-in -10°C

BS&W Continues Monitoring Shut-in/Diversion TBD

Metering – Gas Production EFM

Metering – Condensate Production EFM

Metering – Fuel Gas (site supplied) EFM Metered or Estimate

Metering – Fuel Gas (external ) NOT REQUIRED

2: PIPELINE TIE-IN REQUIREMENTS

ESD Valve REQUIRED Check Valve REQUIRED Insulating Kit REQUIRED Future Connection REQUIRED Corrosion Monitoring Coupon NOT REQUIRED Corrosion Inhibitor Injection REQUIRED

Type NALCO Champion

Methanol NONE

Sulphur Dispersants - Solvents NONE

Operational Liquids NONE (Solvents / Frac. Fluids / PL Initial Batch / …)

Operational Gasses NONE (N2 / CO2 / Air / … )

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Water NONE

2.2: PIPELINE TIE-IN CONTROL AND MEASUREMENT REQUIREMENTS

Pressure Monitoring REQUIRED ESD Valve Position REQUIRED Remote ESD REQUIRED ESD – Local PSHH (High Pressure Shutdown Device) REQUIRED ESD – Local PSLL (Low Pressure Shutdown Device) REQUIRED

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H. KAY-220 BIGSTONE NGL (HVP) PIPELINE

GENERAL DESCRIPTION

The Bigstone NGL Pipeline is a 4” Pipeline which transports NGL 25.5 Kilometers from 01-10-061-22W5 to the SemCAMS Kaybob Gas Plant located at 03-12-062-20W5. Valve Stations and Tie-in points are installed along the length at several locations.

PIPELINE SPECIFICATIONS:

PIPELINE STATIC DATA

Pipeline Substance Natural Gas Liquid (HVP)

Pipeline License # 27530 Line 1 License H2S 0 %

Pipeline Diameter 4” (114.3mm) Pipeline Length 25.5 km

Maximum Operating Pres. 9930 kPag Normal Operating Pres. 2000 – 3000 kPag

ANSI Rating 600 RTJ

TIE-IN / ESD LOCATIONS

STN 01 02-10-061-22W5 Manual Block Valve

STN 02 07-22-061-21W5 Manual Block Valve

STN 03 06-29-061-20W5 ESD Valve Station

STN 04 05-28-061-20W5 Manual Block Valve

STN 05 13-01-062-20W5 Manual Block Valve

STN 06 03-12-062-20W5 ESD Valve Station

FACILITY AND PIPELINE TIE-IN SPECIFICATIONS:

1: FACILITY REQUIREMENTS

Dehydration NOT REQUIRED

Dewpoint Monitoring NOT REQUIRED

Condensate BS&W Monitoring REQUIRED

SCADA Monitoring REQUIRED

1.1: FACILITY CONTROL AND MEASUREMENT REQUIREMENTS

Dehydration N/A

Maximum Sales Gas Temperature 50°C

Dewpoint Continues Monitoring Shut-in N/A

BS&W Continues Monitoring Shut-in/Diversion TBD

Metering – Gas Production N/A

Metering – Condensate Production EFM

Metering – Fuel Gas (site supplied) EFM Metered or Estimate

Metering – Fuel Gas (external ) NOT REQUIRED

2: PIPELINE TIE-IN REQUIREMENTS

ESD Valve REQUIRED Check Valve REQUIRED Insulating Kit REQUIRED Future Connection REQUIRED Corrosion Monitoring Coupon REQUIRED Corrosion Inhibitor Injection REQUIRED

Type NALCO Champion

Methanol NONE

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Sulphur Dispersants - Solvents NONE

Operational Liquids NONE (Solvents / Frac. Fluids / PL Initial Batch / …)

Operational Gasses NONE (N2 / CO2 / Air / … )

Water NONE

2.2: PIPELINE TIE-IN CONTROL AND MEASUREMENT REQUIREMENTS

Pressure Monitoring REQUIRED ESD Valve Position REQUIRED Remote ESD REQUIRED ESD – Local PSHH (High Pressure Shutdown Device) REQUIRED ESD – Local PSLL (Low Pressure Shutdown Device) REQUIRED

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I. KAY-230 C-POOL PIPELINE

GENERAL DESCRIPTION

The C Pool South Shallow Gas Pipeline is a 6” Pipeline which transports Low Pressure Sweet Gas 6 Kilometers from 16-25-062-20W5 to the SemCAMS Southwest Shallow Gas Pipeline at 12-12-062-20W5 and then into the Kaybob Gas Plant at 01-12-062-20W5. Valve Stations and Tie-in points are installed along the length at several locations.

PIPELINE SPECIFICATIONS:

PIPELINE STATIC DATA

Pipeline Substance Low Pressure Sweet Gas

Pipeline License # 44657 Line 1,2 License H2S 0 %

Pipeline Diameter 6” (168.3mm) Pipeline Length 6.2 km

Maximum Operating Pres. 9930 kPag Normal Operating Pres. 1500 – 2500 kPag

ANSI Rating 600 RTJ

TIE-IN / ESD LOCATIONS

STN 0A 05-31-062-22W5 Out of Service

STN 0B 16-25-062-20W5 Under Ground Tee

STN 01 02-25-062-20W5 Hot Tap

STN 02 07-24-062-20W5 Riser Site

STN 03 12-12-062-20W5 Manual Block Valve

FACILITY AND PIPELINE TIE-IN SPECIFICATIONS:

1: FACILITY REQUIREMENTS

Dehydration NOT REQUIRED

Dewpoint Monitoring NOT REQUIRED

Condensate BS&W Monitoring NOT REQUIRED

SCADA Monitoring REQUIRED

1.1: FACILITY CONTROL AND MEASUREMENT REQUIREMENTS

Dehydration N/A

Maximum Sales Gas Temperature 50°C

Dewpoint Continues Monitoring Shut-in N/A

BS&W Continues Monitoring Shut-in/Diversion N/A

Metering – Gas Production N/A

Metering – Condensate Production EFM

Metering – Fuel Gas (site supplied) EFM Metered or Estimate

Metering – Fuel Gas (external ) NOT REQUIRED

2: PIPELINE TIE-IN REQUIREMENTS

ESD Valve REQUIRED Check Valve REQUIRED Insulating Kit REQUIRED Future Connection REQUIRED Corrosion Monitoring Coupon REQUIRED Corrosion Inhibitor Injection REQUIRED

Type NALCO Champion RU-196

Methanol Inhibited Methanol

Sulphur Dispersants - Solvents NONE

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Operational Liquids NONE (Solvents / Frac. Fluids / PL Initial Batch / …)

Operational Gasses NONE (N2 / CO2 / Air / … )

Water NONE

2.2: PIPELINE TIE-IN CONTROL AND MEASUREMENT REQUIREMENTS

Pressure Monitoring REQUIRED ESD Valve Position REQUIRED Remote ESD REQUIRED ESD – Local PSHH (High Pressure Shutdown Device) REQUIRED ESD – Local PSLL (Low Pressure Shutdown Device) REQUIRED

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J. KAY-250 SOUTHWEST GAS GATHERING SYSTEM

GENERAL DESCRIPTION

The South West Gas Gathering System is a 6” Pipeline which transports Low Pressure Sweet Gas 14.5 Kilometers from 06-02-061-20W5 to the SemCAMS Kaybob Gas Plant located at 01-12-062-20W5. Valve Stations and Tie-in points are installed along the length at several locations. Interconnection with other pipeline systems and processing plants has been utilized to re-route gas from one system / plant to another as required.

PIPELINE SPECIFICATIONS:

PIPELINE STATIC DATA

Pipeline Substance Low Pressure Sweet Gas

Pipeline License # 45122 Line 1,2,3,4,5 License H2S 0 %

Pipeline Diameter 6” (168.3mm) Pipeline Length 15.5 km

Maximum Operating Pres. 9930 kPag Normal Operating Pres. 3000 – 4300 kPag

ANSI Rating 600 RTJ

TIE-IN / ESD LOCATIONS

STN 01 06-02-061-20W5 Manual Block Valve STN 02 10-10-061-20W5 Manual Block Valve STN 03 11-22-061-20W5 Manual Block Valve STN 04 12-34-061-20W5 Manual Block Valve STN 05 08-03-062-20W5 Manual Block Valve

STN 06 16-02-062-20W5 Manual Block Valve STN 617 12-12-062-20W5 Manual Block Valve STN 07 13-01-062-20W5 Manual Block Valve

FACILITY AND PIPELINE TIE-IN SPECIFICATIONS:

1: FACILITY REQUIREMENTS

Dehydration NOT REQUIRED

Dewpoint Monitoring NOT REQUIRED

Condensate BS&W Monitoring NOT REQUIRED

SCADA Monitoring REQUIRED

1.1: FACILITY CONTROL AND MEASUREMENT REQUIREMENTS

Dehydration N/A

Maximum Sales Gas Temperature 50°C

Dewpoint Continues Monitoring Shut-in N/A

BS&W Continues Monitoring Shut-in/Diversion N/A

Metering – Gas Production EFM

Metering – Condensate Production EFM

Metering – Fuel Gas (site supplied) EFM Metered or Estimate

Metering – Fuel Gas (external ) NOT REQUIRED

2: PIPELINE TIE-IN REQUIREMENTS

ESD Valve REQUIRED Check Valve REQUIRED Insulating Kit REQUIRED Future Connection REQUIRED

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Corrosion Monitoring Coupon NOT REQUIRED Corrosion Inhibitor Injection REQUIRED

Type NALCO Champion

Methanol Inhibited Methanol

Sulphur Dispersants - Solvents NONE

Operational Liquids NONE (Solvents / Frac. Fluids / PL Initial Batch / …)

Operational Gasses NONE (N2 / CO2 / Air / … )

Water NONE

2.2: PIPELINE TIE-IN CONTROL AND MEASUREMENT REQUIREMENTS

Pressure Monitoring REQUIRED ESD Valve Position REQUIRED Remote ESD REQUIRED ESD – Local PSHH (High Pressure Shutdown Device) REQUIRED ESD – Local PSLL (Low Pressure Shutdown Device) REQUIRED

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K. KAY-260 EAST VIKING PIPELINE

GENERAL DESCRIPTION

The East Viking Shallow Gas Pipeline is a 6” Pipeline which transports High Pressure Sweet Gas 8.5 Kilometers from 11-10-062-19W5 to the SemCAMS Kaybob Gas Plant located at 01-12-062-20W5. Valve Stations and Tie-in points are installed along the length at several locations. Interconnection with other pipeline systems and processing plants has been utilized to re-route gas from one system / plant to another as required.

PIPELINE SPECIFICATIONS:

PIPELINE STATIC DATA

Pipeline Substance High Pressure Sweet Gas

Pipeline License # 6983 Line 21,22 47149 Line 2

License H2S 0 %

Pipeline Diameter 6”(168.3mm) / 8”(219.1mm) Pipeline Length 8.5 km

Maximum Operating Pres. 8270 kPag Normal Operating Pres. 6200 – 7000 kPag

ANSI Rating 600 RTJ

TIE-IN / ESD LOCATIONS

STN 01 11-10-062-19W5 Manual Block Valve STN 02 09-07-062-19W5 Hot Tap STN 03 12-12-062-20W5 Manual Block Valve STN 04 13-01-062-20W5 Manual Block Valve

FACILITY AND PIPELINE TIE-IN SPECIFICATIONS:

1: FACILITY REQUIREMENTS

Dehydration NOT REQUIRED

Dewpoint Monitoring NOT REQUIRED

Condensate BS&W Monitoring NOT REQUIRED

SCADA Monitoring REQUIRED

1.1: FACILITY CONTROL AND MEASUREMENT REQUIREMENTS

Dehydration N/A

Maximum Sales Gas Temperature 50°C

Dewpoint Continues Monitoring Shut-in N/A

BS&W Continues Monitoring Shut-in/Diversion N/A

Metering – Gas Production EFM

Metering – Condensate Production EFM

Metering – Fuel Gas (site supplied) EFM Metered or Estimate

Metering – Fuel Gas (external ) NOT REQUIRED

2: PIPELINE TIE-IN REQUIREMENTS

ESD Valve REQUIRED Check Valve REQUIRED Insulating Kit REQUIRED Future Connection REQUIRED Corrosion Monitoring Coupon NOT REQUIRED Corrosion Inhibitor Injection REQUIRED

Type NALCO Champion

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Methanol Inhibited Methanol

Sulphur Dispersants - Solvents NONE

Operational Liquids NONE (Solvents / Frac. Fluids / PL Initial Batch / …)

Operational Gasses NONE (N2 / CO2 / Air / … )

Water NONE

2.2: PIPELINE TIE-IN CONTROL AND MEASUREMENT REQUIREMENTS

Pressure Monitoring REQUIRED ESD Valve Position REQUIRED Remote ESD REQUIRED ESD – Local PSHH (High Pressure Shutdown Device) REQUIRED ESD – Local PSLL (Low Pressure Shutdown Device) REQUIRED

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Appendix 4:

WEST FOX CREEK GAS GATHERING

SYSTEM SPECIFICATIONS

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A. KAY-270 WEST FOX CREEK NORTH PIPELINE

GENERAL DESCRIPTION

The West Fox Creek North Pipeline is a 6” Pipeline which transports Low Pressure Sweet Gas 2.98 Kilometers from 07-33-060-19W5 to the SemCAMS West Fox Creek Gas Plant located at 11-22-060-19W5. Valve Stations and Tie-in points are installed at riser locations.

PIPELINE SPECIFICATIONS:

PIPELINE STATIC DATA

Pipeline Substance Low Pressure Sweet Gas

Pipeline License # 45103 Line 1 License H2S 0 %

Pipeline Diameter 6” (168.3mm) Pipeline Length 2.98 km

Maximum Operating Pres. 8960 kPag Normal Operating Pres. 500 – 1000 kPag

ANSI Rating 600 RTJ

TIE-IN / ESD LOCATIONS

STN 01 07-33-060-19W5 Manual Block Valve STN 02 01-33-060-19W5 Manual Block Valve

STN 03 04-27-060-19W5 Manual Block Valve

STN 04 14-22-060-19W5 Manual Block Valve

STN 05 11-22-060-19W5 Manual Block Valve

FACILITY AND PIPELINE TIE-IN SPECIFICATIONS:

1: FACILITY REQUIREMENTS

Dehydration NOT REQUIRED

Dewpoint Monitoring NOT REQUIRED

Condensate BS&W Monitoring NOT REQUIRED

SCADA Monitoring REQUIRED

1.1: FACILITY CONTROL AND MEASUREMENT REQUIREMENTS

Dehydration N/A

Maximum Sales Gas Temperature 50°C

Dewpoint Continues Monitoring Shut-in N/A

BS&W Continues Monitoring Shut-in/Diversion N/A

Metering – Gas Production EFM

Metering – Condensate Production EFM

Metering – Fuel Gas (site supplied) EFM Metered or Estimate

Metering – Fuel Gas (external ) NOT REQUIRED

2: PIPELINE TIE-IN REQUIREMENTS

ESD Valve REQUIRED Check Valve REQUIRED Insulating Kit REQUIRED Future Connection REQUIRED Corrosion Monitoring Coupon NOT REQUIRED Corrosion Inhibitor Injection REQUIRED

Type NALCO Champion

Methanol Inhibited Methanol

Sulphur Dispersants - Solvents NONE

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Operational Liquids NONE (Solvents / Frac. Fluids / PL Initial Batch / …)

Operational Gasses NONE (N2 / CO2 / Air / … )

Water NONE

2.2: PIPELINE TIE-IN CONTROL AND MEASUREMENT REQUIREMENTS

Pressure Monitoring REQUIRED ESD Valve Position REQUIRED Remote ESD REQUIRED ESD – Local PSHH (High Pressure Shutdown Device) REQUIRED ESD – Local PSLL (Low Pressure Shutdown Device) REQUIRED

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B. KAY-271 WEST FOX CREEK NORTH (06-35 Lateral) PIPELINE

GENERAL DESCRIPTION

The West Fox Creek North (06-35 Lateral) Pipeline is a 4” Pipeline which transports Low Pressure Sweet Gas 8.39 Kilometers from 06-35-060-20W5 to 01-33-060-19W5. Valve Stations and Tie-in points are installed at riser locations.

PIPELINE SPECIFICATIONS:

PIPELINE STATIC DATA

Pipeline Substance Low Pressure Sweet Gas

Pipeline License # 45739 Line 3 45103 Line 1,2,3

License H2S 0 %

Pipeline Diameter 4” (114.3mm) Pipeline Length 8.39 km

Maximum Operating Pres. 8960 kPag Normal Operating Pres. 500 – 1000 kPag

ANSI Rating 600 RTJ

TIE-IN / ESD LOCATIONS

STN 01 06-35-060-20W5 Manual Block Valve STN 02 11-25-060-20W5 Manual Block Valve

STN 03 01-33-060-19W5 Manual Block Valve

FACILITY AND PIPELINE TIE-IN SPECIFICATIONS:

1: FACILITY REQUIREMENTS

Dehydration NOT REQUIRED

Dewpoint Monitoring NOT REQUIRED

Condensate BS&W Monitoring NOT REQUIRED

SCADA Monitoring REQUIRED

1.1: FACILITY CONTROL AND MEASUREMENT REQUIREMENTS

Dehydration N/A

Maximum Sales Gas Temperature 50°C

Dewpoint Continues Monitoring Shut-in N/A

BS&W Continues Monitoring Shut-in/Diversion N/A

Metering – Gas Production EFM

Metering – Condensate Production EFM

Metering – Fuel Gas (site supplied) EFM Metered or Estimate

Metering – Fuel Gas (external ) NOT REQUIRED

2: PIPELINE TIE-IN REQUIREMENTS

ESD Valve REQUIRED Check Valve REQUIRED Insulating Kit REQUIRED Future Connection REQUIRED Corrosion Monitoring Coupon NOT REQUIRED Corrosion Inhibitor Injection REQUIRED

Type NALCO Champion

Methanol Inhibited Methanol

Sulphur Dispersants - Solvents NONE

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Operational Liquids NONE (Solvents / Frac. Fluids / PL Initial Batch / …)

Operational Gasses NONE (N2 / CO2 / Air / … )

Water NONE

2.2: PIPELINE TIE-IN CONTROL AND MEASUREMENT REQUIREMENTS

Pressure Monitoring REQUIRED ESD Valve Position REQUIRED Remote ESD REQUIRED ESD – Local PSHH (High Pressure Shutdown Device) REQUIRED ESD – Local PSLL (Low Pressure Shutdown Device) REQUIRED

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C. KAY-272 WEST FOX CREEK NORTH (06-27 Lateral) PIPELINE

GENERAL DESCRIPTION

The West Fox Creek North (06-27 Lateral) Pipeline is a 4” Pipeline which transports Low Pressure Sweet Gas 0.4 Kilometers from 06-27-060-19W5 to 04-27-060-19W5. Valve Stations and Tie-in points are installed at riser locations.

PIPELINE SPECIFICATIONS:

PIPELINE STATIC DATA

Pipeline Substance Low Pressure Sweet Gas

Pipeline License # 45739 Line 3 45103 Line 1,2,3

License H2S 0 %

Pipeline Diameter 4” (114.3mm) Pipeline Length 0.4 km

Maximum Operating Pres. 8960 kPag Normal Operating Pres. 500 – 1000 kPag

ANSI Rating 600 RTJ

TIE-IN / ESD LOCATIONS

STN 01 06-27-060-19W5 Manual Block Valve STN 02 04-27-060-19W5 Manual Block Valve

FACILITY AND PIPELINE TIE-IN SPECIFICATIONS:

1: FACILITY REQUIREMENTS

Dehydration NOT REQUIRED

Dewpoint Monitoring NOT REQUIRED

Condensate BS&W Monitoring NOT REQUIRED

SCADA Monitoring REQUIRED

1.1: FACILITY CONTROL AND MEASUREMENT REQUIREMENTS

Dehydration N/A

Maximum Sales Gas Temperature 50°C

Dewpoint Continues Monitoring Shut-in N/A

BS&W Continues Monitoring Shut-in/Diversion N/A

Metering – Gas Production EFM

Metering – Condensate Production EFM

Metering – Fuel Gas (site supplied) EFM Metered or Estimate

Metering – Fuel Gas (external ) NOT REQUIRED

2: PIPELINE TIE-IN REQUIREMENTS

ESD Valve REQUIRED Check Valve REQUIRED Insulating Kit REQUIRED Future Connection REQUIRED Corrosion Monitoring Coupon NOT REQUIRED Corrosion Inhibitor Injection REQUIRED

Type NALCO Champion

Methanol Inhibited Methanol

Sulphur Dispersants - Solvents NONE

Operational Liquids NONE (Solvents / Frac. Fluids / PL Initial Batch / …)

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Operational Gasses NONE (N2 / CO2 / Air / … )

Water NONE

2.2: PIPELINE TIE-IN CONTROL AND MEASUREMENT REQUIREMENTS

Pressure Monitoring REQUIRED ESD Valve Position REQUIRED Remote ESD REQUIRED ESD – Local PSHH (High Pressure Shutdown Device) REQUIRED ESD – Local PSLL (Low Pressure Shutdown Device) REQUIRED

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D. KAY-273 WEST FOX CREEK NORTH EAST PIPELINE

GENERAL DESCRIPTION

The West Fox Creek North East Pipeline is a 3” Pipeline which transports Low Pressure Sweet Gas 2 Kilometers from 06-26-060-19W5 to the SemCAMS West Fox Creek Gas Plant located at 11-22-060-19W5. Valve Stations and Tie-in points are installed at riser locations.

PIPELINE SPECIFICATIONS:

PIPELINE STATIC DATA

Pipeline Substance Low Pressure Sweet Gas

Pipeline License # 17325 Line 3 License H2S 0 %

Pipeline Diameter 3” (88.9mm) Pipeline Length 2 km

Maximum Operating Pres. 8960 kPag Normal Operating Pres. 500 – 1000 kPag

ANSI Rating 600 RTJ

TIE-IN / ESD LOCATIONS

STN 01 06-26-060-19W5 Manual Block Valve STN 02 10-22-060-19W5 Manual Block Valve

STN 03 11-22-060-19W5 Manual Block Valve

FACILITY AND PIPELINE TIE-IN SPECIFICATIONS:

1: FACILITY REQUIREMENTS

Dehydration NOT REQUIRED

Dewpoint Monitoring NOT REQUIRED

Condensate BS&W Monitoring NOT REQUIRED

SCADA Monitoring REQUIRED

1.1: FACILITY CONTROL AND MEASUREMENT REQUIREMENTS

Dehydration N/A

Maximum Sales Gas Temperature 50°C

Dewpoint Continues Monitoring Shut-in N/A

BS&W Continues Monitoring Shut-in/Diversion N/A

Metering – Gas Production EFM

Metering – Condensate Production EFM

Metering – Fuel Gas (site supplied) EFM Metered or Estimate

Metering – Fuel Gas (external ) NOT REQUIRED

2: PIPELINE TIE-IN REQUIREMENTS

ESD Valve REQUIRED Check Valve REQUIRED Insulating Kit REQUIRED Future Connection REQUIRED Corrosion Monitoring Coupon NOT REQUIRED Corrosion Inhibitor Injection REQUIRED

Type NALCO Champion

Methanol Inhibited Methanol

Sulphur Dispersants - Solvents NONE

Operational Liquids NONE (Solvents / Frac. Fluids / PL Initial Batch / …)

Operational Gasses NONE (N2 / CO2 / Air / … )

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Water NONE

2.2: PIPELINE TIE-IN CONTROL AND MEASUREMENT REQUIREMENTS

Pressure Monitoring REQUIRED ESD Valve Position REQUIRED Remote ESD REQUIRED ESD – Local PSHH (High Pressure Shutdown Device) REQUIRED ESD – Local PSLL (Low Pressure Shutdown Device) REQUIRED

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E. KAY-280 WEST FOX CREEK SOUTH PIPELINE

GENERAL DESCRIPTION

The West Fox Creek South Pipeline is a 4” & 6” Pipeline which transports High Pressure Sweet Gas 10.52 Kilometers from 07-22-059-19W5 to the West Fox Creek Gas Plat at 11-22-060-19W5. Valve Stations and Tie-in points are installed at riser locations.

PIPELINE SPECIFICATIONS:

PIPELINE STATIC DATA

Pipeline Substance High Pressure Sweet Gas

Pipeline License # 45739 Line 4 45103 Line 5,6,7

License H2S 0 %

Pipeline Diameter 4” (114.3mm) 6” (168.3mm)

Pipeline Length 10.52 km

Maximum Operating Pres. 8960 kPag Normal Operating Pres. 500 – 1000 kPag

ANSI Rating 600 RTJ

TIE-IN / ESD LOCATIONS

STN 01 07-22-059-19W5 Manual Block Valve STN 02 11-27-059-19W5 Manual Block Valve

STN 03 11-34-059-19W5 Manual Block Valve

STN 04 11-03-060-19W5 Manual Block Valve

STN 05 11-22-060-19W5 Manual Block Valve

STN 05 11-22-060-19W5 Manual Block Valve

FACILITY AND PIPELINE TIE-IN SPECIFICATIONS:

1: FACILITY REQUIREMENTS

Dehydration NOT REQUIRED

Dewpoint Monitoring NOT REQUIRED

Condensate BS&W Monitoring NOT REQUIRED

SCADA Monitoring REQUIRED

1.1: FACILITY CONTROL AND MEASUREMENT REQUIREMENTS

Dehydration N/A

Maximum Sales Gas Temperature 50°C

Dewpoint Continues Monitoring Shut-in N/A

BS&W Continues Monitoring Shut-in/Diversion N/A

Metering – Gas Production EMF

Metering – Condensate Production EFM

Metering – Fuel Gas (site supplied) EFM Metered or Estimate

Metering – Fuel Gas (external ) NOT REQUIRED

2: PIPELINE TIE-IN REQUIREMENTS

ESD Valve REQUIRED Check Valve REQUIRED Insulating Kit REQUIRED Future Connection REQUIRED Corrosion Monitoring Coupon NOT REQUIRED Corrosion Inhibitor Injection REQUIRED

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Type NALCO Champion

Methanol Inhibited Methanol

Sulphur Dispersants - Solvents NONE

Operational Liquids NONE (Solvents / Frac. Fluids / PL Initial Batch / …)

Operational Gasses NONE (N2 / CO2 / Air / … )

Water NONE

2.2: PIPELINE TIE-IN CONTROL AND MEASUREMENT REQUIREMENTS

Pressure Monitoring REQUIRED ESD Valve Position REQUIRED Remote ESD REQUIRED ESD – Local PSHH (High Pressure Shutdown Device) REQUIRED ESD – Local PSLL (Low Pressure Shutdown Device) REQUIRED

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F. KAY-281 WEST FOX CREEK SOUTH (06-35 Lateral) PIPELINE

GENERAL DESCRIPTION

The West Fox Creek South (06-35 Lateral) Pipeline is a 4” Pipeline which transports High Pressure Sweet Gas 1.5 Kilometers from 06-35-059-19W5 to 11-34-059-19W5. Valve Stations and Tie-in points are installed at riser several locations.

PIPELINE SPECIFICATIONS:

PIPELINE STATIC DATA

Pipeline Substance High Pressure Sweet Gas

Pipeline License # 45739 Line 5 License H2S 0 %

Pipeline Diameter 4” (114.3mm) Pipeline Length 1.5 km

Maximum Operating Pres. 9000 kPag Normal Operating Pres. 5500 – 6000 kPag

ANSI Rating 600 RTJ

TIE-IN / ESD LOCATIONS

STN 01 06-35-059-19W5 Manual Block Valve STN 02 05-35-059-19W5 Manual Block Valve

STN 03 11-34-059-19W5 Manual Block Valve

FACILITY AND PIPELINE TIE-IN SPECIFICATIONS:

1: FACILITY REQUIREMENTS

Dehydration NOT REQUIRED

Dewpoint Monitoring NOT REQUIRED

Condensate BS&W Monitoring NOT REQUIRED

SCADA Monitoring REQUIRED

1.1: FACILITY CONTROL AND MEASUREMENT REQUIREMENTS

Dehydration N/A

Maximum Sales Gas Temperature 50°C

Dewpoint Continues Monitoring Shut-in N/A

BS&W Continues Monitoring Shut-in/Diversion N/A

Metering – Gas Production EFM

Metering – Condensate Production EFM

Metering – Fuel Gas (site supplied) EFM Metered or Estimate

Metering – Fuel Gas (external ) NOT REQUIRED

2: PIPELINE TIE-IN REQUIREMENTS

ESD Valve REQUIRED Check Valve REQUIRED Insulating Kit REQUIRED Future Connection REQUIRED Corrosion Monitoring Coupon NOT REQUIRED Corrosion Inhibitor Injection REQUIRED

Type NALCO Champion

Methanol Inhibited Methanol

Sulphur Dispersants - Solvents NONE

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Operational Liquids NONE (Solvents / Frac. Fluids / PL Initial Batch / …)

Operational Gasses NONE (N2 / CO2 / Air / … )

Water NONE

2.2: PIPELINE TIE-IN CONTROL AND MEASUREMENT REQUIREMENTS

Pressure Monitoring REQUIRED ESD Valve Position REQUIRED Remote ESD REQUIRED ESD – Local PSHH (High Pressure Shutdown Device) REQUIRED ESD – Local PSLL (Low Pressure Shutdown Device) REQUIRED

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G. KAY-282 WEST FOX CREEK SOUTH (08-03 Suction) PIPELINE

GENERAL DESCRIPTION

The West Fox Creek South (08-03 Suction) Pipeline is a 4” Pipeline which transports Low Pressure Sweet Gas 0.73 Kilometers from 11-03-060-19W5 to the 08-03-060-19W5 compressor station. Valve Stations and Tie-in points are installed at riser locations.

PIPELINE SPECIFICATIONS:

PIPELINE STATIC DATA

Pipeline Substance Low Pressure Sweet Gas

Pipeline License # 45103 Line 9 License H2S 0 %

Pipeline Diameter 6” (168.3mm) Pipeline Length 0.73 km

Maximum Operating Pres. 8960 kPag Normal Operating Pres. 500 – 1000 kPag

ANSI Rating 600 RTJ

TIE-IN / ESD LOCATIONS

STN 01 11-03-060-19W5 Manual Block Valve STN 02 08-03-060-19W5 Manual Block Valve

FACILITY AND PIPELINE TIE-IN SPECIFICATIONS:

1: FACILITY REQUIREMENTS

Dehydration NOT REQUIRED

Dewpoint Monitoring NOT REQUIRED

Condensate BS&W Monitoring NOT REQUIRED

SCADA Monitoring REQUIRED

1.1: FACILITY CONTROL AND MEASUREMENT REQUIREMENTS

Dehydration N/A

Maximum Sales Gas Temperature 50°C

Dewpoint Continues Monitoring Shut-in N/A

BS&W Continues Monitoring Shut-in/Diversion N/A

Metering – Gas Production EFM

Metering – Condensate Production EFM

Metering – Fuel Gas (site supplied) EFM Metered or Estimate

Metering – Fuel Gas (external ) NOT REQUIRED

2: PIPELINE TIE-IN REQUIREMENTS

ESD Valve REQUIRED Check Valve REQUIRED Insulating Kit REQUIRED Future Connection REQUIRED Corrosion Monitoring Coupon NOT REQUIRED Corrosion Inhibitor Injection REQUIRED

Type NALCO Champion

Methanol Inhibited Methanol

Sulphur Dispersants - Solvents NONE

Operational Liquids NONE (Solvents / Frac. Fluids / PL Initial Batch / …)

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Operational Gasses NONE (N2 / CO2 / Air / … )

Water NONE

2.2: PIPELINE TIE-IN CONTROL AND MEASUREMENT REQUIREMENTS

Pressure Monitoring REQUIRED ESD Valve Position REQUIRED Remote ESD REQUIRED ESD – Local PSHH (High Pressure Shutdown Device) REQUIRED ESD – Local PSLL (Low Pressure Shutdown Device) REQUIRED

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H. KAY-283 WEST FOX CREEK SOUTH (08-03 Discharge) PIPELINE

GENERAL DESCRIPTION

The West Fox Creek South (08-03 Discharge) Pipeline is a 4” Pipeline which transports Low Pressure Sweet Gas 0.73 Kilometers from the 08-03-060-19W5 compressor station to 11-03-060-19W5. Valve Stations and Tie-in points are installed at riser locations.

PIPELINE SPECIFICATIONS:

PIPELINE STATIC DATA

Pipeline Substance Low Pressure Sweet Gas

Pipeline License # 45103 Line 8 License H2S 0 %

Pipeline Diameter 4” (114.3mm) Pipeline Length 0.73 km

Maximum Operating Pres. 8960 kPag Normal Operating Pres. 5500 – 6000 kPag

ANSI Rating 600 RTJ

TIE-IN / ESD LOCATIONS

STN 01 08-03-060-19W5 Manual Block Valve STN 02 11-03-060-19W5 Manual Block Valve

FACILITY AND PIPELINE TIE-IN SPECIFICATIONS:

1: FACILITY REQUIREMENTS

Dehydration NOT REQUIRED

Dewpoint Monitoring NOT REQUIRED

Condensate BS&W Monitoring NOT REQUIRED

SCADA Monitoring REQUIRED

1.1: FACILITY CONTROL AND MEASUREMENT REQUIREMENTS

Dehydration N/A

Maximum Sales Gas Temperature 50°C

Dewpoint Continues Monitoring Shut-in N/A

BS&W Continues Monitoring Shut-in/Diversion N/A

Metering – Gas Production EFM

Metering – Condensate Production EFM

Metering – Fuel Gas (site supplied) EFM Metered or Estimate

Metering – Fuel Gas (external ) NOT REQUIRED

2: PIPELINE TIE-IN REQUIREMENTS

ESD Valve REQUIRED Check Valve REQUIRED Insulating Kit REQUIRED Future Connection REQUIRED Corrosion Monitoring Coupon NOT REQUIRED Corrosion Inhibitor Injection REQUIRED

Type NALCO Champion

Methanol Inhibited Methanol

Sulphur Dispersants - Solvents NONE

Operational Liquids NONE (Solvents / Frac. Fluids / PL Initial Batch / …)

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Operational Gasses NONE (N2 / CO2 / Air / … )

Water NONE

2.2: PIPELINE TIE-IN CONTROL AND MEASUREMENT REQUIREMENTS

Pressure Monitoring REQUIRED ESD Valve Position REQUIRED Remote ESD REQUIRED ESD – Local PSHH (High Pressure Shutdown Device) REQUIRED ESD – Local PSLL (Low Pressure Shutdown Device) REQUIRED

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I. KAY-284 WEST FOX CREEK (10-22 Lateral) PIPELINE

GENERAL DESCRIPTION

The West Fox Creek (10-22 Lateral) Pipeline is a 3” Pipeline which transports Low Pressure Sweet Gas 0.49 Kilometers from 10-22-060-19W5 to the West Fox Creek Gas Plant at 11-22-060-19W5 compressor station. Valve Stations and Tie-in points are installed at riser locations.

PIPELINE SPECIFICATIONS:

PIPELINE STATIC DATA

Pipeline Substance Low Pressure Sweet Gas

Pipeline License # 15379 Line 1,2 License H2S 0 %

Pipeline Diameter 3” (88.9mm) Pipeline Length 0.49 km

Maximum Operating Pres. 8960 kPag Normal Operating Pres. 500 – 1000 kPag

ANSI Rating 600 RTJ

TIE-IN / ESD LOCATIONS

STN 01 10-22-060-19W5 Manual Block Valve STN 02 11-22-060-19W5 Manual Block Valve

FACILITY AND PIPELINE TIE-IN SPECIFICATIONS:

1: FACILITY REQUIREMENTS

Dehydration NOT REQUIRED

Dewpoint Monitoring NOT REQUIRED

Condensate BS&W Monitoring NOT REQUIRED

SCADA Monitoring REQUIRED

1.1: FACILITY CONTROL AND MEASUREMENT REQUIREMENTS

Dehydration N/A

Maximum Sales Gas Temperature 50°C

Dewpoint Continues Monitoring Shut-in N/A

BS&W Continues Monitoring Shut-in/Diversion N/A

Metering – Gas Production EFM

Metering – Condensate Production EFM

Metering – Fuel Gas (site supplied) EFM Metered or Estimate

Metering – Fuel Gas (external ) NOT REQUIRED

2: PIPELINE TIE-IN REQUIREMENTS

ESD Valve REQUIRED Check Valve REQUIRED Insulating Kit REQUIRED Future Connection REQUIRED Corrosion Monitoring Coupon NOT REQUIRED Corrosion Inhibitor Injection REQUIRED

Type NALCO Champion

Methanol Inhibited Methanol

Sulphur Dispersants - Solvents NONE

Operational Liquids NONE (Solvents / Frac. Fluids / PL Initial Batch / …)

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Operational Gasses NONE (N2 / CO2 / Air / … )

Water NONE

2.2: PIPELINE TIE-IN CONTROL AND MEASUREMENT REQUIREMENTS

Pressure Monitoring REQUIRED ESD Valve Position REQUIRED Remote ESD REQUIRED ESD – Local PSHH (High Pressure Shutdown Device) REQUIRED ESD – Local PSLL (Low Pressure Shutdown Device) REQUIRED


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