BALZAC THERMAL ELETRIC POWER PLANT
Transcript of BALZAC THERMAL ELETRIC POWER PLANT
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BALZAC SOUR GAS PROCESSING PLANT AND
THE BALZAC SULPHUR PROCESSING PLANT
(‘BALZAC GAS PLANT’)
APPLICATION TO
ALBERTA ENVIRONMENT
FOR
AMENDMENT OF
APPROVAL NUMBER: 155-02-00
FOR
DECOMMISSIONING, DISMANTLING, ABANDONMENT, REMEDIATION &
RECLAMATION OF THE BALZAC GAS PLANT
March 5, 2012
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INTRODUCTION ............................................................................................................................................. 5
3 (1) AN APPLICATION MUST BE MADE TO THE DIRECTOR AND MUST BE ACCOMPANIED
BY THE FOLLOWING INFORMATION RELATIVE TO THE ACTIVITY, THE CHANGE IN THE
ACTIVITY OR THE PROPOSED AMENDMENT, ADDITION OR DELETION OF THE TERM OR
CONDITION: .................................................................................................................................................... 8
A. APPLICANT INFORMATION ..................................................................................................................... 8 B. LOCATION, CAPACITY AND SIZE OF THE ACTIVITY ................................................................................. 9
1. Legal Land Description .................................................................................................................... 9 2. Relation to nearest town, city, village, and residents/users of the land. ........................................... 9 3. Geographical description of the surrounding topography (including a topographical map) and
relation to nearby watercourses................................................................................................................. 9 4. Gas Processing Capacity (Raw), Hydrogen Sulphide Processing Capacity, Sulphur Inlet Rate. .... 9 5. Sulphur Production Capacity, Liquid Hydrocarbon Production, Sulphur Storage Status, Bitumen
Processing Capacity, Other. ...................................................................................................................... 9 6. Material Balance. ........................................................................................................................... 10 7. Descriptive size of the affected area, leased area, and/or plant site (Le., hectares), or ................. 10 8. Physical dimensions of the plant site including a plant site map (i.e., plot plan) and number of
employees working at the facility. ............................................................................................................ 10
C. THE NATURE OF THE ACTIVITY, THE CHANGE TO THE ACTIVITY OR THE
AMENDMENT, ADDITION OR DELETION, AS THE CASE MAY BE: ............................................... 13
APPLICATIONS FOR ACTIVITY CHANGE OR AN AMENDMENT ........................................................................ 13 3.1 Describe the change(s). .................................................................................................................. 13
3.1.1 HISTORY OF THE PLANT ................................................................................................................. 13 3.1.2 CURRENT PHASE OF THE PROJECT .............................................................................................. 13 3.1.3 FACILITIES TO REMAIN IN OPERATION DURING THE DRR PROJECT PHASE ..................... 15 3.1.4 FACILITIES TO REMAIN IN OPERATION DURING THE DLR PROJECT PHASE ..................... 17
3.2 Describe the affect that the change(s) may have on the environment. ........................................... 20 3.3 Describe the affect that the change(s) may have on the Environment Control Systems. ................ 20 3.4 Describe the implications, which the change(s) may have on the current approval. ..................... 20 3.5 Describe when the changes will take place. ................................................................................... 23
D. WHERE THE APPLICATION REQUIRES AN APPROVAL FROM THE ALBERTA ENERGY
AND UTILITIES BOARD OR THE NATURAL RESOURCES CONSERVATION BOARD IN
RELATION TO THE ACTIVITY, THE DATE OF THE WRITTEN DECISION IN RESPECT OF
THE APPLICATION ...................................................................................................................................... 23
1. DATE OF ALBERTA ENERGY AND UTILITIES BOARD (EUB) APPROVAL............................................... 23 2. APPROVAL NUMBER ............................................................................................................................ 23
E. AN INDICATION OF WHETHER AN ENVIRONMENTAL IMPACT ASSESSMENT (EIA)
REPORT HAS BEEN REQUIRED ............................................................................................................... 23
1. WAS AN EIA REQUIRED? ..................................................................................................................... 23
F. COPIES OF EXISTING APPROVALS THAT WERE ISSUED TO THE APPLICANT IN
RESPECT OF THE ACTIVITY UNDER THIS ACT OR A PREDECESSOR OF THIS ACT ............. 23
G. THE PROPOSED OR ACTUAL DATES FOR CONSTRUCTION COMMENCEMENT,
CONSTRUCTION COMPLETION, AND COMMENCEMENT OF OPERATION .............................. 24
3.1 PROVIDE ACTUAL DATE FOR ORIGINAL COMMENCEMENT OF OPERATION, IF KNOWN. .......................... 24 3.2 PROVIDE PROPOSED EFFECTIVE DATE FOR "ACTIVITY CHANGE" AND/OR AMENDMENT. ..................... 24
H. A LIST OF SUBSTANCES, THE SOURCES OF THE SUBSTANCES AND THE AMOUNT OF
EACH SUBSTANCE THAT WILL BE RELEASED INTO THE ENVIRONMENT AS A RESULT OF
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THE ACTIVITY, THE CHANGE TO THE ACTIVITY OR THE AMENDMENT, ADDITION OR
DELETION, AS THE CASE MAY BE, THE METHOD BY WHICH THE SUBSTANCES WILL BE
RELEASED AND THE STEPS TAKEN TO REDUCE THE AMOUNT OF THE SUBSTANCES
RELEASED. .................................................................................................................................................... 24
APPLICATIONS FOR ACTIVITY CHANGE OR AN AMENDMENT ........................................................................ 24 3.1 Provide a description of current substance releases. ..................................................................... 24 3.2 Describe the implications to the above description as a result of the Activity Change. ................. 24 3.3 Provide the final modified description that will result after the Activity Change is operational. .. 24
I. A SUMMARY OF THE ENVIRONMENTAL MONITORING INFORMATION GATHERED
DURING THE PREVIOUS APPROVAL PERIOD .................................................................................... 25
APPLICATIONS FOR ACTIVITY CHANGE OR AN AMENDMENT ........................................................................ 25 1. Only monitoring information on the affected parameters is required. ........................................... 25
J. A SUMMARY OF THE PERFORMANCE OF SUBSTANCE RELEASE CONTROL SYSTEMS
USED FOR THE ACTIVITY DURING THE PREVIOUS APPROVAL PERIOD: ................................ 25
APPLICATIONS FOR ACTIVITY CHANGE OR AN AMENDMENT ........................................................................ 25 3. Present the same information, as required above for Renewals, however, limit it to only those
environmental control systems affected by the Activity Change .............................................................. 25
K. THE JUSTIFICATION FOR THE RELEASE OF SUBSTANCES INTO THE ENVIRONMENT
AS A RESULT OF THE ACTIVITY, THE CHANGE TO THE ACTIVITY OR THE AMENDMENT,
ADDITION OR DELETION, AS THE CASE MAY BE. ............................................................................ 25
APPLICATIONS FOR ACTIVITY CHANGE OR AN AMENDMENT ........................................................................ 25 2. Same as for new plants except the discussion should be limited to only those items which will be
affected by the Activity change. ................................................................................................................ 25
L. THE MEASURES THAT WILL BE IMPLEMENTED TO MINIMIZE THE AMOUNT OF
WASTE PRODUCED, INCLUDING A LIST OF THE WASTES THAT WILL OR MAY BE
PRODUCED, THE QUANTITIES AND THE METHOD OF FINAL DISPOSITION ........................... 26
APPLICATIONS FOR ACTIVITY CHANGE OR AN AMENDMENT ........................................................................ 26 3. Discuss the environmental aspects of the present approval which will be affected by the change(s).
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M. ANY IMPACT, INCLUDING SURFACE DISTURBANCE, THAT MAY OR WILL RESULT
FROM THE ACTIVITY, THE CHANGE TO THE ACTIVITY OR THE AMENDMENT, ADDITION
OR DELETION, AS THE CASE MAY BE .................................................................................................. 27
APPLICATIONS FOR ACTIVITY CHANGE OR AN AMENDMENT ........................................................................ 27 3.1 Limit discussion to the extent and nature of the surface disturbance which is proposed by
construction, other impacts should be identified in the other relevant areas of this application form such
as section (k). ........................................................................................................................................... 27 3.2 Describe the change to surface disturbance both temporary and permanent caused by the "Activity
Change". .................................................................................................................................................. 27
N. CONFIRMATION THAT ANY EMERGENCY RESPONSE PLANS THAT ARE REQUIRED
TO BE FILED WITH THE LOCAL AUTHORITY OF THE MUNICIPALITY IN WHICH THE
ACTIVITY IS OR IS TO BE CARRIED ON OR WITH ALBERTA PUBLIC SAFETY SERVICES
HAVE BEEN SO FILED ................................................................................................................................ 28
APPLICATIONS FOR ACTIVITY CHANGE OR AN AMENDMENT ........................................................................ 28 4. Provide only if there is a change in plant status (i.e. convert from a sweet gas to a sour gas
processing plant) that necessitates a change. .......................................................................................... 28
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O. CONFIRMATION THAT THERE ARE CONTINGENCY PLANS IN PLACE TO DEAL WITH
ANY UNEXPECTED SUDDEN OR GRADUAL RELEASES OF SUBSTANCES TO THE
ENVIRONMENT ............................................................................................................................................ 28
P. THE CONSERVATION AND RECLAMATION PLAN FOR THE ACTIVITY ........................... 29
APPLICATIONS FOR ACTIVITY CHANGE OR AN AMENDMENT ........................................................................ 29 3.1 Describe any topsoil conservation plans for any areas affected by the change, if applicable. .......... 29 3.2 A plan to prevent, remove or treat areas of contamination to within established guidelines
(Environmental Sciences Division of AENV). .......................................................................................... 29
Q. A DESCRIPTION OF THE PUBLIC CONSULTATION UNDERTAKEN OR PROPOSED BY
THE APPLICANT. ......................................................................................................................................... 29
APPLICATIONS FOR ACTIVITY CHANGE OR AN AMENDMENT ........................................................................ 29 3.1 Same as for New Plants ..................................................................................................................... 29
APPENDIX I – EXISTING AENV APPROVALS ....................................................................................... 32
APPENDIX II – PUBLIC CONSULTATION FACT SHEET .................................................................... 33
APPENDIX III – DECOMMISSIONING, REMEDIATION AND LAND RECLAMATION PLAN .... 34
APPENDIX IV – BALZAC POWER STATION MAPS ............................................................................. 35
APPENDIX V – PROPOSED 2012 GROUNDWATER MONITORING PROGRAM ............................ 36
Table 1. Company Information .............................................................................................. 8 Table 2. Approval Summary ................................................................................................ 23
Figure 1. Regional Aerial Photo of Location ....................................................................... 11
Figure 2. Aerial Photo of Balzac Gas Plant (2009) ............................................................. 12 Figure 3. Infrastructure Expected to Remain ....................................................................... 19
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INTRODUCTION
The BALZAC SOUR GAS PROCESSING PLANT (FOR THE PROCESSING OF NATURAL
GAS) AND THE BALZAC SULPHUR PROCESSING PLANT (“Balzac Gas Plant”) are operated
by Nexen Inc. (“Nexen”) of Calgary, pursuant to approval No. 6457, issued by the Energy and
Utilities Board (hereafter referred to as the Energy Resources Conservation Board (“ERCB)) and
Alberta Environment (“AENV”) approval 155-02-00.
The Balzac Gas Plant ceased operations permanently on April 28th, 2011 (“Plant Closure”).
Therefore, Nexen is submitting this amendment application for approval to decommission,
dismantle, remediate and reclaim the Balzac Gas Plant (“Plant”).
This amendment application is being prepared in accordance with the Applications for Sour Gas
Processing Plants and Heavy Oil Processing Plants - A Guide to Content (AENV 1999).
The Balzac Gas Plant is located adjacent to the Calgary's city limits, in LSD 7-2-26-29 W4M. Other
nearby communities includes the towns of Balzac and Airdrie, Alberta.
The Balzac Gas Plant was a sour, natural gas processing plant that receives gas streams from
surrounding well sites and produce specification sales gas with the recovery of propane, butane,
condensate, and sulphur. The operation used conventional gas processing units with inlet separation,
gas compression, amine sweetening (hydrogen sulphide (H2S) and carbon dioxide (CO2) removal),
refrigeration/dehydration, condensate stabilization, sulphur recovery, and LPG fractionation.
Propane and butane were stored in horizontal pressure tanks in the tank farm and were loaded into
truck or rail car for delivery to markets. Condensate was stored in tankage and transferred to the
Pembina Pipeline system for delivery to refineries. Sales gas was sent to the Trans Canada
Transmission pipeline system, and liquid (molten) sulphur was processed into a sulphur granulation
product (prilled) and shipped by rail to Vancouver. Enersul operated and owns the sulphur
granulation facility.
The sulphur granulation process was discontinued after May 2011.
Approximately eighty-one producing gas wells (“Balzac Field”) supplied the raw natural gas
mixture to the plant for processing. Most of the gas produced from the wells is considered "sour"
meaning naturally-occurring H2S is present. H2S content varies from well to well and from different
formations. Within the Balzac field, H2S in the produced sour gas varies from 0.6% to 42%.
In the Balzac Field, all Crossfield and Elkton pipelines have been shut in and purged with Nitrogen.
Basal Quartz pipelines were pigged with fuel gas. All Crossfield wells have been blinded at the
wellhead. Elkton wells and Basal Quartz wells have been shut-in as per ERCB requirements.
The Plant has been shut down in a safe, controlled fashion, equipment and piping was
decontaminated and any sources of energy, such as steam and electricity, isolated and shut off as
required. The shutdown was managed by the Shutdown, Decommissioning and Salvage (“SDS”)
team comprised of a group of operations, maintenance, environmental and safety personnel from the
Plant, in addition to contractors familiar with the Plant and experienced to execute work in a safe,
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efficient manner. Decommissioning activities to bring the Plant to a state of zero energy and make it
safe for demolition began in May, 2011 and finished December 2011.
Under Nexen’s current operating approval with Alberta Environment, Nexen is required to submit a
Decommissioning, Remediation and Land Reclamation Plan (“DLR”) amendment within six (6)
months of closure of the facility. Nexen submitted a draft amendment application dated September
12, 2011 which was reviewed by AENV with feedback provided. The current version of this
application incorporates changes to reflect the feedback from AENV. Approval of the DLR
amendment is expected in 2012.
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ABBREVIATIONS
ABSA Alberta Boilers Safety Association
AENV Alberta Environment
AMD Air Monitoring Directive
BalCAP Balzac Community Advisory Panel
BGP Balzac Gas Plant
BPS Balzac Power Station
DLR Decommissioning, Remediation and Land Reclamation Plan
DRR Demolition, Remediation and Reclamation
EPEA Environmental Protection & Enhancement Act
ERCB Energy Resources Conservation Board
ERP Emergency Response Plan
SDS Shutdown, Decommissioning and Salvage
SHA Sulphur Handling Area
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3 (1) An application must be made to the Director and must be accompanied by the following
information relative to the activity, the change in the activity or the proposed amendment,
addition or deletion of the term or condition:
A. Applicant Information
Table 1. Company Information
Company Name(s) Nexen Inc.
(Operator of Facility)
Head Office Address 801 – 7
th Avenue S.W.,
Calgary, Ab T2P 3P7
Plant Address Nexen Inc.
RR3, Site 17, Comp 16 Rockyview County, AB T4A 0P7
Contact Numbers
Head Office: P: 403-699-4000; F: 403-699-5800
Gas Plant Office: P: 403-226-3165 (General Inquiries)
Emergency: 403-226-0967
Application Due Date October 28, 2011
Contact Person for
Application
Mr. Todd Jorgensen-Nelson, C.E.T. Sr. Coordinator – HSE&SR
Balzac Gas Plant RR3, Site 17, Comp 16
Rockyview County, AB. T4A 0P7 Phone (403) 699-6978, Fax (403) 716-0691
Application Document
Completed by
Robert McCallum, P.Biol Environmental Coordinator
Technical & Operational Services
Signature Name / Title Date of Signature
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B. Location, Capacity and size of the activity
1. Legal Land Description
07-02-026-29W4M
2. Relation to nearest town, city, village, and residents/users of the land.
The Balzac Gas Plant is located adjacent to Calgary's city limits, which are on
Township Road 260 and Range Road 291. Other nearby communities include the
town of Balzac which is located 4.8 km west and 2.4 km north of the Balzac Gas
Plant, and Airdrie which is approximately 7 km northwest of the Balzac Gas Plant.
There are approximately 222 residences included in the Balzac Gas Plant
Emergency Response Plan that include homeowners (acreage owners), businesses
and schools. (Figures 1, 2, 3)
3. Geographical description of the surrounding topography (including a
topographical map) and relation to nearby watercourses.
The Balzac Gas Plant is located on a rolling morainal plain within the Grassland
Natural Region of Alberta, where the dominant soils are Black Chernozems.
Generally, the topography is subdued with slopes ranging between 6% and 9%. The
local area has a few small seasonal, intermittent wetlands/sloughs, and McDonald
Lake, which is immediately to the west of the Balzac Gas Plant.
4. Gas Processing Capacity (Raw), Hydrogen Sulphide Processing Capacity, Sulphur
Inlet Rate.
Formerly: Raw gas processing capacity: 8,988 10
3m
3J/Day
Hydrogen sulphide processing capacity: 1,276 103m
3/D
Sulphur inlet rate: 1,000 tonnes/day
Currently :
Raw gas processing capacity: 0 103m
3J/Day
Hydrogen sulphide processing capacity: 0 103m
3/D
Sulphur inlet rate: 0 tonnes/day
5. Sulphur Production Capacity, Liquid Hydrocarbon Production, Sulphur Storage
Status, Bitumen Processing Capacity, Other.
Formerly:
Sulphur Production Capacity: 1,000 tonnes/day
Liquid Hydrocarbon Production Capacity (LPG Unit - LPG numbers are
based on 215,474 MSCFD inlet gas at 14.4 PSIA and 60°F):
Propane - 75,580 U.S. gallons/day
Butane - 54,739 U.S. gallons/day
Condensate - 58,976 U.S. gallons/day
------------------------------------------------------------
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Production at the Balzac Gas Plant in 2010 was as follows:
Sulphur production: 84,903 tonnes/year
Raw Gas production: 438,755 E3m
3
Sales Gas production: 267,293 E3m
3
Propane production: 16,053 m3
Butane production capacity: 12,507 m3
Condensate production: 22,263 m3
Current production volumes: 0 m3
Sulphur storage status - the East Sulphur Basepad and West Sulphur Basepad
currently contain approximately 40,000 tonnes of recoverable sulphur.
6. Material Balance.
Not Applicable
7. Descriptive size of the affected area, leased area, and/or plant site (Le., hectares),
or
See 8.
8. Physical dimensions of the plant site including a plant site map (i.e., plot plan) and
number of employees working at the facility.
Nexen, along with its partners, own Section 2-26-29-W4M. The Balzac Gas Plant
occupies approximately 426 hectares within that Section. As of January 1, 2011 the
Balzac Gas Plant employed 74 people.
Due to current cessation of plant operations:
Preliminary staffing for the start of 2012 is as follows:
Number of employees on site full time: 14
Calgary based employees, part time: 10
Calgary based employees, on-site part time: 10
Contract employees, full time on-site: 4
Contract employees, part time on-site: 2
Contract personnel: as needed and currently
unknown
Asbestos abatement personnel: 60-70 contract workers
from March to October
2012.
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Image Date = 14/09/2008
High Pressure Pipelines and Wells current to November 30, 2009 *** Low Pressure Pipelines current to November 1, 2005
Figure 1. Regional Aerial Photo of Power Station Location.
N
MCDONALD
LAKE
226-29-4
COOLING /BLOWDOWN
PLANTMAINTENANCE
INLETCOMPRESSION
/ SALES
CONDENSATE STORAGE AREA
LPG /CONDENSATE
LOADOUT
SULPHUR BLOCK / BASEPAD
SULPHURPLANT
OFFICE / CONTROL ROOM
PROCCESSAREA
LPGUNIT
POWERSTATION
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SULPHURHANDLINGFACILITY
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AREA
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POND
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APPROX.LOCATION OFBORROW PIT
SW DUGOUT
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CAUSTIC PUMP HOUSE
POWERSTATION
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FIRE WATERRESERVOIR
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DRILLINGMUD SUMP
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RIPARIAN /SHORELINE
FIREWATERRESERVOIR
OPEN DRAINCOLLECTION
POND
0 10050Meters
servicesAuthor: L. TulissiGIS Analyst : M. JanickDept. : GIS Services
Date: March 3, 2011File No: A12327.mxd
NEXEN INC. 801-7th Ave S.W. Calgary, AB. Canada T2P 3P7T. 403.699.4000 www.nexeninc.com
BALZAC PLANT
Nexen Inc.Canadian Oil & Gas Division
Scale: 1:3,500
±
LegendPlant Dispositions
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C. The nature of the activity, the change to the activity or the amendment,
addition or deletion, as the case may be:
Applications for Activity Change or an Amendment
3.1 Describe the change(s).
3.1.1 HISTORY OF THE PLANT
Construction of the Balzac gas plant began in April 1961. At the time, the plant was known as the
Petrogas plant, for Petrogas Processing Ltd., a separate company set up with numerous partners
including Canadian Occidental Petroleum (now Nexen). The Petrogas operating structure, which
had become inefficient, was collapsed in 1995 and reverted to a conventional joint venture system.
After eight short months of construction, first gas was processed in November 1961. Through the
’60s and ’70s the plant went through a series of expansions but depressed markets in the mid-’80s
forced a decommissioning of part of the plant. Over a 15-year period beginning in the 1980s, Nexen
tried five times to combine the production from sour gas plants owned by other companies. There
was renewed optimism in 2006 when Nexen undertook an ambitious strategy to license 15 new sour
gas wells and five new pipelines. Unfortunately, results from the first wells drilled were
disappointing and the project was cancelled. In 2010, the Plant was coming up to the 50th year of
operation, facing poor market prices, high repair costs and declining production from its wells, all
partners agreed to retire the Balzac Gas Plant in 2011.
In addition to declining production, urban encroachment was another factor considered when
determining the future of the plant. In 1961, Calgary’s population was 250,000. Today about 1.3
million people live in the Calgary area, and the Balzac gas plant is no longer isolated from the city.
Some of the gas wells are now in residential communities.
More than 3.5 trillion cubic feet of natural gas and millions of tons of sulphur have been processed
over the past 50 years. The plant and the gas fields – covering approximately 400 square kilometres
(154 square miles), with 300 kilometres (186 miles) of pipelines and 120 wells – have run safely and
efficiently since day one with an impeccable safety record.
The plant ceased operations permanently on April 28th, 2011. Nexen no longer processes sour
natural gas at the Balzac Gas Plant and is applying to AENV for approval to shutdown,
decommission, salvage, remediate, and ultimately reclaim the BGP.
3.1.2 CURRENT PHASE OF THE PROJECT
After the plant stopped producing gas in late April 2011, the abandonment process began in the
plant and field (May 2011). The Shutdown, Decommissioning and Salvage (“SDS”) phase of the
project (this means the Plant was prepared, cleaned and its various systems de‐energized) was
executed by the SDS team from May to December 2011. The SDS project dismantled, removed or
demolished only to the extent required by the work of shutdown and decommissioning as well as the
pursuit of any salvage opportunities that may arise while the SDS project is ongoing.
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Items available for immediate disposition and salvage were identified and the removal process has
commenced and will continue into 2012.
In December 2011, the Project was turned over to the Demolition, Remediation and Reclamation
phase (“DRR”). This DRR phase will include demolition of the facilities, remediation of the soil
and ultimately reclamation of the site. Apart from wastes which were produced by the SDS
execution and other wastes which must be disposed of to make the Plant safe for dismantling and
demolition, most salvage and waste activities will be executed by the DRR project.
Disposition of select pieces of equipment under the SDS phase will occur as per Nexen’s EPEA
Approval Amendment No. 155-02-06, issued on July 28, 2011, which authorized the removal of
selected equipment as described in that application and approval.
Guidelines for how the various phases of the work will be executed, from planning to physical
removal and disposal, are currently being developed so that the various assets are removed and
disposed of in a safe, environmentally responsible and cost effective manner.
A preliminary list of BGP assets has been developed. A master asset list of all BGP assets includes
only the major equipment. Spare parts, inventory, tools, furniture, etc. are on separate lists. In order
to maximize asset value, offset future demolition/disposal costs and reduce the amount of waste sent
to landfills, a condensed list of assets and spare parts inventory deemed to be in good condition was
offered to interested parties for transfer or sale.
Where an asset did not/does not sell for reuse an attempt will be made to recycle the asset by selling
it for scrap. If the scrap value cannot be realized for an asset, it will be sent to a landfill. Scrap and
waste disposals will be recorded in a Nexen database.
The priority for asset disposition is:
Transfer/sell for reuse;
Sell for scrap / recycle;
Donate;
Landfill (this categorization will only be made after reasonable investigations into
options for recycling traditional waste streams. Nexen will investigate these options
as waste streams are further identified.
Any equipment leaving the site (working component, scrap or waste) will be documented and
appropriate updates will be made to internal tracking systems and the Alberta Boilers Safety
Association (“ABSA”) (where applicable).
Nexen has implemented contractual mechanisms to ensure that equipment (i.e. tanks) that previously
contained potentially hazardous materials/wastes were/are identified to buyers as a component of the
contract and documentation. Nexen will/has worked with reputable buyers to ensure safe and legal
transport and use of the disposed items, however once the equipment leaves the BGP, Nexen cannot
control 3rd
party buyer end use of the disposed equipment.
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3.1.3 FACILITIES TO REMAIN IN OPERATION DURING THE DRR
PROJECT PHASE
In order to maintain existing environmental controls, safety controls, and operational requirements
for infrastructure fundamental to the DRR project, the following facilities are to remain in operation
during the DRR project phase:
1. Diesel Fire Water Pumps (2 Pumps PM-18-35 & PM-18-1522.
2. Electric Fire Water Pump (18-1516-01).
3. Double Lined Flare Ponds (Open Drain Collection Ponds) – two compartments (38-2802 &
38-2803). Water from thes ponds is sent to an approved disposal well.
i. Flare Pond Pump (28-1520) - Pump associated with pond
4. Chemical Storage Tanks (2) (38-1909 & 38-1910) c/w containment.
5. Miscellaneous small pumps around the Plant for moving surface water.
6. Sulphur Handling Area (SHA) System – all water treated in sulphur basepad area - tank and
lined pond:
i. Lined Acid Water Containment Pond;
ii. Caustic Tank (SV-19-20);
iii. Weeping Tile Pump (PM-18-34);
iv. Pond Discharge Pumps (PM-18-32, PM 18-33);
v. Crusher Pump (PM-18-31);
vi. Sulphur Block Area Surface Runoff Collection Pond;
7. Groundwater Remediation System (LPG GW/Lean Oil Collection):
i. Wilden Air Operated Pump or equivalent; currently operated by portable gas-fired
operated compressor.
ii. Lean Oil Storage Tanks (SV-19-21, SV-19-22, SV-19-23, SV-19-11).
8. Blowdown Holding Ponds: Currently the blowdown holding ponds capture surface water
runoff that occurs as a result of precipitation in the immediate vicinity of the Blowdown
Ponds. During the DRR project phase, runoff will continue to be managed in accordance
with the current approval. The existing infrastructure used to manage surface water runoff
and diversions to the ponds will remain in place. However, all former inlet systems to the
blowdown ponds have been isolated. Only surface water from the immediate area around
the blowdown ponds will enter the blowdown ponds which is now classified as industrial
runoff (developed Area 2 and changed in approval 155-02-06 from Industrial Wastewater to
Industrial Runoff). Blowdown Ponds no longer used to store Process Wastewater. Water in
the blowdown ponds will continue to be sampled prior to release as per the amended AENV
approval 155-02-06.
9. Sub-station #8 complete with a diesel operated Emergency Generator (41-1804): required
to provide power to incinerator stacks for lights as per NAV Canada requirements, power to
16
the on-site abandonment and reclamation offices, shop & warehouse, in addition to the three
maintenance shacks. The single Emergency diesel generator to stay operational.
10. Pipelines:
i. Fuel Gas Pipeline to the Field (timeline for operation is currently undetermined);
ii. Disposal Water Pipeline to Disposal Well 10-36-25-01 W5M. (timeline for
operation dependent on Disposal Well operations);
iii. Water Supply line to the BGP;
iv. Fuel gas line, Water Supply and Water Disposal to and from the Balzac Power
Plant;
v. Firewater Lines located on the Plant site.
11. Cathodic protection on remaining pipelines;
12. All Building Foundations and/or Concrete Pads Used to Support Equipment: During the
salvage component of the SDS phase, equipment was/is being removed for sale. Some of
that equipment was/is situated on concrete support pads. During the DRR phase of the
project, remaining pieces of equipment, facilities, buildings, piping, etc… will be
demolished and removed. Following the demolition and removal of equipment, Nexen will
strive to leave all foundations and concrete pads in place until the remediation phase of the
DRR project begins. If concrete at surface is in the way of equipment removal then activities
may be undertaken to remove surface concrete for access purposes only. Subsurface
concrete associated with these specific projects would then be removed at a later date. Both
the Dismantling and Remediation processes require separate and unique management
techniques, which are easier to manage separately. Therefore, the intent is NOT to leave
foundations and pads in long term but to accomplish two things:
i. Avoid disturbance of underlying soils and materials that may have been potentially
affected by contamination. This will allow Nexen to fully determine appropriate
remediation processes at these numerous locations prior to disturbance of the
foundations and pads. This will allow Nexen to implement appropriate
management, safety and remediation protocols at that time.
ii. Avoid creation of open holes, pits or excavations that would then become
workplace hazards to personnel completing demolition components. Nexen has
completed a risk analysis and hazard assessment of the removal of the foundations
or concrete pads. It was determined that in order to reduce safety hazards on the
project site, minimizing disturbed ground or open excavations is desirable.
As a function of the safety/risk protocols, work permits will be issued for all work
completed by a contractors. The Work Permits are intended to ensure potentially
hazardous work is carried out under safe working conditions. The permit system is
a two-way arrangement and the responsibility for taking special precautions rests on
both the issuer and the receiver of the permit. Prior to starting work contractors are
expected to discuss work permit requirements with the Nexen representative. When
a work permit is issued from an area other than at the immediate work site an
agreement will be made between the two parties regarding who will be responsible
to perform the site hazard assessment prior to work starting and which hazard
assessment form will be used to document the assessment.
17
Non-Routine tasks shall also be subject to a Task Risk Assessment (TRA) and Task
Hazard Assessment (THA). In the case of non-routine tasks, the process takes place
immediately prior to starting the task. The process includes the following:
1. Perform a TRA using the Task Risk Assessment Form;
2. If the Task risk identified is MEDIUM or higher, perform a THA using the
Task Hazard Assessment form;
3. After completing the THA and identifying controls, re-assess the risk of the
task and note the residual risk; and,
4. If the residual risk is MEDIUM or HIGH, The Business Unit Manager, or
their designate, and the HSE Coordinator/Advisor must make the decision and
document whether to proceed or not proceed with the task.
13. Balzac Power Station and associated infrastructure captured under the Balzac Power Station
AEPEA Approval # 136858-00-00.
14. Nexen is currently evaluating the Disposal Well (ERCB - Approval 7079B) located at 10-
36-25-01 W5M. The well is currently shut-in until an analysis of well is completed. There is
a potential that the disposal well will continue to operate after it has met the ERCB’s
regulatory conditions. AENV will be updated accordingly.
15. Some tanks will be left on site for the possible storage of water during non-freezing time
frames. The decision on what tanks may stay is still being reviewed. Any and all tanks
that will be used at various locations (TBD) around the BGP site during upcoming
operations will meet ERCB D55 requirements/regulations.
3.1.4 FACILITIES TO REMAIN IN OPERATION DURING THE DLR
PROJECT PHASE
Following decommissioning and dismantlement, Nexen will implement a remediation and
reclamation management program. This program is referred to as the Decommissioning,
Remediation and Land Reclamation Plan (“DLR”) (The DLR Plan is provided in Appendix III).
The objectives of this Plan are:
To abandon in place below ground facilities such as pipelines that are no longer required as
per ERCB Pipeline regulations (AR 91/2005 PIPELINE REGULATION, Part 10);
To analyze and characterize the existing site conditions of the facility and its surroundings
with respect to potential contamination and remediation requirements;
To characterize and quantify any identified site contamination;
To develop a remedial action plan for the site; and,
To develop a surface reclamation plan for the site based upon project end land use scenarios
and expected requirements to meet equivalent land capability based upon end land use.
During the DLR phase of the Project, and following successful remediation and reclamation to an
approved end land use, the following infrastructure is expected to remain in place (FIGURE 3):
1. Balzac Power Station and associated infrastructure captured under the Balzac Power Station
AEPEA Approval # 136858-00-00.
18
2. Pipelines:
i. Fuel Gas Pipeline to the Field indeterminate;
ii. Disposal Water Pipeline to Disposal Well 10-36-25-01 W5M. (dependent on
Disposal Well operations);
iii. Water Supply line to the BGP (Balzac Gas Plant);
iv. Water Supply to the BPS (Balzac Power Station);
v. Water Disposal line from BPS (Balzac Power Station);
vi. Fuel gas line to the BPS (Balzac Power Station);
MCDONALD
LAKE
226-29-4
PipelineR/W (031
0629)
PipelineR/W (031 0391)
GasPipeline R/W (4609
JK)
Pipeline R/W(791
0816)
Gas Pipeline R/W(851
0253)
Gas TransmissionLine R/W(299 JK)
PipelineR/W (791 0816)
Oil PipelineR/W (754
JK)
PipelineR/W (031 0174)
PipelineR/W
(1547 JK)
Gas TransmissionLine R/W(686 JK)
PipelineR/W (101
2606)
Pipeline R/W(502 JK)
PipelineR/W (061 2620)
PipelineR/W (921 0545)
PipelineR/W (821 0555)
CanadianPacific Railway
(871 JK)
Pipeline R/W(081
5893)
PipelineR/W (081
3328)
GasPipeline R/W (791
0816)
PipelineR/W
(500 JK)
Pipeline R/W(500JK)
Gas PipelineR/W
Gas PipelineR/W
Admin Building
Power Station
FiberOptic Pipeline
(10m R/W)
FiberOptic Pipeline (10m
R/W)
Building
Pipeline R/W
PowerlineR/W
PowerlineR/W (9012327
UR/W)
Pipeline R/W
Well Site 2-2
PipelineR/W (931
2570)
0 100 200 30050Meters
±
LegendDisposition - Operator
Atco
Canadian Pacific Railway
City of Calgary
Fortis
Nexen
Pembina
Telus
services
Nexen Inc.
NEXEN INC. 801-7th Ave S.W. Calgary, AB. Canada T2P 3P7T. 403.699.4000 www.nexeninc.com
BalzacFigure 3
Existing InfrastructureExpected to Remain
Author: R. McCallumGIS Specialist: A. JackDept: GIS Services
Date: November 24, 2011Updated: February 6, 2012File No : CA13581.mxd
NAD 1983 UTM Zone 12NProjection: Transverse Mercator
Imagery provided by ValtusDate Collected: September 22, 2009VISTA Alberta UTM 12 0.3m 2009
Scale: 1:2,500
20
3.2 Describe the affect that the change(s) may have on the environment.
After plant closure Nexen will no longer be processing sour natural gas. Air emissions associated
with sour gas processing will be eliminated. Industrial wastewater and domestic wastewater
emissions will ultimately be eliminated. Upon successful dismantling, remediation and reclamation
at the Balzac Gas Plant, land use will be restored to the appropriate equivalent land capability or end
land use appropriate for that time.
3.3 Describe the affect that the change(s) may have on the Environment Control
Systems.
Environmental control systems for air emissions will no longer be required. Upon successful and
approved remediation and reclamation at the Plant, all environmental control systems (including
industrial wastewater and industrial runoff) will be eliminated.
3.4 Describe the implications, which the change(s) may have on the current
approval.
This application document is being submitted pursuant to Terms 5.1.1 to 5.3.2 of the current
approval 155-02-00.
The approval(s) will require amendment to remove all operational, monitoring and reporting
requirements associated with the Plant as follows:
AMENDMENTS REQUESTED AS A RESULT OF THIS APPLICATION
Nexen requests that the following monitoring/reporting clauses in the current approval (155-02-00)
be removed or amended as they apply specifically to an operating facility:
Terms 4.6.1 to 4.6.7 – Groundwater monitoring. As per this amendment a modified
Groundwater Monitoring Program is being proposed. (See Proposed 2012 Groundwater
Monitoring Program - Appendix V for further information). The rationale for this request is
that Nexen has collected a significant volume of data on groundwater characteristics since
1992. This existing data will allow Nexen to determine remediation options and methods
appropriate for plant decommissioning. Furthermore, Nexen believes that the intent of the
Groundwater monitoring program was/is to delineate impacts and understand groundwater
characteristics. Nexen is confident that this intent has been and will continue to be fulfilled.
In light of the Plant decommissioning, some monitoring wells are of lesser importance to
this aforementioned intent. It should be noted that during Plant decommissioning and
remediation of the area, several wells installed near facilities will be removed. These
monitoring wells will need to be properly abandoned. Nexen will of course continue to
monitor groundwater wells that are on the periphery of either the plant or areas undergoing
decommissioning or remediation but request an amendment to the groundwater monitoring
program.
21
Groundwater conditions at the Balzac Sour Gas Processing Plant (Plant) have been
documented in great detail through monitoring from 1992 to 2011. The main
findings of the groundwater monitoring include:
generally, natural groundwater quality in the Plant area is
of poor quality as indicated by high sulphate and total
dissolved solids (TDS) concentrations;
groundwater flow velocities outside of the process area are
low, in all three monitored groundwater zones, primarily
due to low hydraulic gradients;
groundwater quality, including in zones of contamination,
is relatively stable with small seasonal and annual
variability; and
inorganic and organic groundwater impacts related to Plant
operation identified within the process area, ponds and
adjacent areas are aerially stable and have not expanded
greatly over the monitoring period.
Considering the significant hydrogeological information available and the Plant
decommissioning, a major revision in the forthcoming groundwater monitoring
program is recommended. Proposed changes to the 2012 program include:
reduction in groundwater monitoring frequency;
reduction in the number of monitoring wells to be monitored;
reduction in analytical schedule; and
concentrating monitoring activities around the process area and
perimeter “C” wells.
The proposed groundwater monitoring program would include sampling once a year
in the spring, instead of spring and fall sampling, with the number of monitored
wells reduced. To address operational issues during the 19 year history of
groundwater monitoring, several monitoring wells were installed in relatively close
proximity to each other, often duplicating and/or confirming information obtained
from existing wells. These expansions to the monitoring network were required at
the time of installation. However, in view of the Plant decommissioning, some
monitoring wells are of lesser importance. It should be noted that during Plant
decommissioning and remediation of the area, several wells installed near facilities
will be removed. These monitoring wells should be properly abandoned.
Monitoring wells selected for continued monitoring should be sampled and tested as
follows:
laboratory analysis for benzene, toluene, ethylbenzene, xylenes
(BTEX) and petroleum hydrocarbon (PHC) fractions F1 and F2
and amines; and
field measured parameters including depth to groundwater
surface, temperature, electrical conductivity (EC) and pH. If
significant changes in EC and/or pH are measured as compared
to historical field measurements, a sample should be submitted
for routine potability analysis for the well in question.
Otherwise, laboratory testing for main ions and dissolved
metals should be discontinued.
22
Terms 4.7.1 to 4.7.5 – Soil monitoring. Conditions as outlined in amended approval 155-
02-05 regarding a date change for soil monitoring submission dates;
TERMS AND CONDITIONS EXPECTED TO REMAIN IN FORCE
Nexen expects the following conditions will remain in place during the demolition, remediation and
reclamation components of the Project:
Term 4.1.2: As amended in approval 155-02-06;
Term 4.1.19: As amended in approval 155-02-06;
Term 4.2.1: The approval holder shall not release any substances from the plant to the
surrounding watershed except as authorized;
Term 4.2.3 Industrial wastewater that is collected in the Double Lined Open Drain
Collection Pond shall only be disposed as follows:
(a) to an Alberta Energy and Utilities Board (EUB) approved disposal well; or,
(b) to an Alberta Energy and Utilities Board (EUB) approved Waste Processing
and Disposal Facility; or
(c) as otherwise authorized in writing by the Director.
Term 4.2.6: As amended in approval 155-02-06
Term 4.2.7: As amended in approval 155-02-06.
Term 4.2.8: As amended in approval 155-02-06.
Term 4.2.9: As amended in approval 155-02-06, including 4.2.9.1
Term 4.2.10: As amended in approval 155-02-06,
Term 4.2.11: As amended in approval 155-02-06,
Term 4.2.12: As amended in approval 155-02-06,
Term 4.2.13: As amended in approval 155-02-06,
Term 4.2.14: As amended in approval 155-02-06,
Term 4.4.1 All domestic wastewater shall be directed to a septic tank with subsequent
disposal to an approved municipal wastewater treatment system.
Terms 4.7.6 and 4.7.7 – Sampling standards to remain.
Terms 4.7.8 to 4.7.16 – Soil Management Program. Conditions as outlined in current
approval will be followed.
23
3.5 Describe when the changes will take place.
The plant ceased operations permanently on April 28th, 2011. Upon submission of this amendment
application, Nexen is hopeful that dismantling activities may commence in 2012. The exact date of
commencement will be dependent upon AENV review and approval timelines however general time
periods are as follows (Table 2):
Table 2. Approval Summary
Approval Number Application Number Original Effective Date Expiry Date of
Original Approval
155-02-00 008-155 October 31, 2005 September 30, 2015
155-02-01 014-155 September 17, 2007 September 30, 2015
155-02-02 015-155 February 29, 2008 September 30, 2015
155-02-03 017-155 July 23, 2010 September 30, 2015
155-02-04 016-155 January 14, 2011 September 30, 2015
155-02-05 Not Provided March 9, 2011 September 30, 2015
155-02-06 019-155 July 28, 2011 September 30, 2015
D. Where the application requires an approval from the Alberta Energy and
Utilities Board or the Natural Resources Conservation Board in relation to the
activity, the date of the written decision in respect of the application
1. Date of Alberta Energy and Utilities Board (EUB) Approval
The date of the ERCB Facility Licence for the Balzac Gas Plant is June 28, 2007.
2. Approval Number
Licence No. F3645.
E. An indication of whether an environmental impact assessment (EIA) report has
been required
1. Was an EIA required?
An Environmental Impact Assessment was not required for initial licensing of the facility.
F. Copies of existing approvals that were issued to the applicant in respect of the
activity under this Act or a predecessor of this Act
Refer to APPENDIX I – EXISTING AENV APPROVALS for copies of existing approvals.
24
G. The proposed or actual dates for construction commencement, construction
completion, and commencement of operation
3.1 Provide actual date for original commencement of operation, if known.
The construction of the Balzac Gas Plant began in April 1961. The first sales gas product was
delivered in November 1961.
3.2 Provide proposed effective date for "Activity Change" and/or
Amendment.
Nexen would like to request an effective date for the amendment as 6 months from submission date
of this application.
H. A list of substances, the sources of the substances and the amount of each
substance that will be released into the environment as a result of the activity,
the change to the activity or the amendment, addition or deletion, as the case
may be, the method by which the substances will be released and the steps
taken to reduce the amount of the substances released.
Applications for Activity Change or an Amendment
3.1 Provide a description of current substance releases.
As the Plant has ceased operations, currently there are no exhaust system releases except from:
diesel fired emergency generator exhaust stack; and,
two diesel fired firewater pump exhaust stacks.
Fugitive emissions from sulphur base pad, including AMD soils – measures sulphur deposition and
dust and potential fugitive for demolition and remediation and reclamation phases.
Surface water runoff and domestic wastewater as per current approvals.
3.2 Describe the implications to the above description as a result of the Activity
Change.
No change to the above description.
3.3 Provide the final modified description that will result after the Activity Change
is operational.
Upon successful Shut-down, decommissioning, dismantlement, and remediation the land will be
reclaimed to support equivalent land capability while considering end land use strategies that may be
applicable. As such, no substance releases will occur.
25
I. A summary of the environmental monitoring information gathered during the
previous approval period
Nexen has conducted numerous air quality, soils and groundwater investigations at the facility since
1990. Please refer to the Decommissioning, Remediation and Land Reclamation Plan (Appendix
III) which summarizes this information in detail.
Applications for Activity Change or an Amendment
1. Only monitoring information on the affected parameters is required.
Refer to Decommissioning, Remediation and Land Reclamation Plan (Appendix III).
J. A summary of the performance of substance release control systems used for
the activity during the previous approval period:
Refer to Decommissioning, Remediation and Land Reclamation Plan (Appendix III).
Applications for Activity Change or an Amendment
3. Present the same information, as required above for Renewals, however, limit it to
only those environmental control systems affected by the Activity Change
Not Applicable.
K. The justification for the release of substances into the environment as a result
of the activity, the change to the activity or the amendment, addition or
deletion, as the case may be.
Not Applicable.
Applications for Activity Change or an Amendment
2. Same as for new plants except the discussion should be limited to only those items
which will be affected by the Activity change.
Not Applicable.
26
L. The measures that will be implemented to minimize the amount of waste
produced, including a list of the wastes that will or may be produced, the
quantities and the method of final disposition
Applications for Activity Change or an Amendment
3. Discuss the environmental aspects of the present approval which will be affected by the
change(s).
Nexen is developing a Waste Management Plan to handle wastes associated with the various phases
of this Project.
Nexen Inc. (NEXEN) is committed to demonstrating continuous improvement in reducing the
generation of waste from its operations, beneficially reusing or recycling materials that might
otherwise end up in the waste stream. Nexen will properly store, handle, and dispose of those
wastes that remain in accordance with Provincial or Federal regulations.
Active waste minimization is forefront, when the proper waste handling techniques are employed.
NEXEN is committed to ensuring compliance with regulations, as well as ensuring protection of the
environment when dealing with its waste products.
NEXEN is also committed to properly training all personnel who handle wastes and those
responsible for their supervision.
To actively pursue these commitments, NEXEN is developing a Waste Management Plan to ensure
compliance with all associated environmental regulations. The plan will serve as a valuable tool for
the collection of data, providing guidance to employees, identification of future technology needs
and requirements, as well as reducing risk exposure, and identifying the company’s operating
procedures and standards.
The plan is being designed based on discussions with operations and environmental personnel from
NEXEN. Site visits to a representative sample of facilities may be conducted or third party audits
may be obtained and reviewed to ensure waste facility audits are in place and reviewed. The plan
will ensure regulatory compliance.
This waste management plan is comprised of the following components:
Identification
Characterization and classification
Handling
Storage
Treatment
Disposal
Manifesting
Tracking and record keeping
Reporting
27
The principles of waste minimization will be followed closely in the plan. This is both an
environmental consideration as well as an economical one. Recognizing opportunities to reduce
waste volumes as well as the elimination of certain wastes will enable NEXEN to ensure that it is
operating in an environmentally safe and responsible manner. This will reduce the liabilities
associated with the handling, storage and disposal of dangerous oilfield wastes (DOWs).
Nexen will continue to follow its Waste Management Plan during the transition into the demolition
phase.
Wastes expected to be handled include (list not exhaustive):
Domestic-type wastes (non-hazardous, "garbage")
Salvage metals, i.e. Iron, Copper, Tin, Steel
Construction waste (general building materials, e.g. concrete, plaster, wood, etc.)
Glass and ceramics
Asbestos-containing or contaminated materials (insulations, building materials, abatement
waste materials)
Asbestos-contaminated water (filtered)
Synthetic (non-asbestos) insulating materials
Lead-acid batteries
Mercury, liquid in instrumentation
Mercury lamp bulbs and tubs
PCB Transformer oil (potential)
PCB-containing lamp ballasts (potential)
Ozone-depleting refrigerants (HVAC units)
Other Dangerous Oilfield Wastes ("DOW"), e.g. residual chemicals or contaminated
materials as identified during demolition
M. Any impact, including surface disturbance, that may or will result from the
activity, the change to the activity or the amendment, addition or deletion, as
the case may be
Applications for Activity Change or an Amendment
3.1 Limit discussion to the extent and nature of the surface disturbance which is
proposed by construction, other impacts should be identified in the other
relevant areas of this application form such as section (k).
Refer to Decommissioning, Remediation and Land Reclamation Plan (Appendix III).
3.2 Describe the change to surface disturbance both temporary and permanent
caused by the "Activity Change".
Refer to Decommissioning, Remediation and Land Reclamation Plan (Appendix III).
28
N. Confirmation that any emergency response plans that are required to be filed
with the local authority of the municipality in which the activity is or is to be
carried on or with Alberta Public Safety Services have been so filed
Applications for Activity Change or an Amendment
4. Provide only if there is a change in plant status (i.e. convert from a sweet gas to a sour
gas processing plant) that necessitates a change.
The current version of the Nexen Inc. Balzac Complex Emergency Response Plan (ERP)
was formally approved by the ERCB on November 17, 2011. The plan meets the
requirements of ERCB Directive 71: Emergency Preparedness and Response Requirements
for the Petroleum Industry, 2008 Edition.
The Balzac Gas Plant ERP was updated and re-issued in October 19, 2011.
The approved Balzac Complex Emergency Response Plan is currently registered with the
ERCB (DDS #211) and distributed to all agencies listed below.
1. ERCB;
2. Alberta Health Services;
3. City of Calgary, including:
a. Airport Authority
b. Emergency Management Agency
c. Emergency Operations Centre.
4. Town of Airdrie;
5. County of Rocky View;
6. Town of Chestermere; and,
7. RCMP.
O. Confirmation that there are contingency plans in place to deal with any
unexpected sudden or gradual releases of substances to the environment
The Emergency Response Plan which is in place for the Balzac Gas Plant addresses the prevention
of and response to accidental spills, releases, or other abnormal occurrences which are foreseeable.
The Nexen Balzac Complex has an ERCB approved and up-to-date ERP. A number of plans and
procedures can be found within the ERP that deal with unexpected, sudden, or gradual releases of
substances to the environment. Generally, any major upset conditions at the facility and at all field
locations are covered by the ERP (e.g., gas releases, fires, explosions, spills, etc.). The Nexen
Balzac Complex also has a Spill Response Plan in place dated February 2007. This document also
references a number of policies, procedures, and action plans that are in place to deal with spills and
it identifies responsibilities at different levels within the company.
Regular visitations to residents and affected stakeholders within the ERP were conducted every two
years with approximately fifty-percent of all residents being contacted in person on an annual basis.
This process ensures for the accuracy of the response plan and helps to identify and address any
existing questions or concerns in the community. Going forward into 2012 resident visitations will
be conducted annually.
29
In 2002, the Nexen Balzac Gas Plant became the first Oil & Gas facility in the world verified
Responsible Care® In-Place.
Responsible Care® (RC) is a unique ethic developed within the chemicals industry that drives
continual improvement in health, safety, environmental and business performance, while openly and
transparently communicating with stakeholders about products and processes.
Critical to RC is an expectation for member companies to have a functioning, effective management
system in place and that it is structured to include all components of the Plan/Do/Check/Act cycle of
continual improvement.
Both the “ethic” and effectiveness of the management system is verified every three years by a team
of external industry experts and leaders within the community through a process of staff interviews,
document reviews and meetings with external stakeholders. The next verification for the Balzac Gas
Plant is scheduled for the fall of 2013.
P. The conservation and reclamation plan for the activity
Refer to Decommissioning, Remediation and Land Reclamation Plan (Appendix III).
Applications for Activity Change or an Amendment
3.1 Describe any topsoil conservation plans for any areas affected by the change, if
applicable.
Refer to Decommissioning, Remediation and Land Reclamation Plan (Appendix III).
3.2 A plan to prevent, remove or treat areas of contamination to within established
guidelines (Environmental Sciences Division of AENV).
Refer to Decommissioning, Remediation and Land Reclamation Plan (Appendix III).
Q. A description of the public consultation undertaken or proposed by the
applicant.
Applications for Activity Change or an Amendment
3.1 Same as for New Plants
At Nexen, public consultation is the conduit to actively involving the public and community in the
processes and decisions that may impact their lives or livelihood. Communities have a legitimate
right-to-know about our planned and on-going activities and to participate in decision-making for
30
issues that affect them. Nexen believes that in identifying shared concerns, we are better able to find
shared solutions or opportunities.
Nexen's commitment to ongoing and continued communication with area residents, neighbours,
stakeholders and business's is one way in which we conduct our activities and work with the
community to maintain an open, honest and transparent relationship. In 2002, the Nexen Balzac Gas
Plant became the first upstream Oil & Gas facility in the world to be verified in achieving the status
of Responsible Care®.
Responsible Care®, originally developed by the Chemical Industry Association of Canada (CIAC),
is a global, chemical industry initiative. It is a comprehensive performance improvement initiative
designed to address public concerns related to impacts associated with the chemical industry.
Although the Nexen Balzac Gas Plant was the first upstream Oil and Gas facility to implement
Responsible Care®, Nexen's other Divisions have taken a leadership role in Responsible Care® with
In-place certification assigned in October of 2010.
In addition, Nexen was instrumental in the development and support of the Balzac Community
Advisory Panel (BalCAP). The mission (focus) of the Balzac Community Advisory Panel was to
provide a forum for open, honest and transparent communication, on-going dialogue and timely
discussion of issues related to existing and proposed development and operations in the Balzac and
surrounding area. However, due to Plant shutdown, BalCAP has now been disbanded as of 4th
Quarter of 2011 and consultation will conducted through open houses (see below).
Communications and consultation processes for the Nexen Balzac Complex are divided into three
basic categories, they are:
1. Annual and ongoing contacts;
2. Emergency response planning contacts; and,
3. Project and maintenance contacts.
Regular visitations to residents and affected stakeholders within the ERP were conducted every two
years with approximately fifty-percent of all residents being contacted in person on an annual basis.
This process ensures for the accuracy of the response plan and helps to identify and address any
existing questions or concerns in the community. Going forward into 2012 resident visitations will
be conducted annually.
Direct mail, local newspaper advertising, open houses, and visitations were also used to delineate
information regarding regular field maintenance upgrades, new drilling programs, and testing.
Abandonment and reclamation activities are also conducted in such a manner as to ensure that
residents living adjacent to these activities are informed of the schedule of activities and rationale
for the work.
Amendment Application: Consultation Activities
Following an administrative review of the Nexen Balzac Gas Plant amendment application by
Alberta Environment, Nexen's public involvement process will begin by advertising in the following
local and regional newspapers to advise interested parties of the amendment application and thirty-
day review process:
Calgary Herald;
31
Calgary Sun;
Airdrie City View; and,
Rocky View Weekly.
Stakeholder Notification:
In addition to the newspaper advertisement all the residents, businesses, local authorities within the
Balzac Complex & Gathering System Emergency Planning Zone (approximately 1500 contacts)
were mailed three editions of the Nexen Community Matters news publication since January 1st,
2011 and an invitation to attend our Open House held at the Balzac Community hall on October 18th
2011. Nexen is planning on another Open House in early 2012.
All information presented at the Open House is posted on the Nexen Balzac website
www.nexeninc.com/balzac
Comments and feedback to the amendment application will be collected through a variety of
mechanisms. Nexen has provided the phone numbers for the Plant Manager(s) and Social
Responsibility department, as well as an email address where queries and/or comments can be
forwarded. All comments received will be recorded, catalogued and available on request.
32
APPENDIX I – EXISTING AENV APPROVALS
APPROVAL
PROVINCE OF ALBERTA
ENVIRONMENTAL PROTECTION AND ENHANCEMENT ACT R.S.A. 2000, c.E-12, as amended.
APPROVAL NO. 155-02-00 APPLICATION NO. 008-155 EFFECTIVE DATE: October 31, 2005 EXPIRY DATE: September 30, 2015 APPROVAL HOLDER: Nexen Inc.
ACTIVITY: CONSTRUCTION, OPERATION AND RECLAMATION OF THE BALZAC SOUR GAS PROCESSING PLANT FOR THE PROCESSING OF NATURAL GAS AND THE BALZAC SULPHUR PROCESSING PLANT. ……………………………………………………………………………………………… ……………………………………………………………………………………………… IS SUBJECT TO THE ATTACHED TERMS AND CONDITIONS. Designated Director under the Act Alan Pentney, P.Eng. Date Signed October 31, 2005
APPROVAL NO. 155-02-00 Page 1 of 31
………………….
TERMS AND CONDITIONS ATTACHED TO APPROVAL PART 1: DEFINITIONS
SECTION 1.1: DEFINITIONS
1.1.1 All definitions from the Act and the regulations apply except where expressly defined in this approval.
1.1.2 In all PARTS of this approval:
(a) "Act" means the Environmental Protection and Enhancement Act, R.S.A. 2000, c.E-12, as amended;
(b) "air contaminant" means any solid, liquid or gas or combination of any of them in the atmosphere resulting directly or indirectly from the activities of man;
(c) "application" means the written submissions to the Director in respect of application number 008-155 and 010-155 and any subsequent applications for amendments of approval number155-02-00;
(d) "CEM" means continuous emissions monitor;
(e) "CEMS Code" means the Continuous Emission Monitoring System Code, Alberta Environment, 1998, as amended;
(f) "chemical" means any substance that is added or used as part of the treatment process;
(g) "commence operation" means to start up the plant, process unit or equipment for the first time with the introduction of feed material, electrical or thermal energy and the simultaneous production of products for which the plant, process unit or equipment was designed excluding predetermined period of commissioning or testing;
(h) "container" means any portable device in which a substance is kept, including but not limited to drums, barrels and pails which have a capacity greater than 18 litres but less than 210 litres;
(i) "day" means any sampling period of 24 consecutive hours unless otherwise specified;
(j) "decommissioning" means the dismantling and decontamination of a plant undertaken subsequent to the termination or abandonment of any activity or any part of any activity regulated under the Act;
(k) "decontamination" means the treatment or removal of substances from the plant and affected lands;
APPROVAL NO. 155-02-00 Page 2 of 31
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TERMS AND CONDITIONS ATTACHED TO APPROVAL
(l) "Director" means an employee of the Government of Alberta designated as a Director under the Act;
(m) "dismantling" means the removal of buildings, structures, process and pollution abatement equipment, vessels, storage facilities, material handling facilities, railways, roadways, pipelines and any other installations that are being or have been used or held for or in connection with the plant;
(n) "fugitive emissions" means emissions of substances to the atmosphere other than ozone depleting substances, originating from a plant source other than a flue, vent, or stack but does not include sources which may occur due to breaks or ruptures in process equipment;
(o) "industrial runoff" means precipitation that falls on or traverses the plant developed area;
(p) "industrial runoff control system" means the parts of the plant that collect, store or treat industrial runoff from the plant;
(q) "industrial wastewater" means the composite of liquid wastes and water-carried wastes, any portion of which results from any industrial process carried on at the plant;
(r) "industrial wastewater control system" means the parts of the plant that collect, store or treat industrial wastewater;
(s) “ISO 17025” means the international standard, developed and published by International Organization for Standardization (ISO), specifying the management and technical requirements for laboratories;
(t) "local environmental authority" means the Department of Environment, in the Province of Alberta, or the agency that has the equivalent responsibilities for any jurisdiction outside the Province;
(u) "manual stack survey" means a survey conducted in accordance with the Alberta Stack Sampling Code, Alberta Environment, 1995, as amended;
(v) "monitoring system" means all equipment used for sampling, conditioning, analyzing or recording data in respect of any parameter listed or referred to in this approval including equipment used for continuous monitoring;
(w) "month" means calendar month;
(x) "net or lower heating value" means the quantity of heat evolved on complete combustion where the combustion products remain as vapour at 15°C;
APPROVAL NO. 155-02-00 Page 3 of 31
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TERMS AND CONDITIONS ATTACHED TO APPROVAL
(y) "plant” means all buildings, structures, process and pollution abatement equipment, vessels, storage facilities, material handling facilities, roadways, pipelines and other installations, and includes the land, located on East half of Section 2, Township 26, Range 29, West of the 4th Meridian, that is being or has been used or held for or in connection with the Balzac sour gas processing plant and sulphur processing plant;
(z) "plant developed area" means the areas of the plant used for the storage, treatment, processing, transport, or handling of raw material, intermediate product, by-product, finished product, process chemicals, or waste material;
(aa) "QA/QC" means quality assurance and quality control;
(bb) "quarter year" means a time period of three consecutive months designated as January, February, and March; or April, May, and June; or July, August, and September; or October, November, and December;
(cc) "representative grab sample" means a sample consisting of equal volume portions of water collected from at least four sites between 0.20-0.30 metres below the water surface within a pond;
(dd) "soil" means mineral or organic earthen materials that can, have, or are being altered by weathering, biological processes, or human activity;
(ee) "suitable quality" means topsoil having a good, fair or poor rating as described in the Soil Quality Criteria Relative to Disturbance and Reclamation, Alberta Agriculture March, 1987, as amended;
(ff) "tank" means a stationary device, designed to contain an accumulation of a substance, which is constructed primarily of non-earthen materials that provide structural support including wood, concrete, steel, and plastic;
(gg) "topsoil" means the uppermost layer of suitable quality soil, containing organic matter, ordinarily moved in tillage or its equivalent in uncultivated soils;
(hh) "volume estimate" means a technical evaluation based on the sources contributing to the release, including, but not limited to, pump capabilities, water meters, and batch release volumes;
(ii) "week" means any consecutive 7-day period unless otherwise specified.
PART 2: GENERAL
SECTION 2.1: GENERAL
APPROVAL NO. 155-02-00 Page 4 of 31
………………….
TERMS AND CONDITIONS ATTACHED TO APPROVAL 2.1.1 The approval holder shall immediately report to the Director by telephone any
contravention of the terms and conditions of this approval at 1-780-422-4505.
2.1.2 The approval holder shall submit a written report to the Director within 7 days of the reporting pursuant to 2.1.1.
2.1.3 The terms and conditions of this approval are severable. If any term or condition of this approval or the application of any term or condition is held invalid, the application of such term or condition to other circumstances and the remainder of this approval shall not be affected thereby.
2.1.4 The approval holder shall immediately notify the Director in writing if any of the following events occurs:
(a) the approval holder is served with a petition into bankruptcy;
(b) the approval holder files an assignment in bankruptcy or Notice of Intent to make a proposal;
(c) a receiver or receiver-manager is appointed;
(d) an application for protection from creditors is filed for the benefit of the approval holder under any creditor protection legislation; or
(e) any of the assets which are the subject matter of this approval are seized for any reason.
2.1.5 If the approval holder monitors for any substances or parameters which are the subject of operational limits as set out in this approval more frequently than is required and using procedures authorized in this approval, then the approval holder shall provide the results of such monitoring as an addendum to the reports required by this approval.
2.1.6 All abbreviations used in this approval follow those given in Standard Methods for the Examination of Water and Wastewater published jointly by the American Public Health Association, the American Water Works Association, and the Water Environment Federation, 1998, as amended, unless otherwise specified in this approval.
2.1.7 Environmental Protection and Enhancement Act Approval No. 155-01-00 (previously approved as 95-IND-072) is cancelled.
SECTION 2.2: RECORD KEEPING
APPROVAL NO. 155-02-00 Page 5 of 31
………………….
TERMS AND CONDITIONS ATTACHED TO APPROVAL 2.2.1 The approval holder shall record and retain all the following information in respect of
any sampling conducted or analyses performed in accordance with this approval for a minimum of ten years, unless otherwise authorized in writing by the Director:
(a) the place, date and time of sampling;
(b) the dates the analyses were performed;
(c) the analytical techniques, methods or procedures used in the analyses;
(d) the names of the persons who collected and analyzed each sample; and
(e) the results of the analyses.
SECTION 2.3: ANALYTICAL REQUIREMENTS
2.3.1 With respect to any sample required to be taken pursuant to this approval, the approval holder shall ensure that:
(a) collection; (b) preservation; (c) storage; (d) handling; and (e) analysis;
shall be conducted in accordance with the following unless otherwise authorized in
writing by the Director:
(i) for air monitoring:
(A) the Alberta Stack Sampling Code, Alberta Environment, 1995, as amended;
(B) the Methods Manual for Chemical Analysis of Atmospheric Pollutants, Alberta Environment, 1993, as amended;
(C) the Air Monitoring Directive, Alberta Environment, 1989, as amended; and,
(D) the CEMS Code;
APPROVAL NO. 155-02-00 Page 6 of 31
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TERMS AND CONDITIONS ATTACHED TO APPROVAL
(ii) for industrial wastewater, industrial runoff, groundwater and domestic wastewater parameters:
(A) the Standard Methods for the Examination of Water and Wastewater, published jointly by the American Public Health Association, American Water Works Association, and the Water Environment Federation, 1998, as amended;
(iii) for soil samples:
(A) Soil Sampling and Methods of Analysis, Lewis Publishers, 1993, as amended;
(B) the Test Methods for Evaluating Solid Waste, Physical/Chemical Methods, USEPA, SW-846; September 1986, as amended;
(C) the Soil Quality Criteria Relative to Disturbance and Reclamation, Alberta Agriculture, March 1987, as amended;
(D) the Guidance Manual on Sampling, Analysis and Data Management for Contaminated Sites – Volume I: Main Report, CCME EPC-NCS62E, 1993, as amended; and
(E) the Guidance Manual on Sampling, Analysis and Data Management for Contaminated Sites – Volume II: Analytical Method Summaries, CCME EPC-NCS66E, 1993, as amended;
2.3.2 The approval holder shall analyze all samples that are required to be obtained by this approval in a laboratory accredited pursuant to ISO 17025, as amended, for the specific parameter(s) to be analyzed, unless otherwise authorized in writing by the Director.
2.3.3 The approval holder shall comply with the terms and conditions of any written
authorization issued by the Director under 2.3.2. SECTION 2.4: OTHER 2.4.1 All industrial wastewater and process liquids contained in above and below ground
storage tanks, shall be contained in accordance with the Alberta Energy and Utilities Board (EUB) Guide G-55 "Storage Requirements for the Upstream Petroleum Industry", as amended.
2.4.2 All aboveground storage tanks containing liquid hydrocarbons or organic compounds
shall conform to the Environmental Guidelines for Controlling Emissions of Volatile
APPROVAL NO. 155-02-00 Page 7 of 31
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TERMS AND CONDITIONS ATTACHED TO APPROVAL
Organic Compounds from Aboveground Storage Tanks, CCME-EPC-87-E, as amended.
PART 3: CONSTRUCTION
Not used at this time.
PART 4: OPERATIONS, LIMITS, MONITORING AND REPORTING
SECTION 4.1: AIR
OPERATIONS
4.1.1 The approval holder shall not emit any effluent streams to the atmosphere except as provided in this approval.
4.1.2 The approval holder shall only emit effluent streams to the atmosphere from the following sources:
(a) the East Sulphur recovery process unit incinerator stack;
(b) the two Emergency Flare Stacks (Low and High Pressure);
(c) the three 24,625 kW power boiler exhaust stacks;
(d) the 246 kW compressor engine exhaust stack;
(e) the 328 kW compressor engine exhaust stack;
(f) the two 410 kW compressor engine exhaust stacks;
(g) the four 1,790 kW compressor engine exhaust stacks (two stacks for each engine);
(h) the two 13,800 kW still reboiler exhaust stacks (one standby);
(i) the two 1,760 kW stabilizer reboiler exhaust stacks (one standby);
(j) the 3,250 kW sulfreen heater exhaust stack;
(k) the two 513 kW Salt Bath Heaters;
(l) the three Enersul GXM2 sulphur granulator units exhaust stacks;
(m) the natural gas fired emergency generator exhaust stack;
APPROVAL NO. 155-02-00 Page 8 of 31
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TERMS AND CONDITIONS ATTACHED TO APPROVAL
(n) the diesel emergency firewater pump exhaust stacks;
(o) the instrument air compressor engine stack;
(p) the space ventilation exhaust stacks as described in the application;
(q) the space heater exhaust vents as described in the application;
(r) the compressor starter gas vents as described in the application; and
(s) any other source authorized in writing by the Director or by an amendment to this approval.
4.1.3 The approval holder shall maintain the following stacks according to the minimum height requirements specified in TABLE 4.1-A and TABLE 4.1-B:
TABLE 4.1-A: STACK HEIGHTS
STACK MINIMUM HEIGHT ABOVE GRADE (metres)
High Pressure Emergency Flare Stack 61.6
Low Pressure Emergency Flare Stack 61.3
East Sulphur Recovery Process Unit Incinerator Stack 121.9
TABLE 4.1-B: STACK HEIGHTS
COMPRESSOR ENGINE RATED CAPACITY KILOWATTS (kW)
NUMBER OF ENGINES
MINIMUM HEIGHT ABOVE GRADE (metres)
246 1 18.4
328 1 18.4
410 2 18.2
1,790 4 16.25 4.1.4 The approval holder shall operate the emergency flare stacks in accordance with
4.1.9.
APPROVAL NO. 155-02-00 Page 9 of 31
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TERMS AND CONDITIONS ATTACHED TO APPROVAL 4.1.5 Residue gas shall be added to the sour gas released to the emergency flare stacks
such that the net or lower heating value of the combined gas stream is not less than 12 MJ/m3 (at 101.325 kPa and 15°C), unless otherwise authorized in writing by the Director.
4.1.6 The approval holder shall ensure the combustion of all combustible gases released to the emergency flare stacks.
4.1.7 The approval holder shall equip and operate all emergency flare stacks with:
(a) a wind guard; and
(b) a continuously burning pilot light; and
(c) an electric, or equivalent, ignitor.
4.1.8 All plant pressure safety valves in sour gas service shall be connected to the flare system.
4.1.9 Except as provided for by the Director in writing, the approval holder shall not emit fugitive emissions or an air contaminant from any source not specified in 4.1.2 or an air contaminant from the emergency flare stacks that causes or may cause any of the following:
(a) the impairment, degradation or alteration of the quality of natural resources; or
(b) material discomfort, harm or adversely affect the well being or health of a person; or
(c) harm to property or to plant or animal life.
SULPHUR PROCESSING PLANT
4.1.10 Effective the earlier of April 30, 2006 or the commencement of full operation of the new Sulphur Handling Facility as described in application 010-155:
(a) sulphur shall only be processed by the new Sulphur Handling Facility consisting of the Enersul GXM2 sulphur granulator units;
(b) no sulphur shall be processed by the existing Sulphur Handling Facility consisting of the slater units.
4.1.11 The approval holder shall provide, to the Director by March 31, 2006, an amendment to the Decommissioning and Reclamation Plan for the Sulphur Handling Facility dated November 2004 that consists of an update of the schedule of activities to be undertaken as described in the Plan, unless otherwise authorized in writing by the Director.
APPROVAL NO. 155-02-00 Page 10 of 31
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TERMS AND CONDITIONS ATTACHED TO APPROVAL 4.1.12 The approval holder shall implement the Decommissioning and Reclamation Plan as
amended, as referred to in 4.1.11, unless otherwise authorized in writing by the Director.
4.1.13 Effective the earlier of April 30, 2006 or the commencement of full operation of the new Sulphur Handling Facility as described in application 010-155, the approval holder shall not operate the existing Sulphur Handling Facility unless the approval holder has obtained an amendment permitting such operation.
LIMITS 4.1.14 Release of air contaminants shall not exceed the limits specified in TABLE 4.1-C.
TABLE 4.1-C: LIMITS
EMISSION SOURCE AIR CONTAMINANT/ PARAMETER LIMIT
2.33 tonnes per hour
40.0 tonnes per day Sulphur Dioxide
10,300 parts per million by volume for a one-hour
averaging period
East Sulphur Recovery Process Unit Incinerator Stack
Temperature a minimum of 465°C for a one-hour averaging period
Sulphur granulator units SHF_1 and 2 and 3 exhaust stacks
Total Particulate Matter 0.20 grams per kilogram of
effluent
MONITORING AND REPORTING 4.1.15 The approval holder shall monitor as specified in TABLE 4.1-D.
4.1.16 The approval holder shall report as specified in TABLE 4.1-D.
APPROVAL NO. 155-02-00 Page 11 of 31
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TERMS AND CONDITIONS ATTACHED TO APPROVAL TABLE 4.1-D SOURCE MONITORING AND REPORTING
EMISSION SOURCE/ EFFLUENT STREAM
PARAMETER SAMPLING FREQUENCY
MONITORING METHOD
METHOD OF ANALYSIS
REPORTING FREQUENCY (one copy required)
REPORT TO
Sulphur Dioxide, Flow Rate,
and Temperature
Continuous CEM CEMS Code
Monthly, before the end
of the next month
East Sulphur Recovery Process Unit Incinerator Stack
Sulphur Dioxide Twice per year Manual Stack Survey
Alberta Stack Sampling
Code
Twice per year, each by the end of the Month after
the survey is done
Emergency Flare Stacks
Amount of Sulphur Dioxide released to the
atmosphere
Acid gas & residue or fuel gas released to
flare
Daily Measured or estimated
Mass Balance
Monthly, before the end
of the next month
Exhaust stacks of Sulphur granulator Units SHF_1, SRF 2 or SRF 3
Total Particulate Matter, PM2.5
Annual sampling of
one stack at a minimum, with
rotation so that each of the stacks shall be
surveyed at a minimum once
every three years
Manual Stack Survey
Alberta Stack Sampling
Code
Before the end of the Month
after the month in which the
survey is done
Director
4.1.17 The approval holder shall monitor for ambient levels of all parameters as specified in
TABLE 4.1-E.
4.1.18 The approval holder shall report as specified in TABLE 4.1-E.
APPROVAL NO. 155-02-00 Page 12 of 31
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TERMS AND CONDITIONS ATTACHED TO APPROVAL TABLE 4.1-E: AMBIENT MONITORING AND REPORTING
PARAMETER TO BE ANALYSED OR MEASURED
NUMBER OF MONITORING SITES
FREQUENCY METHOD OF MONITORING
METHOD OF ANALYSIS OF MEASURE-MENT
REPORT FREQUENCY (one copy required)
REPORT TO
SO2, H2S, wind speed and direction
2 ambient air quality monitoring
stations
12 Months/year Continuous
Total Sulphation and Hydrogen Sulphide
13 exposure stations Monthly Exposure
Stations
Monthly, before the end of the
next month
Soil Testing in accordance with the Air Monitoring Directive
As authorized by the Director Annually Air Monitoring
Directive
Air Monitoring Directive
Annually
Director
4.1.19 An annual summary and evaluation report shall be submitted to the Director by March
15 of each year that contains for the previous year information related to plant operation, performance of air pollution control equipment and air contaminant emissions.
STUDIES 4.1.20 The approval holder shall submit a proposal to the Director by June 1, 2006 for
investigating the elevated ambient air H2S concentrations observed at the ambient air quality monitoring stations to the Director by June 1, 2006.
4.1.21 The proposal referred to in 4.1.20 shall include the following:
(a) site map showing the plant in relation to activities believed to contribute to elevated ambient air H2S concentrations;
(b) description and summary of dates of observed elevated ambient air H2S concentrations and wind speed and direction, observed plant activities and other possible factors related to elevated ambient air H2S concentrations;
(c) method to investigate sources of elevated ambient air H2S concentrations including additional monitoring based on historic events;
(d) possible means to mitigate or prevent elevate ambient air H2S concentrations; and,
APPROVAL NO. 155-02-00 Page 13 of 31
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TERMS AND CONDITIONS ATTACHED TO APPROVAL
(e) a schedule for implementing the investigation.
4.1.22 The approval holder shall implement the proposal referred to 4.1.20 as authorized in writing by the Director.
4.1.23 The approval holder shall submit a report summarizing the results of the investigation referred to in 4.1.20 and as authorized in writing by the Director by March 31, 2007.
SPECIAL REPORTING 4.1.24 The approval holder shall continuously measure or estimate and record on a daily
basis the average sulphur inlet rates in tonnes per day.
4.1.25 If the percentage of daily SO2 mass emission rates as reported in 4.1.26 are less than or equal to the values in Column 3 in TABLE 4.1-F for the applicable daily SO2 mass emission (Column 2, TABLE 4.1-F) based on the average daily sulphur inlet rates (Column 1, TABLE 4.1-F) at which the plant operated during the reporting period;
OR
If the percentage of hourly SO2 mass emission rates as reported in 4.1.26 are less than or equal to the values in Column 5 in TABLE 4.1-F for the applicable hourly SO2 mass emission (Column 4, TABLE 4.1-F) based on the average daily sulphur inlet rates (Column 1, TABLE 4.1-F) at which the plant operated during the reporting period;
then the following information shall be provided in the monthly report by the approval holder:
(a) a description of the events or circumstances that lead to higher cumulative mass emission readings; and
(b) an outline of the action taken to control the magnitude and/or duration of the event; and
(c) a description of any long-term measures or actions that are required to prevent or minimize such occurrences in the future and a schedule of implementation for these measures or actions.
APPROVAL NO. 155-02-00 Page 14 of 31
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TERMS AND CONDITIONS ATTACHED TO APPROVAL
TABLE 4.1-F: SO2 MASS EMISSION TIERS
COLUMN 1 COLUMN 2 COLUMN 3 COLUMN 4 COLUMN 5
PLANT DAILY AVERAGE SULPHUR INLET RATE
(TONNES/DAY)
DAILY SO2 MASS EMISSION (TONNES/DAY)
Sulphur Recovery Process Unit Incinerator Stack
% OF DAILY READINGS IN A MONTH THAT ARE TO BE LESS THAN THE DAILY MASS EMISSION VALUE IN COLUMN 2
HOURLY SO2 MASS EMISSION (TONNES/HOUR)
Sulphur Recovery Process Unit Incinerator Stack
% OF HOURLY READINGS IN A MONTH THAT ARE TO BE LESS THAN THE HOURLY MASS EMISSION VALUE IN COLUMN 4
0 – 300.0 12.0 90.0 0.70 90.0
300.1 – 700.0 28.0 93.3 1.63 95.0
700.1 – 975.0 39.0 96.7 2.28 98.0
4.1.26 The approval holder shall report the frequency distribution of both the hourly and daily mass emission rates of sulphur dioxide versus the monthly average daily sulphur inlet rate monthly.
4.1.27 The approval holder shall notify in writing the Director a minimum of two weeks prior to all stack surveys.
SECTION 4.2: INDUSTRIAL WASTEWATER
OPERATIONS
4.2.1 The approval holder shall not release any substances from the plant to the surrounding watershed except as authorized by this approval.
4.2.2 Industrial wastewater shall be managed as described in the application, unless otherwise authorized in writing by the Director.
4.2.3 Industrial wastewater that is collected in the Double Lined Open Drain Collection Pond shall only be disposed as follows:
(a) to an Alberta Energy and Utilities Board (EUB) approved disposal well; or
(b) to an Alberta Energy and Utilities Board (EUB) approved Waste Processing and Disposal Facility; or
APPROVAL NO. 155-02-00 Page 15 of 31
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TERMS AND CONDITIONS ATTACHED TO APPROVAL
(c) as otherwise authorized in writing by the Director.
4.2.4 The approval holder shall only release the following industrial wastewater streams to the Blowdown Holding Ponds:
(a) Boiler blowdown; and,
(b) Cooling tower blowdown.
4.2.5 The approval holder shall only release industrial wastewater from the Blowdown Holding Ponds via pipeline to McDonald Lake, unless otherwise authorized in writing by the Director.
4.2.6 All industrial runoff from the plant developed area shall be directed to the Sulphur Block Area Surface Runoff Collection Pond.
4.2.7 The approval holder shall only release industrial runoff from the Sulphur Block Area Surface Runoff Collection Pond via pipeline to McDonald Lake, unless otherwise authorized in writing by the Director.
LIMITS
4.2.8 Releases from the Blowdown Holding Ponds shall not exceed the limits for the parameters specified in TABLE 4.2-A.
4.2.9 Releases from the Sulphur Block Area Surface Runoff Collection Pond shall not exceed the limits for the parameters specified in TABLE 4.2-A.
APPROVAL NO. 155-02-00 Page 16 of 31
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TERMS AND CONDITIONS ATTACHED TO APPROVAL TABLE 4.2-A: LIMITS
PARAMETER LIMIT
Industrial Wastewater Released from the Blowdown Holding Ponds
PH 6.0 - 9.5 pH units
Floating solids Must not be present except in trace amounts
Visible foam Must not be present except in trace amounts
Oil or other substances Must not be present in amounts sufficient to create a visible film or sheen
Chemical Oxygen Demand 200 mg/L
Ammonia-Nitrogen 5 mg/L
Oil & Grease 5 mg/L
Total Suspended Solids 25 mg/L
Chlorine Residual 0.3 mg/L
Industrial Runoff Released from the Sulphur Block Area Surface Runoff Collection Pond pH 6 – 9.5 pH units
Oil & Grease No visible sheen
Chemical Oxygen Demand 50 mg/L
Ammonia-Nitrogen 5 mg/L
Total Suspended Solids 25 mg/L
Chloride 500 mg/L
APPROVAL NO. 155-02-00 Page 17 of 31
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TERMS AND CONDITIONS ATTACHED TO APPROVAL MONITORING AND REPORTING 4.2.10 The approval holder shall monitor the Blowdown Holding Ponds, Industrial Runoff
Control System and McDonald Lake as required in TABLE 4.2-B unless otherwise authorized by the Director.
4.2.11 The approval holder shall report to the Director the results of monitoring the Blowdown Holding Pond, Industrial Runoff Control System and McDonald Lake as required in TABLE 4.2-B.
4.2.12 For the purpose of Table 4.2-B:
(a) sampling location A is defined as Blowdown Holding Ponds;
(b) sampling location B is defined as Sulphur Block Area Surface Runoff Collection Pond; and
(c) sampling location C is defined as McDonald Lake.
APPROVAL NO. 155-02-00 Page 18 of 31
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TERMS AND CONDITIONS ATTACHED TO APPROVAL TABLE 4.2-B: INDUSTRIAL WASTEWATER AND INDUSTRIAL RUNOFF CONTROL
SYSTEM MONITORING AND REPORTING
MONITORING REPORTING
PRIOR TO RELEASE
DURING RELEASE
Parameter, Test, Event, Study Proposal or
Reporting Requirement Frequency Frequency Sample Type Sampling
Location Monthly Annually
Flow (m3/d) Daily Estimate A, B
Ammonia-Nitrogen (mg/L)
Weekly Representative Grab A, B
Total Suspended Solids (mg/L)
Weekly Representative Grab A, B
pH Daily Representative Grab A, B
Floating Solids Daily Visual A
Visible Foam Daily Visual A
Oil and Grease Daily Visual B
Oil and Grease (mg/L) Weekly Representative Grab A
Chemical Oxygen Demand (mg/L) Weekly Representative
Grab A, B
Chloride (mg/L) Weekly Representative Grab B
Chlorine Residual (mg/L) Weekly Representative Grab A
Sulphate (mg/L) Weekly Representative Grab B
Total Phosphorus (mg/L) Weekly Representative Grab A
Conductivity (umhos) Weekly Representative Grab A
Monthly Industrial
Wastewater and Industrial
Runoff Report as per
4.2.13
(On or before the end of the month
following the month in which the
information was
collected)
Number of Copies
Required 1
Temperature, pH, total hardness, total alkalinity, carbonate, bicarbonate, chloride, sulphate, nitrite-nitrogen, nitrate-nitrogen, sodium, magnesium, potassium, total iron, oil & grease, chemical oxygen demand, conductivity, total dissolved solids, water level, BTEX and F1 Parameters
Once per year
Representative Grab C Not
required
Annual Industrial
Wastewater and
Industrial Runoff
Report as per 4.2.14 due March 15 of each
year
Number of Copies
Required 1
APPROVAL NO. 155-02-00 Page 19 of 31
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TERMS AND CONDITIONS ATTACHED TO APPROVAL 4.2.13 In addition to the monthly reporting in Table 4.2-B, the monthly Industrial Wastewater
and Industrial Runoff Report shall include, at a minimum, all of the following information:
(a) an assessment of the monitoring results relative to the limits in TABLE 4.2-A;
(b) the release from the Blowdown Holding Pond and the Industrial Runoff Pond to McDonald Lake for the parameters listed in TABLE 4.2-A in kilograms per day;
(c) the daily minimum, maximum and average pH recorded as per TABLE 4.2-B;
(d) an assessment of the performance of the Industrial Wastewater Control System, the Industrial Runoff Control System, pollution abatement equipment and monitoring equipment;
(e) a summary of contraventions reported pursuant to 2.1.1; and
(f) any other information as required in writing by the Director.
4.2.14 In addition to the annual reporting in Table 4.2-B, the Annual Industrial Wastewater and Industrial Runoff Report shall include, at a minimum, all of the following information:
(a) an overview of the operation and performance of the Industrial Wastewater and Industrial Runoff Control Systems and pollution abatement equipment;
(b) a tabulated summary of the monitoring results for the industrial wastewater and industrial runoff released to McDonald Lake including the minimum, maximum and average for all the parameters listed in Table 4.2-B for each month;
(c) an assessment of the monitoring results relative to the limits specified in Table 4.2-A including trend analysis and control charts;
(d) a summary of contraventions reported pursuant to 2.1.1; and
(e) any other information as required in writing by the Director.
APPROVAL NO. 155-02-00 Page 20 of 31
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TERMS AND CONDITIONS ATTACHED TO APPROVAL SULPHUR MANAGEMENT
4.2.15 The approval shall not pour liquid sulphur to the sulphur storage blocks unless the following requirements are met:
(a) the pouring shall be conducted under the circumstances specified in the application or in the event of an emergency event; and,
(b) the approval holder shall notify the following parties at least 72 hours in advance of the commencement of the set up of pouring: (i) Alberta Environment, and (ii) all residents within a 3 km radius of the plant; and
(c) any other information as required in writing by the Director.
4.2.16 The approval holder shall ensure that sulphur spills are cleaned up as soon as possible after each spill event.
4.2.17 The approval holder shall submit to the Director by October 31, 2006 an Environmental Assessment for management of contaminated sulphur and materials contaminated with sulphur.
4.2.18 The Environmental Assessment for management of contaminated sulphur and materials contaminated with sulphur shall include, but is not limited to, the sulphur block and basepads, the slater units, the sulphur load-out area, the sulphur storage pad and sulphur soil pile. The Assessment shall include:
(a) an estimate of contaminated sulphur and material contaminated with sulphur;
(b) a schedule for removal and disposal of contaminated sulphur and materials contaminated with sulphur;
(c) an evaluation of the permeability of the areas where the contaminated sulphur and materials contaminated with sulphur are stored;
(d) recommendations for upgrading the storage area(s) with an impermeable surface based on the results from 4.2.18(c);
(e) recommendations for mitigating wind erosion of the storage area(s);
(f) recommendations for upgrading and lining the collection ditches and sump areas;
(g) material specification of proposed liners;
(h) schedule of planned activities; and
(i) any other information the Director requires.
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TERMS AND CONDITIONS ATTACHED TO APPROVAL 4.2.19 The approval holder shall correct any deficiencies in the Environmental Assessment
referred to in 4.2.18 as specified in writing by the Director.
4.2.20 The approval holder shall implement the Environmental Assessment recommendations referred to in 4.2.18 and as authorized in writing by the Director.
UPGRADES TO INDUSTRIAL RUNOFF CONTROL SYSTEM
4.2.21 The approval holder shall conduct an assessment of Industrial Runoff at the plant. The assessment shall have the following components:
(a) a brief description of the catchment areas;
(b) a description of the sampling program for collecting samples of industrial runoff from catchment areas in 2006 including a site plan showing the catchment areas and the locations of where the samples were taken;
(c) interpretation and tabulation of the analytical results including the laboratory analytical results;
(d) a determination of industrial runoff quantities at the plant and for each catchment area;
(e) a description of the risks of contaminating industrial runoff at each catchment area;
(f) an assessment of implementing Best Management Practices (BMPs) at the plant to mitigate industrial runoff at the plant including the possibility of diverting industrial runoff from specified portions of catchment areas and details on the receiving areas and potential impacts on these receiving areas.
(g) a plan and schedule for implementing BMPs at the plant.
4.2.22 The approval holder shall submit the Industrial Runoff Assessment referred to in 4.2.21 to the Director by December 1, 2006 unless otherwise authorized in writing by the Director.
4.2.23 The approval holder shall implement the plan referred to in 4.2.21(g) as authorized in writing by the Director.
APPROVAL NO. 155-02-00 Page 22 of 31
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TERMS AND CONDITIONS ATTACHED TO APPROVAL UPGRADES TO INDUSTRIAL WASTEWATER CONTROL SYSTEM
4.2.24 The approval holder shall submit a proposal to the Director by December 1, 2006 for upgrading the industrial wastewater control system. The proposal shall include, at a minimum, all of the following:
(a) identification of the chemicals of concern in the boiler blowdown and cooling tower blowdown based on treatment chemicals used for the boiler and cooling tower water systems;
(b) review of the monitoring results of the blowdown holding pond including a tabulated summary, graphs showing trends for monitoring data collected from 1995 to 2005;
(c) an assessment of the boiler and cooling tower water treatment systems to determine the optimum number of cycles to minimize treatment chemical usage and contaminants in the blowdown including Total Suspended Solids;
(d) an assessment of technology options for treating boiler blowdown and cooling tower blowdown including:
(i) the quality of treated wastewater that can be achieved for each technology option and feasibility of recycling this treated wastewater to the cooling water and boiler or other uses;
(ii) the estimated quantity and quality of the waste stream resulting from the treatment technology and possible disposal options; and
(iii) recommendations for the most effective treatment technology option for implementation at the plant; and
(iv) a schedule for this work to be done.
4.2.25 If the proposal referred to in 4.2.24 is found deficient by the Director, the approval holder shall correct all the deficiencies as outlined by the Director within 120 days of the deficiency letter.
4.2.26 The approval holder shall implement the recommendations referred to in 4.2.24(d)(iii) as authorized in writing by the Director.
SECTION 4.3: WASTE MANAGEMENT
OPERATIONS
Not used at this time.
APPROVAL NO. 155-02-00 Page 23 of 31
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TERMS AND CONDITIONS ATTACHED TO APPROVAL SECTION 4.4: DOMESTIC WASTEWATER
OPERATIONS
4.4.1 All domestic wastewater shall be directed to a septic tank with subsequent disposal to an approved municipal wastewater treatment system.
SECTION 4.5: WATERWORKS
Not used at this time.
SECTION 4.6: GROUNDWATER
4.6.1 The approval holder shall implement the Groundwater Monitoring Program for the plant as authorized in writing by the Director.
4.6.2 The samples extracted from the groundwater monitor wells shall be collected using scientifically acceptable purging, sampling and preservation procedures so that a representative groundwater sample is obtained.
4.6.3 All groundwater monitor wells shall be:
(a) protected from damage; and
(b) locked except when being sampled; unless otherwise authorized in writing by the Director.
4.6.4 If a representative groundwater sample cannot be collected because the groundwater monitor well is damaged or is no longer capable of producing a representative groundwater sample:
(a) the groundwater monitor well shall be cleaned, repaired or replaced; and
(b) a representative groundwater sample shall be collected and analyzed prior to the next scheduled sampling event; unless otherwise authorized in writing by the Director.
4.6.5 In addition to the sampling information recorded in 2.2.1, the approval holder shall record the following sampling information for all groundwater samples collected:
(a) a description of purging and sampling procedures;
(b) the static elevations, above sea level, of fluid phases in the groundwater monitor well prior to purging;
(c) the temperature of each sample at the time of sampling;
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TERMS AND CONDITIONS ATTACHED TO APPROVAL
(d) the pH of each sample at the time of sampling; and
(e) the specific conductance of each sample at the time of sampling.
4.6.6 The approval holder shall compile an Annual Groundwater Monitoring Program Summary Report which shall include, at a minimum, all of the following information:
(a) a legal description of the plant and a map illustrating the plant boundaries;
(b) a topographic map of the plant;
(c) a description of the industrial activity and processes;
(d) a map showing the location of all surface and groundwater users, and, a listing describing surface water and water well use details, within at least a three kilometre radius of the plant;
(e) a general hydrogeological characterization of the region within a five kilometre radius of the plant;
(f) a detailed hydrogeological characterization of the plant;
(g) a geological cross-section(s) of the plant;
(h) a map of surface drainage patterns located within the plant;
(i) a map of groundwater monitor well locations and a description of the existing groundwater monitoring program for the plant;
(j) a summary of any changes to the groundwater monitoring program made since the last groundwater monitoring report;
(k) analytical data recorded as required in 4.6.1 and 4.6.5;
(l) a summary of fluid elevations recorded as required in 4.6.5(b) and an interpretation of changes in fluid elevations;
(m) an interpretation of groundwater flow patterns;
(n) an interpretation of the analytical results including the following:
(i) diagrams indicating the location of any contamination identified,
(ii) probable sources of contamination, and
(iii) the extent of contamination identified;
APPROVAL NO. 155-02-00 Page 25 of 31
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TERMS AND CONDITIONS ATTACHED TO APPROVAL
(o) a summary and interpretation of the data collected since the groundwater monitoring program began including:
(i) control charts which indicate trends in contaminant concentrations, and
(ii) the migration of contaminants;
(p) a description of the following:
(i) contaminated groundwater remediation techniques employed,
(ii) source elimination measures employed,
(iii) risk assessment studies undertaken, and
(iv) risk management studies undertaken;
(q) a sampling schedule for the following year;
(r) recommendations, as follows;
(i) for changes to the groundwater monitoring program to make it more effective; and
(ii) for remediation, risk assessment or risk management of contamination identified.
4.6.7 The approval holder shall submit two copies of the Annual Groundwater Monitoring Summary Report to the Director on or before April 14 of the year following the year in which the information on which the report is based was collected, unless otherwise authorized in writing by the Director.
SECTION 4.7: SOIL
MONITORING
4.7.1 The approval holder shall develop and document proposals for the Soil Monitoring Program in accordance with the Soil Monitoring Directive, Alberta Environment, May 1996, as amended.
4.7.2 The approval holder shall submit the Soil Monitoring Program proposals to the Director for authorization in writing according to the following schedule:
(a) for the first soil monitoring proposal, no later than May 1, 2006; and
(b) for the second soil monitoring proposal, no later than March 1, 2011; or
APPROVAL NO. 155-02-00 Page 26 of 31
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TERMS AND CONDITIONS ATTACHED TO APPROVAL
unless otherwise authorized in writing by the Director.
4.7.3 If the Soil Monitoring Program proposals are found deficient by the Director, the approval holder shall correct all the deficiencies as outlined by the Director within 120 days of the deficiency letter.
4.7.4 The approval holder shall implement the Soil Monitoring Program proposals as authorized in writing by the Director.
4.7.5 The approval holder shall implement QA/QC provisions in accordance with the CCME Guidance Manual on Sampling, Analysis and Data Management for Contaminated Sites, Volume I, Report CCME EPC-NCS62E, Winnipeg, Manitoba, December 1993, as amended.
STANDARDS
4.7.6 For sampling locations which meet the conditions in C.1 of the Soil Monitoring Directive, May 1996, as amended, the concentration of substances in soil shall be compared to values in the following:
(a) for petroleum hydrocarbons, Alberta Soil and Water Quality Guidelines for Hydrocarbons at Upstream Oil and Gas Facilities, Alberta Environment, 2001, as amended;
(b) for salt, Salt Contamination Assessment and Remediation Guidelines, Alberta Environment, 2001, as amended;
(c) for substances not included in 4.7.6 (a) or (b), Canadian Environmental Quality Guidelines, Canadian Council of Ministers of the Environment, PN1299, 1999, as amended, excluding values determined before 1997;
(d) for substances not found in 4.7.6 (a) to (c), for soil which will be remediated to an agricultural, residential, or parkland land use, Alberta Tier I Criteria for Contaminated Soil Assessment and Remediation, Alberta Environmental Protection, March 1994, as amended; and
(e) for substances not found in 4.7.6 (a) to (c), for soil which will be remediated to a commercial or industrial land use, the Interim Canadian Environmental Quality Criteria for Contaminated Sites, Canadian Council of Ministers of the Environment, EPC-CS34, September 1991, as amended.
4.7.7 For sampling locations which do not meet the conditions in C.1 of the Soil Monitoring Directive, May 1996, as amended, or if substances are present that are not listed in the standards referred to in 4.7.6 (a) to 4.7.6 (e), the concentrations of substances in soil shall be compared to values derived using methods in C.2 of the Soil Monitoring Directive.
APPROVAL NO. 155-02-00 Page 27 of 31
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TERMS AND CONDITIONS ATTACHED TO APPROVAL REPORTING
4.7.8 The approval holder shall submit two copies of each Soil Monitoring Program Report to the Director summarizing the data obtained from the soil monitoring referred to in 4.7.4 according to the following schedule:
(a) for the first soil monitoring report, no later than December 1, 2006; and
(b) for the second soil monitoring report, no later than October 1, 2011; or
unless otherwise authorized in writing by the Director.
4.7.9 The Soil Monitoring Program reports shall be as prescribed in the reporting requirements of the Soil Monitoring Directive, May 1996, as amended.
SOIL MANAGEMENT PROGRAM
4.7.10 If the Soil Monitoring Program, or any other soil monitoring, reveals that there are substances present in the soil at concentrations greater than the applicable concentrations in 4.7.6 or 4.7.7, the approval holder shall develop and document a Soil Management Program Proposal in accordance with the Guideline for Monitoring and Management of Soil Contamination Under EPEA Approvals, Chemicals Assessment and Management Division, May 1996, as amended, or as otherwise authorized in writing by the Director.
4.7.11 If required pursuant to 4.7.10, the approval holder shall submit a Soil Management Program Proposal to the Director within six months after the date that the Soil Monitoring Report referred to in 4.7.8 is due.
4.7.12 The Soil Management Program Proposal shall include, at a minimum, all of the following:
(a) steps to be taken to control sources of contamination;
(b) remediation objectives for substances identified by soil monitoring as exceeding the applicable maximum standards in 4.7.6 or 4.7.7;
(c) proposed steps for management of soil contamination; and
(d) a schedule for implementing the Soil Management Program.
4.7.13 If the Soil Management Program Proposal is found deficient by the Director, the approval holder shall correct all the deficiencies as outlined by the Director by the date specified in the deficiency letter.
APPROVAL NO. 155-02-00 Page 28 of 31
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TERMS AND CONDITIONS ATTACHED TO APPROVAL 4.7.14 The approval holder shall implement the Soil Management Program as authorized in
writing by the Director.
4.7.15 If the approval holder must implement a Soil Management Program pursuant to 4.7.14, the approval holder shall submit a written Soil Management Program Report to the Director on or before March 31 of each year, unless otherwise authorized in writing by the Director.
4.7.16 The Soil Management Program report shall include, at a minimum, all of the following information:
(a) a summary of actions taken under the Soil Management Program during the previous year;
(b) a description and interpretation of results obtained, including any soil testing, from the Soil Management Program; and
(c) events planned for the current year including any deviations from the program authorized in writing by the Director.
PART 5: RECLAMATION
SECTION 5.1: GENERAL
5.1.1 The approval holder shall apply for an amendment to this approval to reclaim the plant by submitting a Decommissioning and Land Reclamation Plan to the Director.
5.1.2 The Decommissioning and Land Reclamation Plan referred to in 5.1.1 shall be submitted within six months of the plant ceasing operation, except for repairs and maintenance, unless otherwise authorized in writing by the Director.
5.1.3 The approval holder shall implement the Decommissioning and Land Reclamation Plan as authorized by the Director.
APPROVAL NO. 155-02-00 Page 29 of 31
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TERMS AND CONDITIONS ATTACHED TO APPROVAL SECTION 5.2: DECOMMISSIONING
5.2.1 The approval holder shall develop and submit a plan for the Decommissioning phase to the Director which shall include, at a minimum, all of the following:
(a) a plan for dismantling the plant;
(b) a comprehensive study to determine the nature, degree and extent of contamination at the plant and affected lands;
(c) a plan to manage all wastes produced at the plant during operation and decommissioning;
(d) evaluation of remediation technologies proposed to be used at the plant and affected lands;
(e) a plan for decontamination of the plant and affected lands in accordance with the following:
(i) for petroleum hydrocarbons, Alberta Soil and Water Quality Guidelines for Hydrocarbons at Upstream Oil and Gas Facilities, Alberta Environment, 2001, as amended;
(ii) for salt, Salt Contamination Assessment and Remediation Guidelines, Alberta Environment, 2001, as amended;
(iii) for substances not included in 6.2.1 (e) (i) or 6.2.1 (e) (ii), Canadian Environmental Quality Guidelines, Canadian Council of Ministers of the Environment, PN1299, 1999, as amended, excluding values determined before 1997;
(iv) for substances not found in 6.2.1 (e) (i) to 6.2.1 (e) (iii), for soil which will be remediated to an agricultural, residential, or parkland land use, Alberta Tier I Criteria for Contaminated Soil Assessment and Remediation, Alberta Environmental Protection, March 1994, as amended;
(v) for substances not found in 6.2.1 (e) (i) to 6.2.1 (e) (iii), for soil which will be remediated to a commercial or industrial land use, the Interim Canadian Environmental Quality Criteria for Contaminated Sites, Canadian Council of Ministers of the Environment, EPC-CS34, September 1991, as amended;
(vi) for water, Canadian Water Quality Guidelines, CCREM, 1987, as amended; and
APPROVAL NO. 155-02-00 Page 30 of 31
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TERMS AND CONDITIONS ATTACHED TO APPROVAL
(vii) for soil or water, to contaminant levels in accordance with a risk assessment procedure accepted by the Director;
(f) confirmatory testing to indicate compliance with the remediation objectives; and
(g) a plan for maintaining and operating contaminant monitoring systems.
5.2.2 The approval holder shall implement the Decommissioning plan as authorized in writing by the Director.
5.2.3 All analytical protocols shall be in accordance with the Guidance Manual on Sampling, Analysis and Data Management for Contaminated Sites - Volume 1: Main Report, CCME EPC-NCS62E.
5.2.4 The approval holder shall submit an Annual Report to the Director by December 30 of each year until decommissioning is complete which shall include, at a minimum, all of the following:
(a) summary of decommissioning activities conducted during the reporting period;
(b) status of decommissioning;
(c) decommissioning activities planned for the following reporting period;
(d) summary and interpretation of monitoring data collected for the reporting period; and
(e) interpretation of monitoring data collected historically.
SECTION 5.3: LAND RECLAMATION
5.3.1 The approval holder shall develop and submit a plan for the Land Reclamation phase to the Director which shall include, at a minimum, all of the following:
(a) the final use of the reclaimed area and how equivalent land capability will be achieved;
(b) removal of infrastructure;
(c) restoration of drainage;
(d) soil replacement;
(e) erosion control;
APPROVAL NO. 155-02-00 Page 31 of 31
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TERMS AND CONDITIONS ATTACHED TO APPROVAL
(f) revegetation and conditioning of the plant including:
(i) species list, seed source and quality, seeding rates and methods;
(ii) fertilization rates and methods;
(iii) wildlife habitat plans where applicable; and
(g) reclamation sequence and schedule.
5.3.2 The approval holder shall implement the Land Reclamation plan as authorized in writing by the Director.
DATED October 31, 2005 DESIGNATED DIRECTOR UNDER THE ACT ALAN PENTNEY
AMENDING APPROVAL
PROVINCE OF ALBERTA
ENVIRONMENTAL PROTECTION AND ENHANCEMENT ACTR.S.A. 2000, c.E-12, as amended.
155-02-01APPROVAL NO.
014-155APPLICATION NO.
September 17, 2007EFFECTIVE DATE:.
September 30, 2015EXPIRY DATE:
Nexen Inc.APPROVAL HOLDER
Pursuant to Division 2, of Part 2, of the Environmental Protection and Enhancement Act,R.S.A.2000, c.E-12, as amended, the approval for the following activity:
Balzac sour gas processing plant for the processing of natural gas and the Balzac sulphurprocessing plant.
is amended as per the attached terms and conditions.
Kevin WilkinsonDesignated Director under the Act
Kevin Wilkinson
September 17, 2007Date Signed
APPROVAL NO.155-02-01
……………………….
TERMS AND CONDITIONS ATTACHED TO APPROVAL
Environmental Protection and Enhancement Act Approval No. 155-02-00 is hereby amended asfollows:
1. The following is added after SECTION 4.1.2(s):
(t) the diesel emergency generator exhaust stack.
DATED September 17, 2007 Kevin Wilkinson DESIGNATED DIRECTOR UNDER THE ACT
AMENDING APPROVAL
PROVINCE OF ALBERTA
ENVIRONMENTAL PROTECTION AND ENHANCEMENT ACTR.S.A. 2000, c.E-12, as amended.
155-02-02APPROVAL NO.
015-155APPLICATION NO.
February 29, 2008EFFECTIVE DATE:.
September 30, 2015EXPIRY DATE:
Nexen Inc.APPROVAL HOLDER
Pursuant to Division 2, of Part 2, of the Environmental Protection and Enhancement Act,R.S.A.2000, c.E-12, as amended, the approval for the following activity:
Balzac sour gas processing plant for the processing of natural gas and the Balzac sulphurprocessing plant.
is amended as per the attached terms and conditions.
Kevin WilkinsonDesignated Director under the Act
February 29, 2008Date Signed
APPROVAL NO.155-02-02……………………
….
TERMS AND CONDITIONS ATTACHED TO APPROVAL
Environmental Protection and Enhancement Act Approval No. 155-02-00 is hereby amended asfollows:
1. The following is added after SECTION 4.1.14:
4.1.14 (a) notwithstanding Table 4.1-C, for the period between March 17 to 21, 2008, or asotherwise authorized in writing by the Director, the temperature of the effluentstream released to the atmosphere shall not be less than the one-hour averageof 300 degrees celsius.
DATED February 29, 2008 Kevin Wilkinson DESIGNATED DIRECTOR UNDER THE ACT
33
APPENDIX II – PUBLIC CONSULTATION FACT SHEET
Social ResponsibilityHSE&SR Management System
Public ComplaintsPublic Complaints
Identifying and addressing “Public Complaints”
What is a public complaint?
Guiding Principle & Standard:At Nexen, we conduct our business with respect and care for people. From time to time, we receive complaints from our stakeholders and the general public. Our standard is to track, document and respond to any complaint, question, or query within five working days of its receipt.
At Nexen, we separate complaints into two basic categories; 'Reportable' and 'Non-Reportable'.
Reportable Complaint: A direct expression of concern made by a stakeholder or member of the public that relates to a topic or event associated with Nexen's operations and results in the business unit taking action to correct the problem or concern. In some instances, reportable events are also required to be reported to a regulator.
Non-Reportable Complaint or Comment:A direct or indirect expression of concern, an observation, or viewpoint
of an industry related activity(s) near Nexen's operations that may or may not result in a formal reply or further action by Nexen.
All public complaints are entered into the Lotus Notes LEHS database by the field staff member that received the complaint or by a designate within the regional office. Information to be provided in an LEHS entry must include:
date and time of event, hlocation and/or nearest facility, and hdetails of the complaint. h
Where applicable, the regional social responsibility lead/representative will then add this information including contact information into Nexen's Stakeholder database (Praxis).
The area operations superintendent or supervisor initiates the investigation with the local HSE&SR practitioner providing support and technical guidance as required.
How does Nexen track public complaints?
Who investigates public complaints?
What are examples of public complaints?
A landowner smells something (a hpetroleum odour) on their property and calls Nexen to report the concern,A local fisherman writes a letter to hNexen to express concerns that offshore activity is affecting fishing in the area,A resident calls upset about finding hsediment in their well water and believes it is from a nearby Nexen drilling operation,A farmer informs a contractor on a hNexen lease that they believe their horse (livestock) was injured during recent drilling or mobilization activity,A Nexen field office receives a hnoise complaint from a local landowner where drilling activities are currently underway,A concerned citizen contacts the hlocal authority about Nexen activities in an area that they consider environmentally sensitive, the authority contacts Nexen to seek clarity of the issue.
Element 4 of the HSE&SR Management System:
4.3.1 Ongoing Community EngagementAll divisions will establish and maintain ongoing community engagement programs to support Nexen's long-term social license to operate.
This engagement will typically include: involving the community in decision-making processes for operational hchanges, expansions or abandonment activities that may affect them; taking proactive measures to ensure communities are aware of hongoing Nexen activities; providing a vehicle for members of the public to express questions, hconcerns and complaints regarding our operations.
All divisions will record notable public complaints, comments and inquiries in the Nexen LEHS database, respond to them in a timely manner, and document the response.
July 2011 S13735
Version Dec 8, 2011
Balzac A&R Team
Public Concern 12 Step Response Procedure
1. Call Centre directs Public Concern from a citizen or interested party to the On Call Responder.
2. On Call Responder will complete a Public Concern form while in conversation with caller (see attached).
3. On Call Responder will verify with caller if, after investigation a call back is required.
4. On Call Responder investigates the concern and if required, takes necessary action.
5. On Call Responder will document on the Public Concern form actions taken.
6. If required, the On Call Responder will follow up with the original caller advising them of our findings and or action taken.
7. On Call Responder will classify the concern as “reportable” or “non-reportable”. All reportable concerns require an email notification to the appropriate contacts identified on the Public Concern form.
8. The On Call Responder will enter the Public Concern into the Lotus Notes LEHS database, and attach the Public Concern form to the event in the attachments section. Once attached the document must be retained in a secure environment or shredded.
9. A&R Team Lead will conduct a review of the LEHS event report within 5 days for accuracy and technical content. If necessary, the A&R Team Lead will correct and/or add action items and discuss revisions with On Call Responder.
10. A&R HSE Advisor(s) will conduct a review of the LEHS event report within 10 days for accuracy and technical content from an HSE perspective. If necessary, the A&R HSE Advisor(s) will correct and/or add action items and discuss revisions with A&R Team Lead.
11. A&R Managers (Plant or Field) will conduct a review and/or amend the LEHS event within 15 days and if there are no outstanding issues and all actions items are closed move event to “Final”.
12. On receipt of event in Lotus Notes the Social Responsibility Lead will enter information into stakeholder database (Praxis) at their discretion.
Balzac A&R
Last Edit Dec 8, 2011
PUBLIC CONCERN FORM CALL INFORMATION
DATE and TIME: INFORMATION RECORDED BY: NAME: PHONE NUMBER: LOCATION: CONCERNS:
Follow-up call requested? Yes No ODOUR COMPLAINT: YES NO If Yes, complete section below. Can you describe the direction the odour is coming from: NW NE SW SE When did the odour first appear? How long did the odour last? Is the odour still occurring? Yes No
Can you please describe the smell: Faint Moderate Strong Very Strong
INVESTIGATION SECTION Comments from Nexen Representative after Investigation: Nexen Sites Checked for Odour:
Is this event : Reportable Non- Reportable
FOLLOW UP SECTION Follow-up Call Completed by (Name): Follow up Call Details Time: Same day or Date:
Additional Comments: Attach separately as 2nd Page If this is a REPORTABLE PUBLIC CONCERN issue an email notification to:
FIELD MANAGER PLANT MANAGER A&R TEAM LEAD A&R HSE ADVISOR(s) SOCIAL RESPONSIBILITY COORDINATOR
Entered into Lotus Notes: Yes No Date Entered: Attached Concern form to Event: Yes No LEHS #:
34
APPENDIX III – DECOMMISSIONING, REMEDIATION AND LAND
RECLAMATION PLAN
BALZAC GAS PLANT
DECOMMISSIONING
REMEDIATION
&
LAND RECLAMATION
PLAN
SUBMITTED BY:
NEXEN INC.
801 – 7th
Avenue S.W.
Calgary, Ab
T2P 3P7
March 5, 2012
BALZAC GAS PLANT
DECOMMISSIONING, REMEDIATION & LAND RECLAMATION PLAN 2012
1
Table of Contents INTRODUCTION .............................................................................................................. 5
1. Shutdown, Decommissioning and Salvage ................................................................. 6
2. Dismantling and Demolition of Facility ..................................................................... 9
a. Hazardous Materials Removal ............................................................................... 10
b. Demolition of Equipment, Vessels, Tanks and Piping .......................................... 10
c. Demolition of Buildings and Structures ................................................................ 11
d. Processing of Demolition Recyclables .................................................................. 11
e. Transportation of Materials .................................................................................... 12
f. Site Cleanup ........................................................................................................... 12
g. Noise Control ......................................................................................................... 12
h. Dust Control ........................................................................................................... 12
3. REMEDIATION AND RECLAMATION PLAN .................................................... 13
3.1 Remediation Action Plan (“RAP”) .................................................................... 13
3.2 Reclamation Plan ................................................................................................ 13
4. FACILITY BACKGROUND ................................................................................... 14
5. REGULATORY CRITERIA .................................................................................... 15
6. SITE CHARACTERISTICS AS DETERMINED FROM PAST ASSESSMENTS
ON THE BGP ................................................................................................................... 16
6.1 Regional Characteristics ..................................................................................... 16
6.2 Geology .............................................................................................................. 16
6.3 Soils .................................................................................................................... 17
6.4 Hydrogeology ..................................................................................................... 18
6.4.1 Regional Hydrogeology .............................................................................. 18
6.4.2 Present Groundwater Use ........................................................................... 18
6.4.3 Local Groundwater Conditions ................................................................... 19
6.5 Industrial and Surface Water .............................................................................. 20
6.5.1 Catchment Areas – Balzac Gas Plant .......................................................... 21
6.5.2 Catchment Areas – Surrounding Lands ...................................................... 25
6.6 Surrounding Land Use ....................................................................................... 27
7 REMEDIAL CHARACTERIZATION .................................................................... 30
7.1 Previous Investigations and Remedial Programs ............................................... 30
8 CURRENT STATE OF PROPERTY ....................................................................... 69
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8.1 Primary Sources of Contamination .................................................................... 71
8.2 Summary of COPCs ........................................................................................... 73
8.3 Soil Conditions ................................................................................................... 76
8.3.1 Contaminants of Potential Concern in Soil ................................................. 77
8.4 Groundwater Conditions .................................................................................... 81
8.4.1 COPCs in Groundwater .............................................................................. 81
8.5 Surface Water Conditions .................................................................................. 85
8.5.1 McDonald Lake .......................................................................................... 87
8.6 Secondary Sources of Contamination ................................................................ 88
8.6.1 Free Phase Hydrocarbon Liquids ................................................................ 88
8.7 Data Gaps ........................................................................................................... 89
8.7.1 Background Data ........................................................................................ 89
8.7.2 Bedrock Flow Mechanism .......................................................................... 89
8.7.3 Geographical and Temporal Data Coverage ............................................... 89
8.7.4 Survey Data ................................................................................................. 92
8.7.5 McDonald Lake .......................................................................................... 92
9 REMEDIAL OPTIONS ............................................................................................ 92
9.1 Determination of End Land Use & Remediation Criteria .................................. 93
10 REMEDIATION PLAN ........................................................................................... 95
10.1 General ............................................................................................................ 95
10.2 Sulphur Handling Facility .............................................................................. 97
10.3 McDonald Lake .............................................................................................. 97
10.4 Noise Management ......................................................................................... 97
10.5 Industrial Runoff Management ....................................................................... 97
10.6 Monitoring Programs ...................................................................................... 98
11 RECLAMATION PLAN .......................................................................................... 99
12 HEALTH & SAFETY PROGRAM .......................................................................... 99
13 COMPLAINT RESPONSE .................................................................................... 100
14 REPORTING .......................................................................................................... 101
Appendix I –Slater Demolition Plan ............................................................................... 102
Appendix II – Waste Management Plan ......................................................................... 103
Appendix III – List of Environmental Reporting Completed for the BGP ..................... 104
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TABLES
Table 1. AEPEA Approvals Applicable to BGP ............................................................... 5
Table 2. Equipment Changes on BGP – 2006* ................................................................. 6 Table 3. Equipment Changes on BGP – 2009 ................................................................... 7 Table 4. Summary of catchment area sizes, current land use, and confirmation of Plant
runoff contribution. ........................................................................................................... 23 Table 5. Previous Environmental Investigations by Liability Sub-Unit and Year. ......... 67
Table 6. Liability Sub-Units (“LSU”) .............................................................................. 69 Table 7. Summary of Potential Environmental Issues ..................................................... 71
Table 8. Summary of COPCs in Soil & Groundwater ..................................................... 74 Table 9. COPCs in Soils .................................................................................................. 79
Table 10. Summary of COPCs in Soils ........................................................................... 80 Table 11. Detailed Summary of COPCs in Groundwater by LSU .................................. 82 Table 12. COPCs in Groundwater by LSU ...................................................................... 84
Table 13. COPC in Surface Water Bodies ....................................................................... 86
FIGURES
Figure 1. Catchment Areas within the BGP ..................................................................... 24
Figure 2. Catchment Areas Surrounding BGP ................................................................. 26 Figure 3. Balzac East Area Zoning Map .......................................................................... 29 Figure 4. Complete or Assessed Programs ...................................................................... 68
Figure 5. Liability Sub-Units ........................................................................................... 70 Figure 6. COPC by LSU .................................................................................................. 75 Figure 7. Existing Infrastructure Expected to Remain ..................................................... 94
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ABBREVIATIONS
ACM Asbestos Containing Material AENV Alberta Environment
AEPEA Alberta Environmental Protection and Enhancement Act
AO Aesthetic Objective
BEASP Balzac East Area Structure Plan
BGP Balzac Gas Plant
BPS Balzac Power Station
CAPP Canadian Association of Petroleum Producers
CCME Canadian Councils of Minister of the Environment
COPC Contaminants of Potential Concern
CPW Cathodic Protection Wells
DEA Diethanolamine
DLR Decommissioning, Remediation and Land Reclamation Plan
DRR Demolition, Remediation and Reclamation
ERCB Energy Resources Conservation Board
ERP Emergency Response Plan
GCDWQ Guidelines for Canadian Drinking Water Quality
KVSR KVSR is a brand name compressor LBP Lead Based Paint
LNAPL Light Non-Aqueous Phase Liquid LPG Liquified Petroleum Gas
LSU Liability Sub-Unit
MAC Maximum Acceptable Concentration
MBGS Metres Below Ground Surface
PAH Poly Aromatic Hydrocarbons
PCB Polychlorinated Biphenyl RAP Remedial Action Plan
SDS Shutdown, Decommissioning and Salvage
SMP Soil Monitoring Program
SSLA Site Specific Liability Assessment
SSRA Site Specific Risk Assessment
TDS Total Dissolved Solids
UST Underground Storage Tank
VOC Volatile Organic Compounds
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INTRODUCTION The Balzac Sour Gas Processing Plant (for the processing of natural gas) and the Balzac Sulphur
Processing Plant (herein referred to as the Balzac Gas Plant) are operated by Nexen Inc.
(“Nexen”) of Calgary, Alberta, pursuant to approval No. 6457, issued by the Energy and Utilities
Board (hereafter referred to as the Energy Resources Conservation Board (“ERCB”) and Alberta
Environment (“AENV”) approvals (listed below).
The Balzac Gas Plant (“BGP”) ceased operations permanently on April 28th, 2011 (“Plant
Closure”). Therefore, Nexen is submitting this amendment application for approval to
decommission, dismantle, remediate and reclaim the Balzac Gas Plant (“BGP”).
As part of the overall retirement program, the following undertakings will be completed:
1. Shutdown, Decommissioning and Salvage – All production processes at the BGP are
ceased, equipment on-site is purged of fluids and gas, equipment is inspected and made
safe for eventual demolition equipment is tagged as such, and equipment that can be sold,
reused, or recycled is handled and removed as required or approved;
2. Dismantling and Demolition – asbestos abatement activities are completed then all
equipment is taken apart and taken down for disposal at an approved facility (i.e. landfill,
recycler);
3. Remediation (Management plan is implemented to determine which lands have been, or
require assessment for potential contaminants, and processes are implemented to safely
excavate, remove and dispose of contaminated materials) and Reclamation Plan (site is
restored to an equivalent land capability appropriate with a yet to be determined end land
use).
These undertakings are extremely complex, technical and detailed in scope and execution
requirements. Many processes that form the basis for the undertakings noted above require
specific management, tracking, and outcomes that are too detailed or outside the scope of this
document. These undertakings will therefore be completed in accordance with the general
outline provided in this Decommissioning and Land Reclamation Plan, or updated versions
thereof.
This Plan will be submitted to Alberta Environment in accordance with the following approvals:
Table 1. AEPEA Approvals Applicable to BGP
Approval Number Application Number Effective Date Expiry Date of
Original Approval
155-02-00 008-155 October 31, 2005 September 30, 2015
155-02-01 014-155 September 17, 2007 September 30, 2015
155-02-02 015-155 February 29, 2008 September 30, 2015
155-02-03 017-155 July 23, 2010 September 30, 2015
155-02-04 016-155 January 14, 2011 September 30, 2015
155-02-05 Not Provided March 9, 2011 September 30, 2015
155-02-06 019-155 July 28, 2011 September 30, 2015
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1. Shutdown, Decommissioning and Salvage
The following summarizes previously reported Decommissioning activities:
2006
Nexen upgraded the sulphur handling facilities at the Balzac Gas Plant. The sulphur slaters which
have operated since the1970's were taken out of service in April 2006 and the new sulphur
handling facilities (GX Units) were put into full scale operation. During 2006, some of the
sulphur slating facilities were decommissioned and removed. See the equipment list in Table 2
below for the status of the slater decommissioning and removal.
Table 2. Equipment Changes on BGP – 2006*
DESCRIPTION QUANTITY NOTES* SCHEDULE
SLATER BELTS 6 Item # 4 3rd Quarter 2006 - Removed
SLATER FRAMES 6 Item # 4 3rd Quarter 2006 - Removed
SLATER MOTORS 6 Item # 4 3rd Quarter 2006 - Removed
SLATER FANS 24 Item # 4 3rd Quarter 2006 - Removed
SLATER DRIVES 6 Item # 4 3rd Quarter 2006 - Removed
SLATER BUILDING 1 Item # 5 3rd Quarter 2006 - Removed
ELECTRICAL WIRING LOT 3rd Quarter 2006 - Removed
ELECTRICAL STARTERS 7 3rd Quarter 2006 - Removed
WATER COOLER 1 Item # 9 3rd Quarter 2006 - Removed
COLLECTOR CONVEYOR 1 Item # 13 3rd Quarter 2006 - Removed
*The information provided in this table (specifically the Notes column) refers to the demolition map provided in
Appendix I of this document.
2007
Nexen started removing the sulphur contaminated soil pile which was located on the Plant site
south of the current west sulphur basepad. during October 2007 in two phases. Phase I of the
project started on October 31, 2007 and finished November 23, 2007.Approximately 27,396
metric tonnes of sulphur contaminated soil was removed from the plant site and hauled to an
approved landfill in Phase 1 of this project. Phase 2 of this project was completed in 2008.
2008
Nexen started removing the sulphur contaminated soil pile (Phase 2) and sulphur impacted
underlying soils which were located on the Plant site (south of current west sulphur basepad)
during the first quarter of 2008. Approximately 58,234 metric tonnes of sulphur contaminated soil
was removed from the plant site and hauled to an approved landfill. (Phase 2)
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Nexen removed sulphur contaminated material (Topsoil Stockpile) which was located adjacent to
the Enersul Sulphur Storage Pile in 2008. Approximately 15,086 metric tonnes of sulphur
contaminated soil was removed from this area in 2008 and disposed of at an approved landfill.
Nexen also removed 3,093 metric tonnes of hydrocarbon contaminated soil from the Unknown
Sump which was located adjacent to the Plant Flare Area in 2008. This contaminated material
was removed from this area in 2008 and disposed of at an approved landfill.
2009
Nexen removed the sulphur contaminated material which was located on the site of the removed
Enersul Slating Area in 2009. Approximately 29,138 metric tonnes of sulphur contaminated soil
was removed from the Enersul Slater Area in 2009 and disposed of at a landfill.
Delays were encountered as the result of finding subsurface asbestos contaminated material
which necessitated halting further work to develop a detailed safety and environmental plan
before going ahead with this part of the project. Nexen has decided to include this project in the
overall plant wide hazard assessment. Enersul sump area (located adjacent to the sulphur storage
pad) construction was also delayed due to a change in design plans for sump. As the area is now
shutdown this too will be included in the overall plant wide hazard assessment.
Table 3 summarizes the equipment removed or changed in 2009.
Table 3. Equipment Changes on BGP – 2009
DESCRIPTION QUANTITY NOTES SCHEDULE
WATER TANK 1 Item # 11 3rd Quarter 2009 - Removed
WATER PUMP 2 Item #10 3rd Quarter 2009 - Removed
WATER PUMP BUILDING 1 Item # 10 3rd Quarter 2009 - Removed
SHOP 1 Item # 6 3rd Quarter 2009 - Removed
SEPTIC TANK 1 Item # 7 3rd Quarter 2009 - Removed
FUELS & OIL STORAGE 1 Item # 8 3rd Quarter 2009 - Removed
SITE OFFICE &
CHANGEROOMS 1 Item#12
3rd Quarter 2009 - Removed
STORAGE BLDG. 1 Item # 35 3rd Quarter 2009 - Removed
2010
Nexen planned and executed the removal of the West Cooling Tower in 2010. A pre-demolition
sampling and testing program was conducted on materials slated for demolition and removal.
The following pieces of equipment were removed:
1. West Cooling Water Tower - 3 Banks were removed complete with piping, trays inside the
tower and fans and motors were all demolished and disposed of. The basin/sump was left
intact.
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2. West Cooling Water Deluge Building and all piping attached to the building was demolished
and disposed of.
3. West Cooling Tower Sand Filter (Tank) and associated piping, sand, etc. was removed and
disposed of. The foundation was left intact.
2011
As part of the overall retirement program, shutdown, decommissioning and salvage (SDS)
activities have already been initiated to shut down and clean the plant. The Plant was in the SDS
phase of the Project from June to December of 2011. The Plant has been prepared, cleaned and
its various systems de‐energized. Items available for immediate disposition and salvage have
been identified, and the Plant was turned over to the Demolition, Remediation and Reclamation
project (“DRR”) as of December 15, 2011, which will demolish the facilities, remediate the soil
and ultimately reclaim the site. Prior to demolition, outstanding hazards will addressed including
the large scale abatement project for 2012.
Disposition of select pieces of equipment is occurring as per Nexen’s submission to AENV on
April 6, 2011, entitled “Licence Amendment Application – Asset Disposition & Select Monitoring
and Reporting Changes” and subsequent submissions and as per Amendment Approval # 155-02-
06. In order to maximize asset value, offset future demolition/disposal costs and reduce the
amount of waste sent to landfills, a condensed list of assets deemed to be in good condition was
offered to interested parties for transfer or sale.
Where an asset does not sell for reuse, an attempt will be made to recycle the asset by selling it
for scrap. If the scrap value cannot be realized for an asset, it will be sent to an approved landfill.
The priority for asset disposition is:
Transfer/sell for reuse;
Sell for scrap / recycle;
Donate;
Landfill (this categorization will only be made after reasonable investigations
into options for recycling traditional waste streams. Nexen will investigate these
options as waste streams are further identified.
A preliminary list of BGP assets has been developed. This list will become a master asset list of
all BGP assets: major equipment, spare parts, instrumentation, electrical equipment, furniture, etc.
Sub-lists will be generated from this master list and distributed to partners, potential buyers,
regulators and others as required. Scrap and waste disposals will also be recorded in the database,
although waste streams will be tracked in the overall Waste Tracking database as well.
Any equipment leaving the site (working component, scrap or waste) will be documented and
appropriate updates will be made to internal tracking systems and the Alberta Boilers Safety
Association (“ABSA”) (where applicable).
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The SDS project has dismantled and demolished only to the extent required by the work of
shutdown and decommissioning as well as the pursuit of any salvage opportunities that arose
while the SDS project was ongoing. Apart from wastes which were produced by the SDS
execution and other wastes which must be disposed of to make the Plant safe for dismantling and
demolition, most salvage and waste activities will be executed by the DRR project.
Waste management will be protective of human health and the environment by controlling and
minimizing exposure to hazardous materials. The intent is to minimize the volume of waste
delivered to registered disposal facilities by minimizing waste generation and maximizing the re-
use and recycling of material.
Groundwater wells that are not of potential interest to future monitoring or study will be
decommissioned. Prior to decommissioning any wells, Nexen will obtain agreement to do so from
AENV. Monitoring wells that are a key part of the Site’s monitoring program will be replaced if
there is a need for their decommissioning during remediation or construction.
2. Dismantling and Demolition of Facility
The demolition of the Balzac gas plant is tentatively planned for execution in 2013. The
objective will be to bring the plant site down to grade by demolishing all structures
elevated above the level of the building slab. This would include any raised perimeter
grade beams or pedestals for columns / equipment that are located outside or inside the
buildings. All resulting debris and recyclable materials will be removed from the site as
it is accumulated.
A SDS Health Safety & Environment (HSE) plan is developed based on the Nexen Inc.
(Nexen) Canadian Oil and Gas, the BGP HSE Management Systems (SMS), as well as
applicable regulations and they will be adhered to as the minimum requirement. In
addition, contractors task specific procedures will also be utilized providing they meet or
exceed Nexen’s expectations. Any concerns or questions regarding the expectations
referenced in this plan shall be brought forward to a Nexen supervisor and/or the site
Safety and Environmental Advisors for resolution.
All Nexen management, supervisory and contractor staff will be expected to be familiar
with this plan. Nexen is the Prime Contractor for the SDS Project. Any non-compliance
to the requirements identified in this HSE plan may result in corrective action up to and
including dismissal.
All applicable government rules, regulations or restrictions, Federal or Provincial or
local, in effect must be met or exceeded.
Activities that will be conducted on site include:
removal of any remaining hazardous materials
demolition of applicable equipment, tanks, vessels and piping
demolition of applicable buildings and structures
processing of demolition recycling and debris
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transportation and offsite disposal of recyclables and demolition debris to
approved waste sites
final site cleanup
a. Hazardous Materials Removal
All remaining hazardous materials that were identified in a comprehensive site survey
will be abated prior to building demolition. These hazardous materials may include but
are not limited to:
Domestic-type wastes (non-hazardous, "garbage")
Salvage metals, i.e. Iron, Copper, Tin, Steel
Construction waste (general building materials, e.g. concrete, plaster, wood, etc.)
Glass and ceramics
Asbestos-containing or contaminated materials (insulations, building materials,
abatement waste materials) (ACM)
Asbestos-contaminated water (filtered)
Synthetic (non-asbestos) insulating materials
Lead-acid batteries
Mercury, liquid in instrumentation
Mercury lamp bulbs and tubs
PCB Transformer oil (potential)
PCB-containing lamp ballasts (potential)
Ozone-depleting refrigerants (HVAC units)
Other Dangerous Oilfield Wastes ("DOW"), e.g. residual chemicals or
contaminated materials as identified during demolition
Lead Based Paint (LBP)
Oil / Liquid containing devices
Bird and Rodent Excrement
Handling, transportation and disposal of regulated equipment, building accessories and
generated wastes shall be in accordance with applicable laws and regulation. All wastes
will be accurately recorded and tracked as per current site procedures.
b. Demolition of Equipment, Vessels, Tanks and Piping
All equipment, vessels, tanks and piping not identified as remaining on site will be
demolished / removed and segregated. Equipment, materials and methods for demolition
will be provided by the site demolition contractor and verified by Nexen prior to
executing the work. It will be ensured that any adjacent structures (i.e. buildings,
pipelines, etc.) that are not scheduled for demolition will be adequately protected.
Removal of residual liquids / materials, decontamination and removal of all items shall be
performed in a way that prevents uncontrolled discharge of fluids and maximizes material
/ liquid recovery.
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Nexen will ensure that all Alberta Boiler Safety Association (ABSA) disposition
guidelines are followed for any registered pressure vessels.
c. Demolition of Buildings and Structures
All buildings and structures that have not been identified as remaining on site will be
demolished / removed and segregated. The at-grade portion of the building
foundations will stay in place while all other above grade concrete foundation
components will be removed. All Building Foundations and/or Concrete Pads Used
to Support Equipment: During the salvage component of the SDS phase, equipment
was/is being removed for sale. Some of that equipment was/is situated on concrete
support pads. During the DRR phase of the project, remaining pieces of equipment,
facilities, buildings, piping, etc… will be demolished and removed. Following the
demolition and removal of equipment, if warranted Nexen will leave all foundations
and concrete pads in place until the remediation phase of the project begins. If
concrete at surface is in the way of equipment removal then activities may be
undertaken to remove surface concrete for access purposes only. Subsurface concrete
associated with these specific projects would then be removed at a later date. Both
the Dismantling and Remediation processes require separate and unique management
techniques, which are easier to manage separately. Therefore, the intent is NOT to
leave foundations and pads in long term but to accomplish two things:
i. Avoid creation of open holes, pits or excavations that would then become
workplace hazards to personnel completing demolition components. Nexen has
completed a risk analysis and hazard assessment of the removal of the
foundations or concrete pads. It was determined that in order to reduce safety
hazards on the project site, minimizing disturbed ground or open excavations is
desirable; and,
ii. Avoid disturbance of underlying soils and materials that may have been
potentially affected by contamination. This will allow Nexen to fully determine
appropriate remediation processes at these numerous locations prior to
disturbance of the foundations and pads. This will allow Nexen to implement
appropriate management, safety and remediation protocols at that time.
Equipment, materials and methods for demolition will be provided by the site demolition
contractor and verified by Nexen prior to executing the work. It will be ensured that any
adjacent structures (i.e. buildings, pipelines, etc.) that are not scheduled for demolition
will be adequately protected.
d. Processing of Demolition Recyclables
Processing of steel and other materials will occur on site to make them suitable for
transport to scrap or material recycling facilities. Processed materials will be transported
off-site on a regular basis to avoid large accumulations.
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e. Transportation of Materials
All demolition wastes, both hazardous and non-hazardous, and recyclables will be
transported in accordance to all applicable laws and regulations. This includes, but is not
limited to, The Transportation of Dangerous Goods Act and any local road use
agreements and restrictions. Furthermore, Nexen will manage transportation and waste
management as per the Waste Management Plan provided in Appendix II.
f. Site Cleanup
At the completion of demolition, the site will be free of all demolition materials,
equipment and temporary facilities. Building foundations that are left in place with
trenches, sumps and pits will be backfilled to slab-on-grade or equivalent at Nexen’s
discretion. The site will be graded to ensure that adequate surface drainage is in place.
g. Noise Control
Nexen will follow existing regulations for noise control to reduce effects of noise on
nearby residents and workers. Nexen will comply with the requirements of:
Municipal District of Rockyview No. 44 Bylaw No. C-5772-2003 (aka “Noise
Control Bylaw”);
Occupational Health and Safety Act, Occupational Health and Safety Code 2009.
Approved (recommended CSA Class A or CSA Grade 4) hearing protection
devices must be worn at all times where noise levels exceed 85 DBA. These
areas will usually be marked with signage stating that hearing protection is
required;
Environmental Noise impacts shall be minimized as much as possible.
Reasonable mitigation measures will be taken to reduce noise impacts on the
public, domestic animals or wildlife during operation activities that might cause
adverse noise impacts.
h. Dust Control
When workers are or may be exposed to airborne contaminants or a mixture of airborne
contaminants in concentrations exceeding the occupational exposure limits defined in
OHS regulations for specific province of work, to atmospheres with an oxygen
concentration of less than 19.5% by volume, and/or to other airborne contaminants such
as dusts, hazardous and noxious fumes, rodent infested work areas, etc., the appropriate
respiratory protective equipment must be worn.
Nexen will implement appropriate dust suppression measures on roads, work areas, or
transportation and loading routes as on BGP roads. Further dust control MAY be
required on the existing county road located on the east boundary of the BGP, from the
BGP to Highway ?, located north of the BGP. The decision to control dust will be made
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at the field level and will depend upon site conditions, level of activity, and worker health
and safety.
3. REMEDIATION AND RECLAMATION PLAN This Decommissioning and Reclamation Plan describes general methodologies that will be
implemented to remediate and reclaim the Balzac Gas Plant. The scope of this plan is as follows:
3.1 Remediation Action Plan (“RAP”) The objective of the RAP will be to identify and appropriately manage and remediate
contaminants of concern at the BGP. The RAP is currently under development and includes:
Site Characterization and Background Characterization;
Summary of Previous Assessments and Site Characterizations;
Proposed Remediation Criteria; and,
Remediation Plan for soil, groundwater and sediment;
Management of surface water
The RAP consists of the following components:
1. Facility Background;
2. Regulatory Criteria;
3. Site Characterization;
4. Remedial Characterization;
5. Current State of Property;
6. Remedial Options;
7. Remediation Plan;
8. Health and Safety Program; and,
9. Complaint Resolution System.
Due to the extensive amount of information collected at the BGP since the 1960s, the complex
nature of the infrastructure, and a myriad of unknowns, in order to effectively determine the most
appropriate RAP, Nexen anticipates a 2-3 year timeframe for appropriate development.
Therefore the RAP will be submitted to AENV with the renewal application in 2015. The RAP
will be under constant review and may change prior to the initiation of on-site activities and/or
completion of the overall program at the BGP.
3.2 Reclamation Plan
Following successful remediation at the BGP, reclamation activities will be conducted to meet
regulatory requirements for end land use that may exist at that time and to ensure topsoil
management, drainage restoration, erosion control and re-vegetation are effective.
Each aspect will be discussed in the following sections.
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4. FACILITY BACKGROUND
The Balzac Gas Plant is located adjacent to the Calgary's city limits, in LSD 7-2-26-29 W4M.
Other nearby communities includes the towns of Balzac and Airdrie, Alberta.
The Balzac Gas Plant was a sour, natural gas processing plant that received gas streams from
surrounding well sites and produced specification sales gas with the recovery of propane, butane,
condensate, and sulphur. The operation used conventional gas processing units with inlet
separation, gas compression, amine sweetening (hydrogen sulphide (H2S) and carbon dioxide
(CO2) removal), refrigeration/dehydration, condensate stabilization, sulphur recovery, and LPG
fractionation.
Propane and butane were stored in horizontal pressure tanks in the tank farm and were loaded into
truck or rail car for delivery to markets. Condensate was stored in tankage and transferred to the
Pembina Pipeline system for delivery to refineries. Sales gas was sent to the Trans Canada
Transmission pipeline system, and liquid (molten) sulphur was processed into a sulphur
granulation product (prilled) and shipped by rail to Vancouver. Enersul operated and owned the
sulphur granulation facility. The sulphur granulation process was discontinued after May 2011.
Approximately eighty-one producing gas wells (“Balzac Field”) supplied the raw natural gas
mixture to the plant for processing. Most of the gas produced from the wells is considered "sour"
meaning naturally-occurring H2S is present. H2S content varies from well to well and from
different formations. Within the Balzac field, H2S in the produced sour gas varies from 0.6% to
42%.
In the Balzac Field, all Crossfield and Elkton pipelines have been shut in and purged with
Nitrogen. Basal Quartz pipelines were pigged with fuel gas. All Crossfield wells have been
blinded at the wellhead. Elkton wells and Basal Quartz wells have been shut-in as per ERCB
requirements.
The Plant has been shut down in a safe, controlled fashion, equipment and piping was
decontaminated and any sources of energy, such as steam and electricity, isolated and shut off as
required. The shutdown was managed by the Shutdown, Decommissioning and Salvage (“SDS”)
team comprised of a group of operations, maintenance, environmental and safety personnel from
the Plant, in addition to contractors familiar with the Plant and experienced to execute work in a
safe, efficient manner. Decommissioning activities to bring the Plant to a state of zero energy and
make it safe for demolition began May 31st and will continue for the remainder of the year.
Under Nexen’s current operating approval with Alberta Environment, Nexen is required to submit
a Decommissioning and Land Reclamation (“DLR”) amendment within six (6) months of closure
of the facility. Approval of the DLR amendment is expected in 2012.
The Balzac Power Station (BPS) is located near the northern extent of the BGP property, but
within the BGP boundaries, on the shores of McDonald Lake. The BPS operates under a separate
AEPEA Approval (Approval #: 136858-00-00). The power plant generates 105 MW of
electricity to meet power demands of southern Alberta, Calgary specifically. The plant consumes
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826 MMBtu (HHV)/h of natural gas and 3,000 m3/d of water. Approximately 100 to 300 m
3/d of
process wastewater is produced from plant operations. The Power Station consists of:
Two (2) GE LM-6000 PC E-Sprint gas turbines
Two (2) once-through steam generators (OTSG)
One (1) Dresser-Rand steam turbine
Steam and condensate distribution;
Cooling water system;
Glycol heating system;
Make-up water treatment system;
Boiler feed water polisher system; and
Instrument air system.
This power station will remain active during decommissioning of the Gas and Sulphur Plants and
remediation and reclamation of the larger property parcel. There is no current plan to
decommission this power station. There is also associated infrastructure (pipelines carrying gas
and water) running to and from the BPS that travel above grade across the larger property that
will remain in place after decommissioning of the Gas Plant. This infrastructure has been
considered during the development of this remedial plan.
5. REGULATORY CRITERIA
As discussed in subsequent sections, appropriate remediation criteria have been selected and are
protective of human health and ecological receptors. Through the use of generic remediation
criteria as may be deemed appropriate, and the use of site specific remedial guidelines and/or risk
assessment where possible, this RAP will be implemented in a manner that is protective of human
health and the environment, such that these lands will be returned to safe, and productive end land
use.
There are four options available to Nexen for remediation of the BGP. Each of these options is
discussed in greater detail in the Tier I and Tier II Soil and Groundwater Remediation Guidelines
(December 2010). These options include:
1. Remediation (insitu or exsitu) of soil, groundwater, surface water, and sediment to the
AENV Tier I guidelines (or the CCME environmental quality guideline for parameters
not included in the AENV guidelines).
2. Remediation (insitu or exsitu) of soil, groundwater, surface water, and sediment to AENV
Tier II site specific guidelines which would be developed for the BGP site for each
Contaminant of Concern (COC). Tier II site specific guidelines would be established
through pathway exclusion and/or parameter adjustment in consultation with AENV.
3. Completion of a Tier II Site Specific Risk Assessment (SSRA), possibly allowing for
soils, groundwater, surface water and/or sediment to remain in place. Remediation,
where necessary (insitu or exsitu), would be completed to the Tier II site specific
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guidelines. This option will almost always require a monitoring plan until stable end
points are demonstrated.
4. Exposure Control and Long Term Risk Management (Human Health) and Ecological
Risk Assessment (Ecological Health and McDonald Lake).
Options 1 to 3 allow for full regulatory closure under the Alberta Environment Environmental
Site Assessment Program (Record of Site Condition). Regulatory closure would allow Nexen to
divest of the property in the future. Option 4 does not allow for regulatory closure. It is fully
protective of human and ecological health, with a management plan/exposure control plan in
place. This option would allow Nexen to redevelop and/or lease the property in the future.
Risk assessment activities will ensure that no long term risk is present to the aquatic environment
from remediation activities and surface run off or groundwater inputs from the BGP.
6. SITE CHARACTERISTICS AS DETERMINED FROM PAST
ASSESSMENTS ON THE BGP
This section outlines the regional characteristics, site specific geological, hydrogeological, soils,
surface water and groundwater characteristics of the property and surrounding areas, and
surrounding land use.1
6.1 Regional Characteristics
The Site is located within the Alberta Plain, a sub-region within the Interior Plains physiographic
region of Canada. The plains are characterized by gently rolling landscape with flat-topped hills.
Creek and river valleys are generally broad and deep, representing mature drainage features. The
regional terrain generally slopes from west to east, with a moderate elevation change from
approximately 1,092 metres above sea level (masl) near the Balzac facility, to roughly 1,070 masl,
near Twin Lakes 7 km to the east.
6.2 Geology
Bedrock encountered below the site is the Upper Porcupine Hills Formation, which consists of
dark to very dark grey, fractured and weathered, calcareous siltstone, very fine-grained sandstone,
and claystone. To date, the maximum depth of exploration into the bedrock on-site is 95 metres
below ground surface (mbgs). Regionally, the thickness of the Porcupine Hills Formation is
about 450 m, thinning towards the east.
Surficial deposits, approximately 2 to 11 metres thick, overlay the bedrock. Beneath much of the
Plant site, these deposits have been disturbed as a result of original site grading during
construction of the plant in the late 1950’s. This is evident from the 0.6 to 1.8 m thick layer of fill
in the process area. Native surficial deposits cover the remainder of the site and consist of a
1 References for Section 6.0 Site Characterization were taken from consultant reports listed in Section 7.1
of this report.
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blanket of calcareous, low to medium plastic, sandy silt (Balzac Formation) overlying a silty clay
till (Lochend Formation), containing thin, silty sand lenses ranging from 0.1 to 1.3 m thick. These
Quaternary deposits vary in thickness from 3.0 to 6.7 m at the site. The majority of till appears to
be oxidized, as evidenced by brown colouration and the abundance of iron oxide staining.
However, the lower 1.0 to 1.5 m becomes dark grey to mottled grey-brown in colour, indicating
the presence of a relatively thin transition zone from oxidized to unoxidized till.
During field work in support of the 2006 Site Management Plan, a unit of black organic silty clay
to clayey silt approximately 0.3 to 2.2 m thick was encountered in boreholes covering a large
portion of the southeast part of the Site. Field observations suggest that these sediments were
deposited in a lacustrine environment. Initial results of an investigation into the effects of acid
conditions beneath the west sulphur basepad indicate that this organic layer possesses significant
buffering capacity.
Little topographic gradient can be seen across the Site and hence surface water often ponds onsite
without mechanical pumping.
At the site, there are three distinct water-bearing zones identified in the groundwater monitoring
network. The three zones are defined as follows: Weathered Till Horizon or A-series,
Till/Bedrock Contact or B series, and Bedrock or C-series. Depths of the A-series piezometers do
not exceed 5.1 mbgs. Generally, the A-series wells are completed in silty sand or sandy-silt clay
till. The till is typically moist or saturated and mottling is common. Sub-angular pebbles and
cobbles of various lithologies are prevalent throughout the till across the site. Gypsum crystals are
evident within the till at some piezometers.
The B-series piezometers range from 4.3 to 8.4 mbgs and are screened such that they intersect the
weathered till just at the bedrock contact. They include a very minor portion of the upper bedrock
within the screen. Beneath the till, a very fine, grey sandstone or siltstone is apparent. This unit is
very hard and dry. The sandstone or siltstone alternates with a shale unit to a maximum depth of
28.3 mbgs. The shale is hard, dark grey, brittle and breaks into blocky, angular fragments.
Groundwater flows within the highly fractured shale unit and the depth to groundwater increases
with distance from the lake.
Depths of the C-series monitoring wells vary from 4.1 to 28.3 mbgs.
6.3 Soils The soils of the Site have been mapped as a complex of poorly drained saline Humic Gleysols,
well drained Black Chernozems, and well to imperfectly drained Solodized Solonetz. These soil
types have formed on a thin discontinuous layer of lacustrine sediments overlying till. This till
was deposited in a lower-lying groundwater discharge area divided by occasional well-drained
knolls. All soil types have a black surface horizon (Ah) of varying thickness and texture and high
organic matter content. The light coloured sub soils (Csak) generally contain free lime and
soluble salts.
The majority of the soils sampled near the Site are the Balzac series, which is a saline-carbonate
Rego Humic Gleysol. Balzac soil is poorly drained, and forms where saline groundwater is
permanently maintained near the soil surface. This soil type is associated with groundwater
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discharge and shallow water table areas. Based on the soil survey information and investigative
observations made to date, surface mineral soils of the subject area are saline and calcareous, and
possess a high buffering capacity.
6.4 Hydrogeology During operations, Nexen has completed numerous assessments of groundwater at the BGP
resulting in significant understanding of the regional and local hydrogeology of the area.
6.4.1 Regional Hydrogeology
Porcupine Hills Formation has the potential to contain major aquifer intervals in the area.
Regional groundwater flow in the deeper bedrock is towards the east-southeast. Potential well
yields have been found to range from less than 0.075 L/s to more than 37.5 L/s. In the vicinity of
the plant (5 km radius), groundwater yields range from 0.04 to 11.4 L/s, based on AENV water
well records. Groundwater in the Porcupine Hills Formation is dominantly sodium-bicarbonate
and sodium-bicarbonate-sulphate types exhibiting total dissolved solids (TDS) of approximately
1,500 mg/L. In general, the water quality would be considered poor, based on sulphate and TDS
values in excess of the aesthetic objective (AO) for drinking water quality, with both AO values
set at 500 mg/L.
As previously noted the Quaternary deposits in the area are relatively thin (2 to 11 m) and have
little potential for groundwater resource development, based on their low hydraulic conductivity
and poor water quality. Water produced from the tills commonly has a very high mineralization,
usually associated with sodium and sulphate. Due to the elevated sulphur content in local till
deposits, concentrations of naturally occurring sulphate in groundwater may typically be in excess
of the current Health Canada (2006) AO guideline.
6.4.2 Present Groundwater Use
All water well records within a 5 km radius of the Balzac Sour Gas Plant were reviewed in 2006.
Relevant information was obtained from the AENV Water Well database. A total of 354 water
wells records were obtained from the database search. The state of wells within the area of
interest and their locations were not field verified. The majority of the wells were installed from
1939 to 2001. Well completion depths range from approximately 10 to 137 mbgs, with the
majority of wells being completed within 60 m of the ground surface.
Groundwater use in the study area was as follows:
Domestic use: Approximately 80% ;
Mixed use (domestic, livestock, irrigation): Approximately 4% ;
Livestock watering use: Approximately 10%;
Industrial use: Approximately 1%; and,
Other/Unknown use: Approximately 5%.
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6.4.3 Local Groundwater Conditions
Regional water quality surveys have been conducted on a voluntary basis by Nexen at locations
surrounding the BGP since 1967. These surveys were conducted annually from 1967 to 1976, and
biennially thereafter, last occurring in 2007. The 2007 monitoring program included 15 domestic
supply wells and 2 stock wells. Surface water samples were collected from 2 dugouts and
McDonald Lake. In addition, one industrial injection well was sampled.
The 2007 groundwater quality results were generally consistent with previous programs. The
main findings of that study are summarized below.
Indicator Parameters
Groundwater in the region is generally a sodium-bicarbonate-sulphate type. Many of the domestic
supply wells sampled have natural concentrations of sodium, sulphate, turbidity, and TDS that
exceed the respective aesthetic objectives as defined in the Guidelines for Canadian Drinking
Water Quality (GCDWQ).
Significant variations in the main ion concentrations of the water sampled from McDonald Lake
have been documented over the years. Concentrating effects from evaporation and periodic
dilution from major runoff events are believed to be the cause. The presence of surface salts
around the edges of McDonald Lake supports the hypothesis of excessive evaporation as a
controlling mechanism. Chloride concentrations on the west side of the lake opposite the Plant
facility have been found to range from 375 mg/L to 1,750 mg/L depending on time of sampling.
Similar variations in ion concentrations are observed in samples from other surface water bodies
in the area.
McDonald Lake and the Southwest Dugout are potentially accessible for livestock watering. The
2004 Regional Groundwater Monitoring Program indicated that the sulphate concentrations in
samples from McDonald Lake and the SW dugout within the Plant boundary exceeded the
Canadian Council of Ministers of the Environment (CCME) (1999) livestock guideline of 1,000
mg/L.
Dissolved Hydrocarbons
Water samples were analyzed for benzene, toluene, ethylbenzene, and xylenes (BTEX), and
petroleum hydrocarbon fraction 1 (PHC F1). Hydrocarbons were not detected in any of the
domestic or stock wells tested with the exception of a single well which reported a toluene
concentration of 0.0012 mg/L in November 2004. A confirmatory sample and a duplicate were
taken at this location in December 2004 and the results were both below the analytical method
detection limit (<0.0004 mg/L). The November 2004 result was not confirmed and was likely due
to laboratory error.
Total Metals
The 2004 analytical schedule was updated to include total metals analysis instead of dissolved
metals analysis. Total metals analysis should be performed when sampling from developed water
wells or surface water bodies, including residential water wells. All reported concentrations of
total metals were below the respective Guidelines for Canadian Drinking Water Quality
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“(GCDWQ”) criteria with the exception of total iron and manganese, which may be a result of
natural conditions, and total arsenic at McDonald Lake. Historically, elevated arsenic
concentrations in excess of the Health Canada (2006) Maximum Acceptable Concentration
(MAC) have been reported at well 821. In 2002 and 2004, the arsenic level reported at well 821
remained below the respective MAC of 0.025 mg/L. In 2002, dissolved arsenic concentrations
above the GCDWQ guideline were measured in the Dugout southwest of the Plant (sample 004)
and in McDonald Lake. In 2004, the total arsenic concentration reported at McDonald Lake
(0.0977 mg/L) exceeded the Health Canada (2006) MAC.
At the BGP, arsenic is not a chemical used, or created, as a result of operating processes.
Furthermore, sampling procedures and findings in groundwater assessments lead Nexen to
believe that arsenic levels previously identified, represent background/natural conditions in
McDonald Lake.
Biological Parameters
Total coliforms were below the Maximum Allowable Concentration (‘MAC’) of 10 mpn/100 mL
at all residential wells sampled and fecal coliforms were not detected in any residential wells. All
surface water samples analyzed in 2004 indicated the presence of total coliforms in excess of 10
mpn/100 mL. Fecal coliforms were detected at location 883 (Nexen Slough). The surface water
bacteriological results are consistent with the use of the water bodies by livestock and/or
waterfowl.
6.5 Industrial and Surface Water A Industrial Runoff Management Report was prepared in 2003 for Nexen by Westhoff
Engineering Resources, Inc. (Westhoff, 2003). Westhoff (2003) was a component of the Plant
license renewal application as submitted to Alberta Environment in August, 2003. It described
findings of a site assessment, a review of historical water releases into McDonald Lake, and the
industrial surface runoff drainage system including an assessment of site catchment areas, site
drainage infrastructure, and the locations where surface runoff is released to McDonald Lake.
Westhoff (2003) also assessed industrial runoff quantity through modelling and a separate water
balance analysis of McDonald Lake. The following description of catchment areas is based
largely on the Westhoff (2003) report with confirmation completed during site visits by Worley
Parsons Komex.
Generally, runoff of the Plant is collected in surface ditches and ponds. Much of the south end of
the Plant is self-contained in the sense that runoff stays on site through infiltration and/or
evaporation.
Runoff from the north end is fed via a series of pumps through a water treatment system,
collected in the Sulphur Block Area Surface Runoff Collection Pond and tested before it is
released to McDonald Lake. Runoff from the Plant is released to McDonald Lake in a controlled
manner and only after it has met the release limits of the Approval.
The most important surface drainage feature near the site is McDonald Lake located on the
western edge of the BGP. No streams, creeks, or natural watercourses enter or leave the lake, and
therefore, it is assumed that the lake is a discharge point. Overland drainage from adjacent
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agricultural and pastureland is also known to accumulate in the Lake. Surface runoff occurs
mainly during the spring snowmelt, or immediately following periods of heavy precipitation.
Historical aerial photos indicate that in the past, McDonald Lake has dried.
A report on assessing Industrial Runoff was prepared by Worley Parsons per operating approval
requirements and it was submitted to Alberta Environment in 2006. The purpose of the report was
to review runoff management at the Plant and evaluate current practices to determine what
improvements could be made to positively impact the site and the watershed downstream of the
plant. Worley Parsons Komex Report: Balzac Gas Plant – 2006 industrial Runoff Assessment - File No. C25531806
6.5.1 Catchment Areas – Balzac Gas Plant
Currently there are a total of eight catchment areas across the BGP Site as shown in Figure 1.
Generally, runoff of the Plant is collected in surface ditches and ponds. Much of the south end of
the Plant is self-contained in the sense that runoff stays on site through infiltration and/or
evaporation. Runoff from the north end is fed via a series of pumps through a water treatment
system, collected in the Sulphur Block Area Surface Runoff Collection Pond and tested before it
is released to McDonald Lake. Runoff from the Plant is released to McDonald Lake in a
controlled manner and only after it has met the release limits of the Approvals.
Catchment Area A – Process Area and Sulphur Storage Area
Catchment area A contains two sub-catchment areas: the Sulphur Storage Area (A -1) and the
Process Area (A -2). Surface runoff from the Process Area is naturally conveyed to the S.E.
Runoff Pond located between the railway spur line and the Firewater Pond. From there runoff
flows northward along a drainage ditch towards the S.W. Crusher Pump Station. Runoff from
portions of the Sulphur Storage Area is also collected at the S.W. Crusher Pump Station via small
culverts under the rail line. This surface runoff is then pumped into a High Density Polyethylene
(HDPE) lined swale and commingled with runoff water from the remainder of the Sulphur Storage
Area. In the HDPE lined swale, this water flows by gravity to the single lined HDPE Containment
Pond.
A Crusher Pump Station is in place because generally surface grades do not permit the flow of
surface runoff from the S.E. Runoff Pond and the majority of the Sulphur Storage Area to the
Acid Water Containment Pond. The runoff water is collected in the Acid Water Containment
Pond treated with caustic to neutralize pH and then pumped to the Sulphur Block Area Surface
Runoff Collection Pond. The water in the Sulphur Block Area Surface Runoff Collection Pond is
analyzed for parameters as identified in the approval and released to McDonald Lake, provided
that it meets the release limits.
Catchment Area B – Firewater Pond
Catchment area B is a 0.50 ha self-contained retention area for the storage of fire water with no
structural connections to the adjacent catchment areas. This pond is filled with water supplied by
the City of Calgary to provide a fire suppression contingency for the Plant.
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Catchment Area C – Sulphur Handling Facility and Surrounding Area
Catchment area C is a triangle shaped area between the Sulphur Storage Area and Range Road
291with local Plant roads on the north and the S.E. Quadrant (catchment area E) on the south.
Surface runoff from the Sulphur Handling Facility itself is collected and conveyed via two
culverts to the Acid Water Containment Pond where it is treated with caustic to neutralize pH and
pumped to the Sulphur Block Area Surface Runoff Collection Pond. A portion of runoff
generated from this catchment is drained to a Low-Lying Area west of Range Road 291.
Catchment Area C-C – Plant Entranceway and Surrounding Area
Catchment area C-C is a triangle shaped area between the Sulphur Storage Area and Range Road
291 and Plant entranceway. Surface runoff from the Plant Entranceway flows to McDonald Lake.
Catchment Area D – Sulphur Block Area Surface Runoff Collection Pond
This area includes the runoff collection pond for water that is pumped and treated from catchment
areas A and C. This pond acts as a holding cell while water is analyzed before being released to
McDonald Lake.
Catchment Area E – S.E. Quadrant
This area consists of two wetland areas located between the railway tracks and Range Road 291.
Surface runoff from the northern portion of the S.E. Quadrant is self-contained in that area.
Surface runoff in the southern portion of the S.E. Quadrant at times of high water flows south of
the Plant off of Nexen property to a slough south of the Plant, then makes its way north back onto
the Plant and drains via a ditch system to McDonald Lake.
Catchment Area F – Abandoned Evaporation Pond
Surface runoff in this catchment area F is self-contained within the catchment and drains into the
Abandoned Evaporation Pond where the water evaporates or infiltrates.
Catchment Area G – Auxiliary Facilities
This area contained several auxiliary facilities including a filter cake disposal pond, a chemical
pond, a double-lined open drain collection pond and a hydrocarbon burn pit. Surface runoff from
this catchment area is directed via ditches and overland drainage to a low area known as the
Abandoned Holding Pond. The Abandoned Holding Pond is located in the northeast portion of
the catchment area and across the road from the Abandoned Evaporation Pond. Runoff collected
in catchment area G evaporates or infiltrates in this area.
Catchment Area H – Blowdown Ponds
The wastewater from the cooling tower blowdowns and the treated wastewater from the Plant
boilers were piped to the two Blowdown Ponds. Surface runoff generated in the immediate
catchment area previously made up only a small portion of the water contained in the two
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blowdown ponds. This water (formerly blowdown water), which has been changed from
industrial wastewater to industrial runoff water per amended approval 155-02-06, is analyzed
before it is released to McDonald Lake via a pipeline, hoses or piping.
Table 4. Summary of catchment area sizes, current land use, and confirmation of Plant
runoff contribution.
Catchment Area Area (ha) Land Use Contribution to Runoff
A-1 14.0 Sulphur Storage Area Yes
A-2 19.5 Process Area Yes
B 0.5 Firewater Pond No
C 8.25 Sulphur Handling Facility and
Surrounding Area Yes
C-C .75 Plant Entranceway and
Surrounding Area No
D 1.0 Sulphur Block Area Surface
Runoff Collection Pond Yes
E 6.6 S.E. Quadrant No
F 19.4 Abandoned Evaporation Pond No
G 13.5 Auxiliary Facilities No
H 0.4 Blowdown Ponds No
Catchment area characteristics are based on information provided in Westhoff (2003).
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Nexen has attempted to determine how the reclamation of the BGP will potentially affect
McDonald Lake water levels. The original Westhoff Report (2003) indicated that a 1:10 year
storm would result in approximately 23,400 m3 of surface runoff from the BGP. A 1:100 year
storm was estimated to result in 37,165m3 of surface runoff from the 8 catchment areas into
McDonald Lake. Further analysis indicated that McDonald Lake had adequate capacity to handle
surface runoff volumes. Since the 2003 licence application, however, other inputs into McDonald
Lake have occurred from other areas including new local developments and these volumes into
McDonald Lake have not been studied by Nexen.
The final input of surface water into McDonald Lake from a successfully reclaimed BGP will
depend on final land use at the time of reclamation certification, in addition to surrounding land
use. Currently surrounding the lake there are numerous other developments that result in
unmonitored discharges of surface flow into the lake. As Nexen has no knowledge of those
surrounding surface water inputs, the overall effect of reclamation at the BGP cannot be
determined at this time.
6.5.2 Catchment Areas – Surrounding Lands
Currently there are a total of 11 catchment areas located on lands surrounding the BGP. (FIGURE
2) Generally, runoff from these surrounding lands is collected in surface ditches and ponds before
it is released to McDonald Lake. As far as Nexen can determine, runoff from these surrounding
lands are not released into McDonald Lake in a controlled or monitored manner. Nexen cannot
confirm if release limits are being monitored within these surrounding catchment areas.
!
!
! !
!
!
!
!
!
!
!!
!
!
!
Existing Catchment A619ha
Existing Catchment B1500ha
Catchment A
Catchment BCatchment C
Catchment D
Catchment E
Catchment F Catchment G
Catchment HCatchment I
Cell 'A'
Cell 'B'
Ham EastConceptual
Scheme
Wagon WheelIndustrial Park
ConceptualScheme
High PlainsIndustrial Park
ConceptualScheme
RosemontConceptual
Scheme
Walton Development & Management NE
Residual Area
MunicipalCampus
CrossIron Mills
Racing /
Entertain
ment
Centre
Nose Cree
k
Business
Park
Points North
Business Park
Prodev Ltd.PartnershipConceptual
Scheme
SR
36-025-01-W5
02-026-29-W4
13-026-29-W4
07-026-28-W4
16-026-29-W4
09-026-29-W4
03-026-29-W4
14-026-29-W4
36-025-29-W4
12-026-01-W5
34-025-29-W4
11-026-29-W4
01-026-01-W5
15-026-29-W4
35-025-29-W4
01-026-29-W4
31-025-28-W4
18-026-28-W4
13-026-01-W5
06-026-28-W4
19-026-28-W4
33-025-29-W4
10-026-29-W4
Legend! Storm Water Pond
BuildingsDevelopedStorm Water PondCatchementsConceptual Scheme Outline
±
services
Author: S. DurhamGIS Analyst : M. JanickDept. : GIS Services
Date: September 2, 2011File No: A13256.mxd
NEXEN INC. 801-7th Ave S.W. Calgary, AB. Canada T2P 3P7T. 403.699.4000 www.nexeninc.com
BALZAC CATCHEMENTS026-29-W4M
Nexen Inc.Canadian Oil & Gas Division
Scale: 1:25,000
0 500250Meters
SR Balzac Plant
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6.6 Surrounding Land Use The Site and land directly to the west, north and east is located within Rocky View County. Land
directly to the south of the Site is located within the city limits of Calgary. Currently, surrounding
land use to the north and to the west of the Site is primarily agricultural, while land use to the
south and to the east of the Site is industrial and agricultural.
A Land Use District map from the City of Calgary Planning, Development & Assessment
indicates the land directly south of the Site is situated in zoning of S-FUD. The following is a
description of the zoning classification:
S-FUD – Special Purpose – Future Urban Development District. The purpose of this
district is intended to:
be applied to lands that are awaiting urban development and utility servicing;
protect lands for future urban forms of development;
provide for a limited range of temporary uses that can be easily be removed when
land is re-designated to allow for urban forms of development; and
accommodate extensive agricultural uses prior to development to urban uses
(City of Calgary 2008).
A land use map from the Rocky View County indicates the Site is designated as NRI and
surrounding land use is PS, I-IA, NRI, B-2, DC-94 and DC99. The following is a description of
these zoning classifications:
NRI – Natural Resources Industrial District. The purpose of the district is to provide
development of industrial uses related to non-renewable natural resource extraction and
processing;
PS – Public Services District. The purpose of the district is to provide for the development
of Institutional, Educational and Recreational uses. This can include a residential dwelling;
I-IA – Industrial Activity. The purpose of the district is to provide for a range of industrial
activity, including agricultural, industrial and commercial;
B-2 – The purpose of the district is to provide for a wide range of business and associated
uses, which are compatible with each other and do not adversely affect surrounding land
use. Uses include agricultural, industrial and commercial; and
DC – Direct Control District. The purpose of the district is to provide for developments that
due to unique characteristics, unusual site constraints or innovative ideas require specific
regulations unavailable in other land use districts. All land use applications shall be
evaluated by the Rocky View Council to establish appropriate development standards
(Rocky View County 2011).
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A Balzac East Area Structure Plan (BEASP) from the Rocky View Department of Planning and
Development indicates land to the west of the Site will be primarily a commercial/light industrial
area. Land to the north and east of the Site is also considered appropriate for industrial and
business development (Municipal District of Rocky View 2008). (FIGURE 2)
The catchment area map provided in Figures 1 and 2 also shows future development scenarios for
the lands surrounding the BGP. The Figure shows 5 different Industrial Park development
schemes surrounding the BGP.
Nexen has had preliminary discussions with the Municipal District of Rockyview #44 regarding
existing surrounding, and potential future land uses immediately adjacent to the BGP. The reality
is that at the time of final reclamation, surrounding zoning may have changed. But given the
current state of zoning, the existing industrial uses to the north and south, and the development of
a warehouse directly east of the BGP, Nexen anticipates that zoning will continue to remain
“heavy industrial”. However Nexen will continue to review end land use and zoning with the
MD of Rockyview on an as needed basis as adjacent zoning changes. AENV will be updated
following these meetings.
NRI
AH
DC118R-1
R-2
R
RF
AH
NRI
NRI
AH F
R-1
R-2
F
R-2
R-2
AHB-
4
AHR
-2
F
R-3
R-2
DC30
R-2
NRI
R-2
F
R-2
R-1
B-2 R
-1
R-1
F
R-3
B-2
R-1
FDC109
DC99
DC99
DC99
DC99
DC99
DC99
DC117
DC94
DC109
DC99
C
RF
DC72
R-2
DC125
R-1
DC
31
DC
128
F
AH
DC131B-2
PS
DC131PS
I-IA
2
ST566
LAND USE MAP No.
DATE: Mar 31, 2011
TWP. 26-29-W4M
ROCKY VIEW COUNTY
ALL LANDS ARE DESIGNATED RF UNLESS NOTED OTHERWISE
Part FIVE of the BYLAW No. C-4841-97
64-SOUTH
McDonald Lake Existing Balzac Gas Plant
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7 REMEDIAL CHARACTERIZATION This section provides a detailed discussion by year of previous site assessment studies and
remedial activities that have been completed at the BGP.
7.1 Previous Investigations and Remedial Programs Nexen has conducted numerous air quality, soils and groundwater investigations at the facility
since 1990. This following summarizes information previously gathered (from the date of last
operating approval), and unless otherwise indicated, AENV has already been provided copies.
AIR QUALITY
1. Annual Air Quality Reports. 2003 to 2010. Each report summarizes annual air quality
data collected for ambient H2S and SO2, NOx emissions, sulphur block activity and
sulphur handling facility operations, in addition to an annual evaluation of QAP and
CEMS operations at the Plant. As air quality emissions, testing, results and exceedences
are specific from year to year, and not applicable to the SDS and DRR project due to the
shutdown of the BGP, no further summary is warranted.
WATER QUALITY
1. Annual Water Quality Reports. 2003 to 2010. Each report summarizes annual water
quality data collected. The following data is included in the annual water report:
a. Sources of Fresh Water and Chemical Treatment;
b. Sources of Wastewater;
c. Wastewater Disposal and Treatment;
d. Site Plan Showing Water Handling Facilities;
e. Changes or Modifications;
f. Controlled Releases;
g. Water Quality Survey of McDonald Lake;
h. Industrial Landfills on site;
i. Industrial Runoff Water and Industrial Wastewater is also summarized.
AMD SOILS
1. Annual AMD Soil Monitoring Reports. Assessment of the Effects of Elemental Sulphur
Handling on Soils. 2003 to 2010. The objective of this soil monitoring program was to
monitor soils in the vicinity of the sulphur storage and handling facilities to assess any
impacts resulting from the deposition of elemental sulphur dust. As the effects of
elemental sulphur on surrounding soils were monitored over time, the most recent results
(2010) are the most relevant. They are as follows: Of 50 soil monitoring network sites,
22 sites exceeded the AMD guideline for total sulphur, 9 sites exceed the AMD guideline
for pH. The limestone requirement calculations indicated that 9 sites required limestone
addition to counteract potential and active acidity resulting from the oxidation of sulphur.
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Although sites indicated a lime requirement, none of the sites were limed because the pH
values were either not acidic, or were only slightly acidic.
Finally, most of the sample locations were located east of the BGP. At the time of this
application, most of the surface soils on those lands have been, or are in the process of,
being removed to allow for the construction of a warehouse facility.
SOILS
1. 2006 Soil Monitoring Program. Balzac Sour Gas Plant. Worley Parsons. Report
C25531803. 30 November 2006. The program was designed to meet the terms and
conditions for soil monitoring in Section 4.7.1 through 4.7.9 of the AEPEA Approval
No.155-02-00. In total 58 sampling locations were proposed for the soil monitoring
program at the Balzac Sour Gas Plant only 51 of which were drilled. Please refer to the
Tables 7 – 12 in this document which outline known Contaminants of Potential Concern
(“COPC”) by area.
2. 2006 Soils Management Plan. Worley Parsons - Report No. C25531901. Issued to
Alberta Environment May 31, 2007. This report, subsequent to the completion of the soil
monitoring program, a soil management plan must be submitted to Alberta Environment
within six months of the soil monitoring report. Please refer to Figures 5 & 6 and Tables
8-13 in this document which outline known Contaminants of Potential and Liability
Subunits.
3. 2007 Soil Management Activities Program at Balzac Sour Gas Plant. Worley Parsons.
Report C25532002.
4. March 28, 2008.In 2006, sampling locations were selected to characterize the soil north
of the sulphur/soil stockpiles within the northern and southern stockpiles, and at the base
between the stockpiles. Based on the analytical results and field observations, it was
determined that excavation and off-site disposal of the soil from the sulphur/soil
stockpiles was required. As scheduled, the work began in fall 2007. From October 31 to
December 4, 2007, material from the sulphur-impacted stockpiles was removed from the
Site and hauled to the CCS Energy Services Ltd. (CCS) Landfill located at Rocky
Mountain House, Alberta. Nexen, who is responsible for the overall management of the
Site, supervised and directed the hauling of impacted soil. The following is a summary of
the extent of the sulphur/soil pile removal completed up to December 4, 2007:
Initial sulphur/soil stockpile volume = 23,292 m3 (plus approximately 400 m3 of
waste sulphur; as surveyed)
Volume hauled to CCS Landfill = 16,305 m3 (plus approximately 400 m3 of waste
sulphur)
Remaining sulphur/soil stockpile volume = 6,987 m3 (approximate)
Mass received by CCS Landfill = 27,396 tonnes
Bulk Density of material hauled = 1.64 tonne/m3 (calculated)
The remaining material from the sulphur/soil stockpiles was removed when work
resumed in 2008. The soil north of the stockpiles to a depth of at least 2.0 metres below
ground surface (mbgs) and the soil underlying the stockpiles and to the south of the
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stockpiles to a depth of at least 0.15 mbgs also required excavation and off site disposal.
Excavation work began in 2008.
5. 2008 Soil Management Activities Program at Balzac Sour Gas Plant. Worley Parsons.
Report C25532105. March 27, 2009. On January 21, 2008, work in the sulphur/soil
stockpiles area resumed. Impacted soil underneath and adjacent to the piles underwent
excavation. Removal of the remaining material from the sulphur/soil stockpile (11,459
tonnes) was completed in 2008. In total 38,855 tonnes of impacted soil was landfilled
from the stockpiles. In addition to the removal of the stockpiles, it was determined that
sulphur-impacted soil underlying and adjacent to the stockpiles required excavation and
off Site disposal. Excavation of sulphur-impacted soils was conducted in January to
March 2008 under the direction of a Nexen representative. An additional 46,775 tonnes
of sulphur-impacted soil was hauled from the excavation to the landfill. The excavation
was generally sloped from the south to the north, and soil was excavated to depths
ranging from 0.1 to 3.0 metres below ground surface (mbgs). Physical constraints to the
north (road), east (road), south (pipeline and railway) and west (railway and power poles)
prohibited further excavation; therefore, characterization sampling of the walls and
ditches was conducted. All final confirmatory base samples reported elemental sulphur
below the AENV Tier 1 (2007) guideline (500 mg/kg) and total sulphur content below
the Alberta Environmental Protection (AEP) (1996b) guideline (4% total sulphur). The
AENV Tier 1 (2007) guidelines were also used as remedial endpoints for hydrocarbon
and metals analyses.
The following is a summary of the 2008 activities:
Estimated in situ volume excavated = 22,000 m3
2007 mass received by CCS Landfill = 27,396 tonnes
2008 mass received by CCS Landfill = 58,234 tonnes (inclusive of 11,459
tonnes remaining from stockpile)
Total Sulphur/soil stockpile removal mass received by CCS Landfill =
85,630 tonnes (2007 & 2008 activities).
The excavation was backfilled in April 2008 and topsoil was placed and seeded
in October 2008. The results of the sulphur/soil stockpile removal and excavation
of underlying soil are discussed in WorleyParsons (2009b).
Previously Unknown Sump Excavation: A soil investigation was conducted in
2006 to characterize and delineate the facility-related impacts within the previously
unknown sump area. Based on the results of the 2006 investigation, excavation and both
off Site disposal and on Site treatment of the soil was selected as the remedial strategy.
Excavation activities were conducted under the direction of a Nexen representative from
October 2008 until December 2008. Off Site disposal of heavily impacted material took
place from November 28 to December 2, 2008. Approximately 3,039 tonnes of soil was
hauled off Site to BFI Landfill Calgary. Excavation sampling (November 20 to 22, 2008
and December 4 to 5, 2008) and groundwater sampling events were completed. Soil
sample results were compared to the AENV Tier 1 (2008) guidelines for detailed salinity,
benzene, toluene, ethylbenzene and xylenes (BTEX), petroleum hydrocarbon (PHC)
fractions F1 through F4, polycyclic aromatic hydrocarbons (PAH) and glycols analyses.
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Results indicated impacts above guidelines remaining within areas of the excavation;
therefore additional delineation and excavation activities were recommended for 2009.
The following is a summary of 2008 activities:
Estimated in situ volume excavated = 6,000 m3
2008 mass received by BFI Landfill Calgary = 3,039 tonnes
Enersul Stockpile Removal: In 2006, sulphur and salinity impacts were
identified at sampling locations (S06-71 and S06-75) within the suspected topsoil
stockpile at the Enersul area. Off Site disposal of impacted material was recommended.
As scheduled, the work was conducted in November 2008. Under the direction of a
Nexen representative, the stockpiles and impacted soil underlying and adjacent to the
stockpiles was transported off Site.
The following is a summary of 2008 activities:
Estimated ex situ volume = 8,000 m3
2008 mass received by BFI Landfill Calgary = 15,086 tonnes
On November 28, 2008 soil samples (0.0 to 0.15 mbgs) were obtained from the base area
underlying and adjacent to the stockpiles. Elemental sulphur and total sulphur impacts
were reported above the applicable guidelines at select sampling locations. Test pitting
was conducted to determine the vertical extent of sulphur impacts to soil on January 16,
2009. Elemental sulphur impacts were identified from surface to 0.6 mbgs.
6. 2009 Soil Management Activities Program at Balzac Sour Gas Plant. Worley Parsons.
Report C25522109. March 30, 2010.
Sulphur Handling Facility
A soil investigation was conducted in 2006 to characterize and delineate the
facility-related impacts within the sulphur handling facility (WorleyParsons
Komex 2006a). The following findings of the 2006 investigation pertain to 2009
activities on Site:
i. sampling locations S06-60, S06-73 and S06-74 were investigated to
characterize the sediment in the drainage ditch adjacent to the sulphur
pad and loadout. Elemental and total sulphur impacts were confirmed in
the drainage ditch. Elevated electrical conductivity (EC), depressed pH
values and elevated salinity parameters at S06-73 and S06-74 indicated
significant sulphur-related impacts. Excavation and off Site disposal of
soil was recommended. After remediation of the drainage ditch, it was
recommended that an impermeable liner be utilized to prevent possible
future impacts to this area. An Industrial Runoff Assessment
recommended the reconstruction and remediation of ditches in the
Sulphur Handling Facility Area;
ii. at S06-63, located adjacent to the underground rail tank car, pH,
elemental and total sulphur impacts were confirmed by analytical results
and field observations. Excavation and off Site disposal of soil was
recommended;
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iii. significant hydrocarbon impacts were not identified at S06-64, located
near the former fuel tanks, as hydrocarbon parameters were below
guidelines. No remedial action was recommended; and
iv. soil underneath the old slating units (S06-65) and at the Enersul poured
sulphur pad (S06-66and -67) was characterized. Based on field
observations and laboratory analyses, sulphur impacts were identified
including elevated EC values, acidic pH and elevated elemental/total
sulphur concentrations. Excavation and off Site disposal of soil was
recommended, with potential for in situ remediation for soil at depths
below 1.0.
In 2009, upgrading of the surface water drainage ditch system in the sulphur handling
facility commenced. In conjunction with this program, impacted soil was excavated from
the drainage system, the underground rail car (Enersul Water Tank), the old slating units
and poured sulphur pad within the sulphur handling facility. Soil excavation, disposal
and backfilling activities took place under the direction of a Nexen representative from
August to December 2009. Excavation continued until impacts were not visible and
analytical results were reported below applicable guidelines unless the excavation was
restricted by infrastructure in the area. Soil sample results were compared to the AENV
Tier 1 (2009) guidelines for sulphur, detailed salinity, benzene, toluene, ethylbenzene and
xylenes (BTEX), petroleum hydrocarbon (PHC) fractions F1 through F4, polycyclic
aromatic hydrocarbons (PAH), metals and volatile organic compounds (VOCs). Soil
sample results were also compared to AENVs Guidelines for the Remediation and
Disposal of Sulphur Contaminated Solid Wastes (AEP 1996b) to determine the remedial
requirements for total sulphur.
Approximately 29,100 tonnes of soil was excavated and disposed of at the BFI Calgary
Landfill. During the excavation, the fuel tanks located near S06-64 were moved to the
south side of the maintenance building near soil monitoring location S06-70. Analytical
results of excavation confirmatory soil samples indicate soil concentrations of sulphur,
hydrocarbons and salinity remain above guidelines in areas of the excavation restricted
by infrastructure. The excavation was backfilled with fill imported from an off Site
location and a significant portion of the drainage ditch system was paved with asphalt.
The following is a summary of 2009 activities:
2009 soil received by BFI Landfill Calgary = 29,100 metric tonnes.
DEA UST in the Process Area
The DEA UST is used as the collection point for many of the DEA pumps within the gas
plant’s process area. The tank was single walled and was scheduled for replacement with
a double walled tank.
Excavation and installation of the new tank was conducted under the direction of a Nexen
representative. Installation of the new tank along with a groundwater collection system
was completed on September 3 and 4, 2009. The new tank was installed parallel and
immediately south of the old tank.
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Soil excavated from the new tank area was placed into four 15 m3 bins for disposal.
Characterization sampling was conducted on the four walls and the base of the excavation
and groundwater samples were collected from the excavation. Soil sample results were
compared to the AENV Tier 1 (AENV 2009) guidelines for detailed salinity, BTEX, PHC
F1-F4, metals and amines. Groundwater sample results were compared to AENV Tier 1
(AENV 2009) guidelines for BTEX, PHC F1 – F2, routine potability, dissolved metals
and amines. A soil hydrocarbon concentration was reported above AENV Tier 1
guideline. Inorganic and hydrocarbon parameter concentrations from the groundwater
samples were reported above Tier 1 guidelines.
Unknown Sump Excavation
A soil investigation was conducted in 2006 to characterize and delineate the facility-
related impacts within the unknown sump area. Results of the program indicated
hydrocarbon odour and staining was present in the upper 2-3 m. Analytical results
indicated the presence of hydrocarbons and chloride. Excavation and both off Site
disposal and on Site treatment of the soil was recommended.
Excavation activities were conducted under the direction of a Nexen representative from
October 2008 until March 2009. Off Site disposal of heavily impacted material took place
from November 28 to December 2, 2008. Approximately 3,039 tonnes of soil was
disposed of off Site at BFI Landfill Calgary in 2008. Soil sample results were compared
to the AENV Tier 1 (AENV 2009) guidelines for detailed salinity, BTEX, PHC F1-F4,
PAH and glycols analyses. Results indicated impacts above guidelines remaining within
areas of the excavation.
On January 4, 2009, remedial activities within the unknown sump area resumed. Three
delineation trenches were excavated out from the south and west walls of the excavation.
Based on the results of the trenching, further excavation of the base and the west and
south walls was conducted. All confirmatory samples from the base and walls of the
excavation met AENV Tier 1 (AENV 2009) guidelines, with the exception of select
sampling locations along the eastern wall. Additional excavation along the eastern wall
and further to the east was not possible due to physical constraints (roadway and
pipeline). Partial backfill of the excavation occurred during 2009. Assessment of an in
situ groundwater extraction system along the eastern wall of the excavation is under
review.
Sulphur Base Pad Assessment
A soil investigation was conducted in 2006 to characterize and delineate the facility
related impacts within the sulphur handling facility. Varying depths of sulphur were
drilled through to attain ground surface in the west and east sulphur pads. Soil elemental
sulphur concentrations exceeded the applicable AENV guideline and elevated EC values
above established background data were reported.
The objective of the 2009 sulphur base pad assessment was to quantify the amount of
possible recoverable sulphur on the base pads, and the extent of impacts to soil
underlying the sulphur. Soil sample results were compared to the AENV Tier 1 (AENV
2009) guidelines for sulphur and salinity parameters. Soil sample results were also
compared to AENVs Guidelines for the Remediation and Disposal of Sulphur
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Contaminated Solid Wastes (AEP 1996b) to determine the remedial requirements for
total sulphur.
In total, 10 environmental boreholes were advanced across the west sulphur base pad.
Soil elemental sulphur impacts above the AENV Tier 1 (2009) guideline were identified
to an average depth of 0.6 metres below ground surface (mbgs) across the west sulphur
base pad. A total of 23 environmental boreholes were advanced within the east base pad
area. Nine locations were located on the existing east sulphur base pad. The additional 14
boreholes were located south of the existing sulphur block and base pad, where the base
pad had been previously excavated. Elemental sulphur impacts above the AENV Tier 1
(2009) guideline were identified to an average depth of 0.65 mbgs in soil underlying the
current base pad area. Impacts above the AENV Tier 1 (2009) guidelines were identified
to an average depth of 0.6 mbgs in the excavated portion. The estimated total volume of
impacted soil under both the east and west sulphur base pad areas is approximately
40,700 m3.
7. 2010 Soil Management Activities Program at Balzac Sour Gas Plant. Worley Parsons.
March 11, 2011. During 2010, on Site treatment and backfilling of soils from the
unknown sump excavation continued. All confirmatory samples from the base and walls
of the excavation met Tier 1 (AENV 2010) industrial, fine-grained surface soil
hydrocarbon guidelines, with the exception of select sampling locations along the eastern
wall. Additional excavation along the eastern wall and further to the east was not possible
due to physical constraints (roadway and pipeline). Approximately 3,039 tonnes of soil
was disposed of, off Site at BFI Landfill Calgary. The remainder of hydrocarbon-
impacted soil was stockpiled on Site for treatment and backfilling into the excavation
During 2010, approximately 700 m3 of soil was treated to meet Tier 1 (AENV 2010)
guidelines for hydrocarbon parameters and backfilled into the excavation. A portion of
excavated material requires further treatment.
Unknown Sump Excavation
During 2010, on Site treatment and backfilling of soils from the unknown sump
excavation continued. In 2008 and 2009, the excavation of the unknown sump was
completed. All confirmatory samples from the base and walls of the excavation meet Tier
1 (AENV 2010) industrial, fine-grained surface soil hydrocarbon guidelines, with the
exception of select sampling locations along the eastern wall. Additional excavation
along the eastern wall and further to the east was not possible due to physical constraints
(roadway and pipeline). Partial backfill of the excavation occurred during 2009. Design
and commissioning of an in situ groundwater extraction system along the eastern wall of
the excavation was considered; however, with the anticipated Site closure, a strategy for
managing/remediating residual hydrocarbon impacts will be assessed during the DRR
process. Approximately 3,039 tonnes of soil was disposed of, off Site at BFI Landfill
Calgary. The remainder of hydrocarbon-impacted soil was stockpiled on Site for
treatment and backfilling into the excavation. During 2010, approximately 700 m3 of
soil was treated to meet Tier 1 (AENV 2010) guidelines for hydrocarbon parameters and
backfilled into the excavation. A portion of excavated material requires further treatment.
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LIQUIFIED PETROLEUM GAS (LPG) UNIT NEAR PROPANE/BUTANE BULLETS
1. Delineation of Free Product Contamination in LPG Recovery Area – 1999, Komex
Report KI-2553-10-5 dated May 9, 1999. Conductivity probes were used in delineation of
plume.
2. Remediation Options Analysis - LPG Recovery Area, Komex Report KI-2553-11-02
(Draft) dated May 1999.
3. Installation and 1999 Performance Review - LPG Recovery Area, Komex Report
C2553-1106 dated March 2000.
4. 2000 Performance Review Phase I and Phase II Installation - LPG Recovery Area,
Komex Report C2553-1212 dated October 2001.
5. Proposed Expansion of Free Product Recovery System - LPG Recovery Area, Komex
Report C25531205 dated June 2000.
6. 2001 Performance Report Free Phase Recovery - LPG Recovery Area, Komex Report
C2553-1303 dated July 2002.
7. 2002 Performance Report - LPG Recovery Area, Komex Report C2553-1407 dated
March 19, 2003.
8. 2003/2004 Performance Report LPG Recovery Area, Komex Report C25531605 dated
July 27, 2005
9. 2005-2008 Performance Report Lean Oil Remediation System, Worley Parsons Report
C25532004 (Draft)
10. 2009-2010 Performance Report Lean Oil Remediation System, Worley Parsons Report
C25532104 (Draft)
Summary
In 1998, an Integrated Soil and Groundwater Investigation was conducted and confirmed the
presence of free phase hydrocarbons as light non-aqueous phase liquids (LNAPL) in the
Liquefied Petroleum Gas (LPG) Recovery Area. Further follow-up investigations delineated
an area of approximately 2,700 m2 with free phase hydrocarbons. Historically, free phase
hydrocarbon liquids have been noted in monitoring wells installed within the till, till/bedrock
and bedrock of the LPG plume. Field observations (sheen and hydrocarbon odour) and
elevated hydrocarbon groundwater concentrations indicate free phase hydrocarbon liquids
may have been present during monitoring events where measurable products was not
reported.
Several remediation options were review and a three phased in-situ approach was selected.
The three phased system is collectively referred to as the Lean Oil Remediation System. The
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objective of the Lean Oil Remediation System were free phase hydrocarbon containment and
plume mass recovery with treatment/disposal. The system includes the following:
Phase 1: product recovery trench;
Phase 2: free phase hydrocarbon extraction and dissolved phase hydrocarbon
treatment system using trench and gate technology; and,
Phase 3: vertical recovery wells for free phase hydrocarbon extraction.
Details regarding site conditions and the installation of Phases 1, 2 and 3 and system
monitoring are summarized as follows:
In 2002, Komex proposed Phase 3 of the remediation system, which consisted of a
product skimmer pump rotated between multiple vertical wells within the LPG area
lean oil plume . The skimmer pump concept was chosen so only free product would
be removed, thereby, eliminating the need for water disposal. Three wells (LPG-2,
LPG·3 and LPG-4) were installed in areas where groundwater monitoring
demonstrated the greatest thickness of free product.
Through 2003 to 2004, a TR 515 FAP. Plus™ Skimmer System was installed and
rotated between the three vertical wells on a regular basis. Recovered fluids were
stored in two 45-gallon drums. The drums were placed within Overpac barrels for
secondary containment.
In 2005, free phase hydrocarbon product was detected at LPG-2 (1.5 cm) and LPG-3
(up to 14.7 cm). Sheen was observed at LPG-4. On April 19, 2005, the TR 515
FAP. PlusH" Skimmer System pump (skimmer pump) was installed at LPG-3. The
2005 results indicated successful removal of free hydrocarbon product from the
groundwater, which was then added to the Plant's Open Drain Collection Pond for
deep well disposal. The pump was disconnected on October 12, 2005.
In 2006, two new extraction wells, LPG-5 and LPG-6, were added to the system in
2006 with the intention of recovering more product. Free phase hydrocarbon
product was detected at LPG-3 (up to 36 cm), LPG-5 (up to 1 cm) and LPG-6 (up to
3 ern), Sheen was observed at the other Phase 3 extraction wells. The Skimmer
System pump was re-installed at LPG-3 in 2006; however, due to operational
constraints, the pump was not operated and no free product was recovered.
In 2007, the skimmer pump could not be installed due to damage to the pump and
missing parts. The Phase 3 remediation system was not operated in 2007. Three six
inch remediation wells were installed around the CHD system within the LPG
Recovery Area.
In 2008, hydrocarbon free product was detected at LPG-3 and LPG-5. Hydrocarbon
sheen was observed at the other Phase 3 extraction wells in 2008. A new skimmer
pump was installed and hydrocarbon free product was successfully removed from
LPG-3. Product levels were non-detectable at well LPG-3 after the skimmer pump
was disconnected. On July 23, 2008, samples from the three wells were submitted
for routine potability and dissolved hydrocarbons analyses. In the three culverts,
iron, manganese and TDS concentrations were reported above the applicable AENV
Tier 1 (2008) guidelines (Table 1). The concentrations of chloride, sulphate , TDS
and sodium reported at the CHD culverts were lower than concentrations reported
within the upper-water bearing zone in the area. Measureable thickness of free
phase hydrocarbons were not measured in the culverts in 2008.
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In 2009 and 2010 no recordable free phase hydrocarbons were detected in the Phase
1 tank indicating free phase hydrocarbons were not captured within the Phase 1
system. Analytical results from the Phase 1 tank indicate the system is effective in
removing dissolved phase hydrocarbons from the sub surface. No measurable free
phase hydrocarbon product was observed within the Phase 2 system however,
dissolved hydrocarbon concentrations have consistently been reduced to below
analytical detection limits following treatment from sparging system. Phase 3 of the
lean oil remediation system includes removal of product from extraction wells and
culverts. Free product was removed in 2009 and 2010 via a skimmer pump, bailing
and vacuum truck.
GROUNDWATER
1. 2003 Groundwater Monitoring Report. Balzac Gas Plant. Komex International Ltd.
Report No. C25531502. Issued to Alberta Environment April 2004;
2. 2004 Groundwater Monitoring Report. Balzac Gas Plant. Komex International Ltd.
Report No. C25531603. Issued to Alberta Environment April 2005;
3. 2005 Groundwater Monitoring Report. Balzac Gas Plant. Komex International Ltd.
Report No. C25531701.. Issued to Alberta Environment April 2006;
4. 2006 Groundwater Monitoring Report. Balzac Sour Gas Plant. Worley Parsons Komex
Report No. C25531804. Issued to Alberta Environment April 2007;
5. 2007 Groundwater Monitoring Report. Balzac Gas Plant. Worley Parsons Komex.
Report No. C25531903.. Issued to Alberta Environment April 2008;
6. 2008 Groundwater Monitoring Report. Balzac Gas Plant. Worley Parsons.
Report No. C25532003. Issued to Alberta Environment April 2009;
7. 2009 Groundwater Monitoring Report. Balzac Gas Plant. Worley Parsons.
Report No. C25532103. Issued to Alberta Environment April 2010
8. 2010 Groundwater Monitoring Program. Balzac Sour Gas Plant. Worley Parsons.
Report No. C25532202. Issued to Alberta Environment April 11, 2011.
The scope of work for the annual reports included:
a. Review of the study area including physiography, topography, drainage,
hydrogeology and groundwater usage (5 km radius around plant site);
b. Assessment of local surface water flow and groundwater flow conditions at the
Site (lateral and vertical);
c. Collection of groundwater and surface water samples for assessment of quality;
d. Review of laboratory analytical results and comparison with historical data to
determine the present status of known or suspected contaminant situations; and
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e. Preparation of a groundwater monitoring summary report detailing program
results.
As testing and results are specific from year to year, only the most recent data is summarized:
a) Since September 1992, biannual monitoring of water quality at the Balzac Sour Gas Plant
has been completed by WorleyParsons (formerlyWorleyParsons Komex & Komex
International Ltd.);
b) The Site is underlain by approximately 3.0 to 6.7 m of calcareous sandy silt till and silty
clay till containing sand lenses ranging from 0.1 to 1.3 m thick. An interval of black
organic silty clay to clayey silt approximately 0.3 to 2.2 m thick has been encountered
beneath a large portion of the southeast portion of the Site. The bedrock is grey, fractured
and weathered calcareous siltstone to mudstone.
c) Groundwater flow velocities using geometric mean hydraulic conductivity values for the
upper (A-series), lower (B-series), and bedrock (C-series) water-bearing intervals were
estimated to be 2.2 m/year, 0.5 m/year and 0.5 m/year, respectively.
d) Groundwater flow within the upper and lower water-bearing intervals (till and
till/bedrock respectively) is variable. However, mounding beneath the Process area has
resulted in a radial flow pattern outward from this area. South of the main Process area,
flow in the upper groundwater-bearing zone is dominantly to the west towards McDonald
Lake. Lateral flow in the lower water-bearing zone is west toward McDonald Lake but
also west towards the Flare area. Lateral flow in the bedrock was north/northwest towards
McDonald Lake.
e) Vertical flow conditions do not appear to be completely spatially related, with a small
majority of sites having a downward gradient. Nested locations closest to the lake
exhibited upward gradients year-round, as expected for a groundwater recharged lake.
The potential for off Site migration of impacted groundwater is considered low due to the
hydraulic properties of the sediment and bedrock, existing groundwater flow directions
and prevalent hydraulic gradients.
f) The most significant chloride impacts occur in the Flare area, Former Process Ponds, and
the Evaporation Pond area. The most significant dissolved hydrocarbon impacts occur in
the Flare and Former Process Ponds area, Plant Process area and the LPG Recovery area.
g) Of the contaminants identified to date, chloride appears to have the greatest potential of
reaching McDonald Lake. Considering the age of the facility (49 years), and the
estimated groundwater flow velocities in the weathered till (2.2 m/year), total potential
lateral migration of this inorganic constituent is on the order of 100 m, assuming an
immediate release following plant commissioning. It is possible that chloride from the
Flare area has approached the shoreline. In contrast to chloride, dissolved hydrocarbons
measured down-gradient of the Flare area would have a much lower chance of reaching
McDonald Lake given their tendency to attenuate by natural means (i.e. adsorption and
biodegradation).
h) Dissolved phase hydrocarbon analyses revealed concentrations of some BTEX, PHC F1
and/or PHC F2 constituents exceeding AENV (2009) guidelines at a number of Flare and
Former Process Ponds area piezometer locations. The continued presence of significant
dissolved hydrocarbon concentrations, chloride and/or DEA indicates contaminants have
migrated laterally and somewhat vertically in this area.
i) DEA detections were reported at piezometers within the Flare and Former Process Ponds
area. These detections are generally consistent with historical concentrations, with the
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exception of piezometers where laboratory MDLs have been historically high.
Piezometers in the Flare and Former Process Ponds area are reporting increased
frequency of detectable concentrations and raised detection limits for amine parameters.
j) During 2008 excavation activities at the Unknown Sump piezometer 03-36A was
destroyed.
k) Within the Process area at piezometer 92-9A, ethylbenzene was reported exceeding
guidelines in 2009. Benzene was detected below guidelines. The occurrence of benzene
and ethylbenzene has been consistent since October 2002. At 06-47A, located west of the
KVSR Compressor Buildings, benzene, ethylbenzene, and PHC F2 impacts were reported
exceeding AENV (2009) guidelines in 2009.
l) Piezometer 06-49A (near the glycol storage tank) reported benzene, ethylbenzene, PHC
F1 and PHC F2 concentrations all exceeding AENV (2009) guidelines. At the LP Surge
Culvert, benzene and ethylbenzene concentrations were reported exceeding AENV
(2009) guidelines.
m) Measurable product thickness was not detected in 98-24A/B/C, located within the LPG
Recovery area. Very high dissolved phase hydrocarbon concentrations, though showing a
decrease compared to historical values, were reported at 98-24A. Increased values of
benzene, PHC F1 and PHC F2 at 98-24B were reported exceeding AENV (2009)
guidelines. 98-24C reported benzene, ethylbenzene and PHC F2 exceedances in 2009.
n) In the LPG Recovery Area, measurable thickness of free phase hydrocarbons was
measured, followed by the installation of a passive skimmer at this location. No
measurable thickness of product was detected in the fall 2008, or spring/fall 2009
sampling events. Dissolved hydrocarbon concentrations remained above guidelines,
however concentrations decreased from spring 2008 levels.
o) Piezometers 98-26A/C, MW-8A and MW-10A (east side of Sulphur Block) may be
monitoring inorganic impact from an up-gradient location onto the Site.
p) Concentrations of chloride, hydrocarbons, selected metals and/or amines may indicate
groundwater quality impacts at various locations.
Groundwater conditions at the Balzac Sour Gas Processing Plant (Plant) have been documented
in great detail through monitoring from 1992 to 2011. The main findings of the groundwater
monitoring include:
generally, natural groundwater quality in the Plant area is of poor quality as
indicated by high sulphate and total dissolved solids (TDS) concentrations;
groundwater flow velocities outside of the process area are low, in all three
monitored groundwater zones, primarily due to low hydraulic gradients;
groundwater quality, including in zones of contamination, is relatively stable
with small seasonal and annual variability; and
inorganic and organic groundwater impacts related to Plant operation
identified within the process area, ponds and adjacent areas are aerially stable
and have not expanded greatly over the monitoring period.
Considering the significant hydrogeological information available and the Plant
decommissioning, a major revision in the forthcoming groundwater monitoring program is
recommended. Proposed changes to the 2012 program include:
reduction in groundwater monitoring frequency;
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reduction in the number of monitoring wells to be monitored;
reduction in analytical schedule; and
concentrating monitoring activities around the process area and perimeter “C”
wells.
The proposed groundwater monitoring program would include sampling once a year in the spring,
instead of spring and fall sampling, with the number of monitored wells reduced. To address
operational issues during the 19 year history of groundwater monitoring, several monitoring wells
were installed in relatively close proximity to each other, often duplicating and/or confirming
information obtained from existing wells. These expansions to the monitoring network were
required at the time of installation. However, in view of the Plant decommissioning, some
monitoring wells are of lesser importance. It should be noted that during Plant decommissioning
and remediation of the area, several wells installed near facilities will be removed. These
monitoring wells should be properly abandoned.
Monitoring wells selected for continued monitoring should be sampled and tested as follows:
laboratory analysis for benzene, toluene, ethylbenzene, xylenes (BTEX) and
petroleum hydrocarbon (PHC) fractions F1 and F2 and amines; and
field measured parameters including depth to groundwater surface,
temperature, electrical conductivity (EC) and pH. If significant changes in EC
and/or pH are measured as compared to historical field measurements, a
sample should be submitted for routine potability analysis for the well in
question. Otherwise, laboratory testing for main ions and dissolved metals
should be discontinued.
STORMWATER MANAGEMENT
1. Balzac Gas Plant. Stormwater Management Report. Westhoff Engineering Resources
Inc. July 2003. The report was completed in support of a licence renewal application to
AENV in support of the information requested in “Attachment B –Industrial Runoff and
Surface Runoff Drainage System”. A composite drainage plan and catchment area plan
was developed, dividing the BGP into 9 10 Catchment areas. Westoff Engineering Resources Inc. Balzac Gas Plant Stormwater Management Report – WER 102-74
McDONALD LAKE
1. Sediment Sampling in McDonald Lake to Assess the Potential for Natural Hydrogen
Sulphide Generation. Matrix Solutions Inc. January 29, 2009. The objective of the
program was to assess the potential hydrogen sulphide generation from sediments in
McDonald Lake to determine if natural conditions from the lake could potentially
produce hydrogen sulphide and contribute to exceedances found at Nexen’s ambient
monitoring stations. It was concluded that “McDonald Lake appears to have the
ecological conditions conducive for sulphate reduction and the generation of hydrogen
sulphide at certain times of the year.” This was completed to try to understand the H2S
exceedances that were received at the ambient monitoring trailers during the year.
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SULPHUR HANDLING FACILITIES
1. Decommissioning and Reclamation Plan – Sulphur Handling Facility. Worley Parsons
Komex. Report No. C25531604. Issued to Alberta Environment March 2006.
The primary objective of the D&R Plan was to satisfy the specific requirements of
Amending Approval (155-01-05) and Current Approval (155-02-00) with respect to
decommisioning and reclamation of the former Sulphur Handling Facility.
2. 2006 Environmental Assessment for Management of Contaminated Sulphur And
Materials Contaminated with Sulphur. WorleyParsons Komex. Report No. C25531803.
Issued to Alberta Environment November 28, 2006
The primary objective of the assessment was to address the terms and conditions for
Sulphur Management in Sections 4.2.15 through 4.2.20 of the current operating approval
(155-02-00). This environmental assessment included the following areas:
the sulphur block
sulphur basepad;
the slater units;
the sulphur load-out area; and,
the sulphur soil pile(s).
The results of this assessment program assisted in defining remedial requirements during
remedial activities completed from 2007 to 2009 in liability subunits 18 and 25 (see
Figure 5) and the assessment will also assist in future remedial programs.
Additionally, this assessment partially addresses the regulatory requirement for a Soil
Monitoring Program (SMP) at the site. (See 2006 Soil Monitoring Program. Balzac Sour
Gas Plant. Worley Parsons. Report C25531803. November 30, 2006)
3. Confirmatory Soil Sampling Summary Balzac Plant Ditch Excavation. WorleyParsons
Report No. C25532106 – March 23, 2011. Approximately 29,000 tonnes of sulphur-
impacted soil was excavated and hauled to the BFI Canada Inc. Calgary landfill.
Exceedances of Tier 1 and/or the sulphur remediation guidelines were left in place in
many areas of the excavation. These exceedances will be re-evaluated and removed at a
future date.
4. Sulphur Pit Construction. Balzac Sour Gas Plant. WorleyParsons. Report No.
C25531902. Report still in Draft. May 9th, 2011. Approximately 3,950 m3 (in situ) of
soil was excavated during the sulphur pit excavation. Analytical results indicate
hydrocarbon and sulphur impacts remain in the excavation wall and base. Sulphur
analytical results confirmed sulphur impacts above the Tier 1 Guideline in the suspected
sulphur-impacted stockpile. Hydrocarbon results were reported below Tier 1 Guidelines
from the suspected hydrocarbon-impacted stockpile. Elevated EC and SAR results from
excavation and stockpile samples were within Site background concentrations.
5. Sulphur Pile Closure Sampling. Balzac Sour Gas Plant. Worley Parsons. Report No.
C25532001. April 11, 2011. The 2006 Soils Management Plan (Worley Parsons -
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Report No. C25531901) was issued to Alberta Environment May 31, 2007. The Soil
Management Plan included recommendations for work in the sulphur/soil stockpile area,
located south of the west sulphur block/basepad area. The recommendations included the
excavation and off site disposal of soil from the sulphur/soil stockpiles and soil adjacent
to and underlying the stockpiles. Excavation and off Site removal of the sulphur/soil
stockpile and underlying soil was conducted from October 2007 to April 2008. In total,
85,630 tonnes of impacted soil was sent to a Class II landfill in Rocky Mountain House,
Alberta. The excavation proceeded until elemental sulphur concentrations were below
500 mg/kg and total sulphur was below 4% or further excavation was restricted. The
excavation had some constraints in certain areas as pipelines, railways and roads were
encountered. Backfill material and topsoil was brought in to bring area up to grade and
seeding activities were completed to support plant growth.
6. Topsoil Stockpile Removal Sulphur Handling Facility. Balzac Sour Gas Plant. Worley
Parsons. Report C25532007. May 9th, 2011. Excavation and off Site removal of the soil
stockpile and underlying and adjacent material took place from November 12 to 26, 2008.
Excavated soil was transported to BFI Landfill south of Calgary. The mass received by
the landfill from the excavation activities was 15,086 tonnes. Analytical results indicate
sulphur impacts remain in the base pad of the former stockpile. One test pit indicated
sulphur impacts exceeding Tier 1 Guidelines extend to 0.6 mbgs . Elevated EC results
from base pad and test pit samples were reported within Site background concentrations.
OTHER
1. Condensate Loading Area (CLA) Excavation, Balzac Sour Gas Plant. Worley Parsons.
Report C25531211. Draft May 4th, 2011.
In 1999, Nexen retained Komex International to conduct a soil and groundwater
investigation designed to assess the extent of hydrocarbon impact and sulphur impact at
the Condensate Loading Area (Truck Loading). Excavation activities were conducted
from October 13 to October 31, 2000. The following activities were undertaken:
Removal of 2,500 m3 of sulphur-impacted surface soils to the sulphur
storage area.
Excavation of approximately 1,000 m3 of heavily hydrocarbon-impacted
soil and disposal at a Class II landfill.
Excavation of approximately 1,000 m3
of moderate levels of
hydrocarbon impact for soil treatment in 2001 at the Plant South landfill
location.
Excavation of approximately 2,900 m3 of soil with low level
hydrocarbon impact for treatment in 2001 at a treatment pad adjacent to
the excavation.
The excavation had some constraints in certain areas as underground firewater structures
and railways. It was determined that some impact remained due to these constraints.
Remedial guidelines have changed since this work was conducted and further assessment
requirements will be reviewed as part of the overall Plant remediation assessment
activities.
2. Unknown Sump Excavation. 02-26-29W4M, Alberta. Worley Parsons. Report
C25531802. January 30, 2009. Remedial excavation activities were conducted from
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October 2008 to December 2008. Delineation trenching activities were completed in
January 2009. In addition, groundwater that collected at the base of the excavation was
sampled six times. Approximately 6000 m3 (in situ) of the soil has been excavated. At
various locations throughout the excavation, samples failed Alberta Tier I (2008)
guidelines for BTEX, PHC F1-F4 and PAH parameters. There are remaining impacts
along the eastern wall, however further excavation was stopped due to the presence of the
roadway and underground pipelines. Further impacts were identified on the southern and
western walls. In addition, several base sampling locations failed applicable guidelines.
Further recommendations for the sump are as follows:
Excavation of the majority of the western portion of the base of the current
excavation to a depth of 4.5 mbgs;
Further excavation to the west and south to a depth of at least 4 mbgs. The
western and southern walls of the excavation should be pulled back to
remove further soils; and
Continued pumping of groundwater during excavation and sampling
activities.
Note: this is an update or interim report – this remediation is not complete
Further remediation activities will be reviewed as part of the overall Plant remediation
assessment activities.
3. Remediation Status Report. 01-08-027-27W4M/06-23-027W4M. Worley Parsons.
Report C25532006. May 9th, 2011 (In Draft). Treatment activities began in July 2002.
A total of approximately 7,700 m3 of excavated soil from 01-08-027-27 W4M (4,100 m
3)
and 06-23-027-27 W4M (3,600 m3) as well as excess drilling mud from well re-entry
activities at the Plant, was treated at the Plant from 2002 to 2009. The material was
initially land surface treated in the Temporary Treatment Area (“TTA”) next to the 02-
02-026-29 W4M well site, and piled in the backfill area adjacent to the 02-02-026-29
W4M well site once remediation guidelines at the time of sampling were met. Some
samples collected from 2002-2004 exceed current Tier 1 Guidelines for benzene and
potentially PHC F2; however, concentrations were within applicable guidelines at the
time of sampling. Salinity parameters were reported within Tier 1 Guidelines and/or
background soil values. Untreated soil was moved to the Temporary Surface Land
Treatment Area (“SLTA”) within the Plant in 2008, land surface treated, and piled at the
north end of the SLTA once Tier 1 Guidelines were met. Treated soil hydrocarbon
concentrations in analyzed samples were below Tier 1 Guidelines and thus, these treated
soils were suitable to be used as backfill/contouring material. However, given the
presence of elevated chlorides, soils should remain at the Plant and not transported back
to their original well site locations. The berms surrounding the TTA were removed in
2009.
4. Confirmatory Soil Sampling Summary. Balzac Plant Ditch Excavation. Worley Parsons.
Report C25532106. March 23, 2011. A soil investigation was conducted in 2006 to
characterize and delineate the facility related impacts within the sulphur handling facility.
The following findings of the 2006 investigation pertain to 2009 activities on Site:
• sampling locations were investigated to characterize the sediment in the drainage
ditch adjacent to the sulphur pad and loadout. Elemental and total sulphur
impacts were confirmed in the drainage ditch. Elevated electrical conductivity
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(EC), depressed pH values and elevated salinity parameters indicated significant
sulphur-related impacts. Excavation and off Site disposal of soil was
recommended. After remediation of the drainage ditch, it was recommended that
an impermeable liner be used to prevent possible future impacts to this area. An
Industrial Runoff Assessment recommended the reconstruction and remediation
of ditches in the Sulphur Handling Facility Area.
• at locations adjacent to the underground rail tank car, pH, elemental and total
sulphur impacts were confirmed by analytical results and field observations.
Excavation and off Site disposal of soil was recommended
• soil underneath the old slating units and at the Enersul Area poured sulphur was
characterized. Based on field observations and laboratory analyses, sulphur
impacts were identified including elevated EC values, acidic pH and elevated
elemental/total sulphur concentrations. Excavation and off Site disposal of soil
was recommended, with potential for in situ remediation for soil at depths below
1.0 m.
Approximately 29,000 tonnes of sulphur-impacted soil was excavated from the Site and
hauled to the BFI Canada Inc. Calgary landfill. Exceedances of Tier 1 and/or the sulphur
remediation guidelines were left in place in many areas of the excavation. These
exceedances will be reviewed as part of the overall Plant remediation assessment
activities. As recommended the surface water collection system (ditches) in the Enersul
Area was upgraded. A summary of this work includes:
Upgrades and extensions to the existing surface collection system to
improve conveyance and increase capacity to accommodate runoff.
Reconstruction clay lined and asphalt lined ditches
Removal, replacement and disposal of sulphur impacted soils below
new ditches with clean imported fill.
Installation of a low density polyethylene (LDPE) liner below all new
asphalt ditches to provide secondary containment.
5. 2009 DEA UST Removal and Replacement - Letter Report. Worley Parsons. Report
C25532107. May 10, 2011. Approximately 50 m3 (in situ) of impacted soil was
excavated from the new DEA UST. The excavation did not extend beyond the
dimensions of the new DEA tank. Soil samples were collected from the base and walls of
the excavation for characterization of the soil to establish baseline data. Excavation wall
and base soil sampling and analysis indicated the soil met the Tier 1 Guidelines for all
parameters with the exception of EC at four of the five sample locations and PHC F2 at a
single sample location. EC results reported above the Tier 1 Guideline were within
previously established Site background concentrations. Groundwater sampling during
three events indicated there are exceedances above Tier 1 Guidelines. Some parameters
fluctuate between exceeding and not exceeding parameter guidelines. These results are
consistent with groundwater conditions analyzed at nearby monitoring wells. Due to the
planned decommissioning of the Site, the new DEA UST was never put into operation.
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SUMMARY OF ENVIRONMENTAL STUDIES AT THE PLANT, BY YEAR
The following briefly summarizes the different environmental studies and/or remediation projects
that have been tracked on the BGP since 1989. The information below is provided to demonstrate
to the reader what projects have been implemented and completed, where the projects are located
on the BGP, and why the individual projects were required. All the studies and their conclusions
(which are too numerous to list succinctly) create the basis of information Nexen used to
determine the current state of the property, as summarized in Section 8 – Current State of the
Property.
1989 Activities: A hydrogeological assessment at the Balzac facility was completed. This
program involved the installation and sampling of 11 monitoring wells. Two additional wells
were installed at well sites 11-01-26-29 W4M (MW-12B) east of the plant, and 11-12-26-29
W4M (MW-13B) to the northeast. The purpose of this program was to assess groundwater quality
at these on-site and off-site locations.
1991 Activities: Completion of a follow-up assessment of hydrogeological conditions, and to
address special conditions outlined in the License to Operate. This included a review of reports
prepared by UMA Engineering Ltd., published hydrogeological maps and reports, and water well
records.
1992 Activities: a major upgrade of the groundwater monitoring network was completed. This
program included the installation of 18 additional observation wells across the plant site,
providing more comprehensive monitoring coverage. Prior to this, a geophysical reconnaissance
of the area was completed. Terrain conductivity and magnetometer surveys were conducted near
the buried south landfills, south of the main process area, and down gradient of North and South
Cooling Tower Blowdown Ponds.
Terrain Conductivity and Magnetometer Survey – Petrogas Processing Plant
A geophysical survey of the Blowdown Pond Area and Landfill Area Sulphur Block Storage Area
was conducted. The survey was conducted to better assess potential soil and groundwater
contamination issues. This program is the precursor to starting detailed soil and groundwater
investigations at the Balzac Plant. Komex Report: Terrain Conductivity and Magnetometer Survey at the Petrogas Processing Plant, Balzac Alberta A92-2553-2
1993 Activities: four additional monitoring wells (93-15A/C and 93-16A/C) were installed on
the west side of McDonald Lake. The purpose of these wells was to further define local
background conditions. The piezometers were installed in nested configurations, including one
shallow and one deep, to assess vertical flow conditions at each location.
1994 Activities: a geophysical survey was completed in the vicinity of the sulphur block storage
area. Subsequently, in July 1994, bedrock monitoring wells (94-17C, 94-18C, and 94-19C) were
installed at the plant site to assess groundwater flow conditions and water quality in the deeper
water-bearing horizons. Later in 1994, a geophysical investigation was conducted south of the
main process area to assess the extent of potential subsurface impact associated with a number of
former waste water and surface runoff ponds. This study was followed up in March 1995 with a
soil and sludge sampling program in the Evaporation Pond, Holding Pond, Hydrocarbon Burn Pit,
Chemical Pond, and Filter Cake Pond.
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A stable isotope investigation of soil and groundwater in and around the plant ponds, sulphur
storage, and sulphur loading areas was also completed. The purpose of this investigation was to
determine the source of anomalous groundwater sulphate concentrations at the Balzac site (i.e.,
natural versus industrial).
Upgrade of Runoff Water Control around Sulphur Block Area
This project consisted of installing lined ditches around the sulphur block and sulphur basepad
and construction of a lined acidic water collection pond and secondary containment for caustic
treating facilities. This was in response to AENV concerns on the handling of acidic runoff water
in Sulphur Block Area. An activity change application was submitted to Alberta Environment and
approved. The work stretched over a two-year period (1994-1995). Petrogas Report Entitled: Activity Change – Upgrade of Runoff Water Control around Sulphur Block Area – Central File 001-20
Stable Isotope Study
A Stable Isotope investigation of soils, groundwater and vegetation was conducted in 1994 in
various plant ponds and the Sulphur Storage Area. The purpose of the investigation was to
determine the source of anomalous groundwater sulphate conditions (industrial vs. natural). The
report suggested a low degree of industrial impact from plant operations was evident. Komex Report: Stable Isotope Study at the Petrogas Processing Facility KI94-2553-5
Terrain Conductivity Survey – Petrogas Processing Plant
In 1994 a Geophysical survey of the Sulphur Block Storage Area was conducted. The survey was
conducted to better assess potential soil and groundwater contamination issues. The objective of
the program was to delineate in a plan view shallow inorganic soil and/or groundwater
contamination. This program was the precursor to starting detailed soil and groundwater
investigations at the Balzac Plant. Komex Report: Terrain Conductivity Survey at the Petrogas Processing Plant, Balzac Alberta A94-2553-6
1995 Activities: a piezometer (95-20A) was installed south of piezometer nest 92-8A/B.
Temporary piezometers 96-21A and 96-22A were subsequently installed in 1996 down gradient
of the North and South Cooling Tower Blowdown Ponds.
1995 Geophysical Program and Limited Soil Sampling Investigation This program was conducted to fulfill plant operating licence requirements. The survey was
conducted to better assess potential soil and groundwater contamination issues. The geophysical
program covered the entire south end of the Plant. This geophysical program, in conjunction with
the two previous geophysical investigations (1992 &1994), covered the majority of the Balzac
Plant Site. Komex Report: 1995 Geophysical Program and Limited Soil Sampling Investigation – Petrogas Processing Ltd. KI95-2553-6
1996 Activities: the first soil monitoring program (SMP) was conducted at the Site. Subsequent
to submission of the monitoring program report to AENV, a management plan was developed to
address identified soil contaminant issues over time. It was followed by a Remedial Program
Work Plan.
Effects of Acid Conditions on Element Distribution beneath a Sulphur Basepad
A CAPP research project entitled “Effects of Acid Conditions on Element Distribution beneath a
Sulphur Basepad” was completed in 1996. (West sulphur basepad) The program consisted of
installing two groundwater wells and the collection of six soil samples from different locations
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under the basepad. Results indicated that the pH in the soils immediately under the west sulphur
basepad had not been impacted in the 35 years of operation. Komex Report: Effects of Acid Conditions on Element Distribution Beneath a Sulphur Basepad KI96-4374
Study of Soil, Sludge and Groundwater Conditions around the Blowdown Ponds
This report was submitted to fulfill a plant operating licence requirement regarding the plant
blowdown ponds. The program was to address the integrity of the liner material in the blowdown
ponds and determine if the ponds posed a risk to soils and groundwater and options to upgrade the
ponds if necessary. The report concluded that it did not appear that shallow groundwater had been
adversely impacted from the blowdown ponds. Komex Report: Study of Soil, Sludge and Groundwater Conditions Around the Blowdown Ponds at the Balzac Gas Plant 2553-7-2
1996 Soil Monitoring Program
The 1996 soil monitoring program was conducted to fulfill a condition in the plant operating
licence. The soil monitoring program consisted of the following activities:
Soil sample collection at 19 locations around the facility and one background location.
Sample analysis for parameters as specified in the plant operating approval.
Data summary and presentation, incorporating previous investigations.
The report summarized the nature of impact at specific locations. Komex Report: 1996 Soil Monitoring Program – Balzac Gas Plant – Canadian Occidental Petroleum Ltd. KI96-2553-7-3-6
1997 and 1998 Activities: Initiation of clean-up at the Hydrocarbon Burn Pit, the Filter Cake
Pond, the Chemical Pond, and the Drilling Mud Pit.
In 1998 an integrated soil and groundwater investigation program was completed. The
investigation targeted areas where additional groundwater monitoring was required (e.g.
installation of a bedrock piezometer near the flare area) and locations at which further soil quality
characterization was warranted. Twelve piezometers were installed as part of this program. This
program identified a number of previously unknown issues, including: free hydrocarbon product
contamination in the LPG recovery area and soil contamination in two former flare pits southwest
of the bone yard.
Remediation of soil adjacent to the southeast Process Pond commenced. This area had previously
been contaminated by a release from the Plains Midstream (Federated Pipelines/Anderson were
operators of this pipeline in or around 1998) condensate pipeline, which passes through the area.
Monitoring well 98-29A was installed in the upper water bearing zone to monitor success of the
remediation program. This well is not considered part of the current Nexen monitoring network.
A 5 year Environment Management Plan (EMP) for the Plant was developed. The Management
Plan for the Plant was updated in 2000. Since that time, many of the recommended activities in
the Plan have been implemented and additional site assessments completed. In view of the
progress made, and new information obtained, a revised EMP, extending to 2005, was developed
in 2001.
Soil Quality Adjacent to the Sulphur Contaminated Soil Pile
A study was undertaken in 1997 to determine if there were any impacts due to storing sulphur-
contaminated soil at the Balzac Gas Plant. The sulphur soil pile was generated in 1995 when
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remediation activities around the sulphur block and basepad during the Sulphur Block Runoff
ditches and pond construction. The report indicated that acidic impact beneath the basepad had
been limited to the upper 0.3 meters of the soil profile. The lack of acidic impact suggested that
adequate soil buffering capacity is present in the existing soils after 33 years of operation. Komex Report: Soil Quality Adjacent to the Sulphur Contaminated Soil Pile at the Balzac Gas Plant – 2553-8-2
Remediation of the Hydrocarbon Burn Pit, Filter Cake Pond, Chemical Pond and Ditches
Remediation plans for the on-site Hydrocarbon Burn Pit and ditches, Filter Cake Pond, Chemical
Pond were developed in 1997. The remediation of the Hydrocarbon Burn Pit and ditches began
late in 1997. Heavily contaminated sludge was removed and disposed of at a Class II landfill.
Hydrocarbon contaminated soils were assessed and a decision to spread and land treat the soils
was decided on. These activities were implemented to reduce contaminant levels to below Alberta
Tier I guidelines in the vicinity of the pit and ditches.
The remediation of the Filter Cake Pond and Chemical Pond began in 1998 along with the
completion of the Hydrocarbon Burn Pit and ditch remediation. Again some heavily contaminated
sludge was removed and disposed of at a Class II landfill. The less contaminated sludge was land
spread and land farmed in place. Komex Report: Hydrocarbon Burn Pit, Filter Cake Pond and Chemical Pond Remediation at the Balzac Gas Plant - KI - 2553-10-2
Remediation of the Drilling Mud Pit The remediation of an old Drilling Mud Pit located on the plant site was also completed during
1998. Komex Report: Hydrocarbon Burn Pit, Filter Cake Pond and Chemical Pond Remediation at the Balzac Gas Plant - KI - 2553-10-2
Slop Tank Remediation – Flare Area
During the 1997 upgrade of the plant’s Flare Area, contaminated soil was encountered. During
this upgrade it was decided to remediate the footprint of the new installation. The area was
excavated to a depth of approximately 2.5 meters. The contaminated material was deemed land
treatable and this contaminated material was incorporated into existing land treatment activities
from the Hydrocarbon Burn Pit and ditches, Chemical Pond and Filter Cake Pond. Komex Report: Hydrocarbon Burn Pit, Filter Cake Pond and Chemical Pond Remediation at the Balzac Gas Plant - KI - 2553-10-2
Screening Level Human Health and Ecological Risk Assessment
During 1998, a “Screening Level Human Health and Ecological Risk Assessment” was initiated.
The risk assessment was developed to look at three specific areas of the plant: S.E. Process Area
Runoff Pond, Holding Pond, Evaporation Pond, and it looked at McDonald Lake to a lesser
extent.
In general the assessment found that there would be no unacceptable risks to human health in an
industrial or parkland setting. The ecological risk assessment indicated that there are ecological
risks associated with certain identified chemicals of concern. The next steps included actions to
try and minimize ecological risks. Komex Report: Screening Level Human Health and Ecological Risk Assessment (Ponds) Wascana Energy - Balzac Gas Plant - KI 98-
4683
North Flare Pit and South Flare Pit Investigations
Contamination was identified in the vicinity of Wellsite 2-2-26 (located on Plant Property) during
the 1998 Integrated Soil and Groundwater Program. Based on this Program a delineation
program was initiated in 1999.
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1998 Integrated Soil & Groundwater Investigation Program
This 1998 Integrated Soil and Groundwater Program were conducted to supplement the 1996 Soil
Monitoring Program and in turn help fulfill plant operating licence requirements.
Correspondence with Alberta Environment and Alberta Energy and Utilities Board and an audit
conducted by both parties identified the need for additional soil and groundwater monitoring. The
additional sampling brought forth some specific areas of concern, some of which are being
addressed in various remediation and investigation programs now being conducted at the plant. Komex Report: 1998 Integrated Soil and Groundwater Investigation Program - Wascana Energy Inc. KI-2553-9 T01/T02
Lean Oil Collection System – LPG
During the 1998 Integrated Soil and Groundwater Program, the presence of free product (Lean
Oil) was discovered. A delineation program was developed and implemented in October 1998.
The scope of work consisted of the following:
To identify the extent of the free product in the LPG Area;
To establish the approximate thickness of the free product in the LPG Area; and,
To collect data to support the development of remedial options. Komex Report: Delineation of Free Product Contamination in the LPG Recovery Area – Balzac Gas Plant KI-2553-10-5
1999 Activities: the Former 2-2 North and South Flare Pits were remediated. During this
remediation, approximately 4600 m3 of impacted soil and sludge was excavated; 1100 m
3 was
treated at a thermal desorption unit and later backfilled into the excavations; and 3500 m3 was
spread in a designated on-site treatment area and later backfilled into the excavations.
A soil and groundwater investigation program was undertaken to better delineate known
contaminant situations in the Condensate Loading Area and the Flare Area. The investigation
involved drilling twelve test holes to delineate previously identified hydrocarbon contamination
in soil. Temporary mini-piezometers were installed in four of the test holes to evaluate potential
groundwater impacts. Subsequent remedial work was conducted that included excavation in
2000, and in 2001, the treatment of approximately 4,000 m3 of impacted soils. A lean oil plume,
with an estimated volume of 81 m3 and extending over an approximate area of 3,100 m
2, was
delineated beneath and down gradient of the LPG Recovery Area of the Plant. In 1999, the first
of a three-phase remediation plan was implemented to begin recovery of the mobile free product.
Phase I consisted of a free product recovery trench that was installed within the plume core, in an
open area immediately south of the LPG Recovery facilities. An additional well (LPG-1) was
installed in the LPG Area in August 1999 and has been used to recover additional free product.
Delineation and Remediation of North Flare Pit near Well site 2-2-26 Remediation plans for the on-site 2-2 North Flare Pit were completed in the spring of 1999 and
remediation began in the fall of 1999. The 2-2 North Flare Pit was used to collect a variety of
waste materials from the plant in the early to mid-years of the plant. Approximately 700 m3 of
heavily contaminated sludge was removed from the North Flare Pit and sent for treatment at a
thermal desorption unit (incinerate soil to remove contaminants). In addition to this process
approximately 3,500 m3 of lightly contaminated soil was spread in a designated on-site treatment
cell and treatment was initiated in 1999 and completed in 2000. The first thing that was initiated
was a treatability study to determine if the contaminated soil could be land treated. After the
studies it was decided to use thermal desorption (incinerate) to decontaminate the more heavily
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contaminated sludge. These treated soils were then returned to the Gas Plant for use as fill
material. Komex Report: Soil and Sludge Remediation Program of Flare Pits at Wellsite 2-2 C25531204
Delineation and Remediation of South Flare Pit near Well site 2-2-26
Remediation plans for the Well site 2-2-26 South Flare Pit were completed in the spring of 1999
and remediation began in the fall of 1999. Approximately 420 m3 of heavily contaminated sludge
was removed from the South Flare Pit and sent for treatment at a thermal desorption unit
(incinerate soil to remove contaminants). Komex Report: Soil and Sludge Remediation Program of Flare Pits at Well site 2-2 C25531204
Lean Oil Collection System – LPG
During the 1998 Integrated Soil and Groundwater Program the presence of free product (Lean
Oil) was discovered. In 1999 a Remedial Options Analysis was proposed to address this
contaminant concern. The analysis looked at the following groundwater remediation issues:
1. Understand (characterize) the problem at the site;
2. Assess the risks posed by the problem;
3. Set remedial goals for the site;
4. Review and select the most appropriate remedial options;
5. Pilot scale test(s) of selected remediation option or options;
6. Implement the optimal remediation program at the site; and,
7. Monitor results, modify systems. *Komex Report: Remediation Options Analysis LPG Recovery Area – Balzac Gas Plant KI2553-11-02 (Draft)
The Lean Oil Collection System Remediation program was installed in 1999 after free product
was discovered in the groundwater during the 1998 Integrated Soil and Groundwater
Investigation Program. Trenches and Collection Points were installed to collect free product (lean
oil) from the groundwater in the LPG unit. Komex Report: Installation and 1999 Performance Review LPG Recovery Area Free Phase Recovery System C25531106
2000 Activities: Phase II of the remediation included installation of a trench and gate system
between the two sets of LPG Storage Tanks down gradient of the free product plume. Continuous
operation of Phase II began in May 2001. The system was designed to direct groundwater flow
through the permeable collection trench and into a product separation gate, which traps floating
hydrocarbon. In 2001, only free product sheen was detected in the product separation gate,
therefore no free product removal was required. Analytical results for groundwater samples have
been collected since 2001. Benzene and total xylenes concentrations above the respective AENV
guidelines have been detected in the Phase II product separation gate system. However,
concentrations exiting the system through the re-infiltration gallery are below analytical method
detection limits.
A plant-wide program of UST removals was conducted in the summer of 2000. A total of four
tanks were removed, and impacted soils were delineated, and excavated where possible.
North and South Blowdown Pond Clean-up
Due to deteriorating water quality in North and South Blowdown Ponds a sludge sampling
program was conducted in 2000. The sampling discovered some contaminants and natural
elements (organic) in the sludge. The North Blowdown pond sludge contained some heavy end
hydrocarbons (unknown source) and this material was sent to a landfill. The South Blowdown
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contained a substantial amount of organic matter which may have contributed to an ammonia
nitrogen issue in the water. This sludge was removed from the South Blowdown Pond and added
to the land treatment activities with the added organic matter aiding in the remediation process.
Underground Petroleum Storage Tank Investigation
To facilitate construction of the Balzac Power Station an environmental investigation was
conducted in the fall of 2000. During the investigation phase hydrocarbon impact was discovered.
A program was immediately set up to delineate and formulate a remediation plan to address the
contamination. Three former underground tanks (diesel/gasoline) were located in the vicinity of
this planned construction. Approximately 3600 m3 of hydrocarbon contaminated soil was
removed to a temporary bio-treatment cell. Land treatment of this impacted soil was undertaken
and completed in 2001. Komex Report: Balzac Parking Lot – Underground Petroleum Storage Tank Investigation – File No. 25531208
Condensate Loading Area Remediation
The delineation phase of this project began in 1999 with approximately 12 soil borehole locations
and 4 temporary mini piezometers (groundwater well) being installed. The contamination plume
was mapped and a remediation plan developed. The Condensate Loading Area remediation began
in 2000. The plan was to first excavate approximately a one-meter lift of sulphur contaminated
soil and stockpile on Sulphur Contaminated Soil Pile. Once the program began it was determined
that all the condensate loading facilities would be removed to ensure a full clean-up of the area.
This resulted in the removal of the loading structure and underground facilities in the immediate
area of the loading facility. Approximately 1000 m3 of soil was removed to the Temporary Land
Treatment Cell located on the Plant Site. Approximately 3000 m3 of soil was treated in place at
the Condensate Loading Area. The soil contained light end hydrocarbons and it was successfully
remediated during the 2001 season. The material was deemed clean per Alberta Tier I guidelines
and a portion (1000 m3) was stockpiled adjacent to the South Balzac Landfill.
Komex Report: Balzac Gas Plant – Delineation of the Flare Area and Condensate Loading Area – File No. C25531104 Draft
Komex Report: Balzac Gas Plant – Condensate Loading Area Remediation – File No. 25531211 Draft
Underground Tank Removals
Four underground tanks/sumps located on the Plant were removed in 2000. Remediation activities
were undertaken on 3 of the 4 tanks/sumps removed. The tanks were as follows: KVSR Oil
Sump, RDS Sales Gas Oil Tank, L.P. Surge Rerun Sump and Site ‘G’ Compressor Drain Tank
(contamination not present). These underground tanks/sumps were replaced with aboveground
facilities. The contaminated soil was removed and tested to determine suitable disposal or
treatment options. The KVSR Oil Sump and RDS Sales Gas Oil Tank contained heavy end
hydrocarbons and off-site disposal was undertaken. The L.P. Surge Rerun Sump contaminated
material (900 m3) contained lighter end hydrocarbons and an on-site treatment cell was
constructed to treat this material. Komex Report: Balzac Gas Plant – Underground Tank Removals – File No. C-2553-1206
Land Treatment Activities
Land treatment activities began in 2000 to deal with contaminated soils from various remediation
projects. The table below summarizes this information. These soils were tested extensively during
the remediation process and on completion in 2001. Activities occurred at a temporary land
treatment location within the BGP. Komex Report: Balzac Gas Plant – Landtreatment Activities – File No. C-2553-1211
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Soil Source Contaminated Soil/Sludge Contaminant Main Parking Lot 3600 m
3 Diesel/Gasoline
LP Surge Rerun 900 m3 Condensate
Condensate Loading 4000 m3 Condensate
KVSR Storage Tank 300 m3 To BFI Lube Oil
South Blowdown Pond 1000 m3 Not Contaminated
Sulphur Contaminated Soil Bench Scale Studies
In 2000, soil samples were sent to laboratory to begin a series of studies to determine a suitable
method for extracting elemental sulphur from soil. The bench scale study looked at separating
sulphur/soil by three different methods of gravity concentration. Heavy media separation was
determined to work the most effectively.
Lean Oil Collection System – LPG
The Lean Oil Collection System was expanded in 2000. A trench and gate system was installed
late in 2000. The trench and gate system provided complete hydraulic containment of the free
product plume and treat the dissolved phase. This was the second phase of the system which was
initially installed in 1999. Komex Report: 2000 Performance Review Phase I and Phase II Installation - LPG Recovery Area Free Phase Recovery System
C25531212
After review of the Lean Oil Collection System operations had taken place, another report was
generated entitled “Proposed Expansion of the Free Product Recovery System LPG Recovery
Area – Balzac Gas Plant”. The scope of this report was as follows:
Proposed Phase II Expansion;
Proposed Phase III Expansion; and,
Continued Operation of Phase I operations. Komex Report: Proposed Expansion of the Free Product Recovery System LPG Recovery Area – Balzac Gas Plant C25531205
2001 Activities: The parking lot area was designated for construction of a portion of the Balzac
Power Station. Three USTs containing diesel and gasoline located north of the Plant parking lot
were removed in 1994, and soil quality delineation and remediation programs were implemented
in 2000 to ensure that the site was suitable for Balzac Power Station construction.
During 2001, construction of the new Balzac Power Station was completed in the northeast corner
of the Plant site. This required the installation of a new fuel gas pipeline north of the condensate
storage tanks, and a freshwater pipeline along the north-south access road. Both of these
installations uncovered previously unknown environmental impacts on the property. Condensate
impact was encountered along the fuel gas pipeline path, and a previously unidentified landfill
east of the Evaporation Pond was discovered along the planned route of the water pipeline.
In November 2001, a full characterization and delineation of the North and South Landfills was
completed. Additionally, the planned pathway for the freshwater pipeline necessitated the
removal of two aboveground methanol storage tanks. A remedial excavation and soil treatment
program was conducted on the underlying methanol impacted soils.
A Risk Assessment of the three former process ponds was initiated in 1998 and updated in 2001.
The Evaporation, Holding, and Southeast process ponds were sampled and evaluated for their
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potential to adversely impact aquatic life due to salinity or metals. In December 2002, removal of
the surficial sediment layer from the Southeast Process pond was completed.
In December 2001, a piezometer replacement program was conducted. Three piezometers (01-
33A, 01-34A, and 01-35A) were drilled to replace MW-2A, 92-10A, and MW-7A, respectively;
the first two were removed to allow for construction of the Balzac Power Station. A further
piezometer (98-26A) was abandoned and re-drilled.
Balzac Gas Plant – North and South Landfill Characterization Program
The objective of this program was to characterize the contents of two former landfill sites located
on the Balzac Gas Plant property. The landfills had been previously identified and a preliminary
characterization program had been completed. The objective of the program was collect enough
information to develop a remediation plan.
The North Landfill contained filters, wood, crushed drums, catalyst, asbestos, tires, tubes from
reboilers, small amounts of sulphur and hydrocarbon contamination. The approximate volume of
the North Landfill was 9000 m3.
The South Landfill contains 5 separate cells which were in operation from 1967 to 1984. Again
the South Landfill site contains general plant refuse including: filters, pipes, timbers, catalyst,
small amounts of sulphur and hydrocarbon contamination. The approximate volume of the South
Landfill is 8000 m3.
Komex Report: Balzac Gas Plant – North and South Landfill Characterization Program – File No. 25531309 Komex Report: Balzac Gas Plant – 1998 Integrated Soil and Groundwater Investigation Program Volume 1 of 2 - File No. KI-2553-9
T01/T02 (Page 50 and Photos Section)
Sulphur Contaminated Soil Remediation Technology
To further progress the sulphur bench scale testing that had begun in 2000, a temporary Field
Pilot Project was implemented in the fall of 2001. The pilot ran for approximately six weeks. The
purpose of the pilot was to collect data to assess whether this technology was suitable to remove
elemental sulphur from soil. The pilot plant operated as planned. Process Research Associates Ltd. Report: Project No. 00-05207
Land Treatment Activities
Land treatment activities continued through 2001 and they were completed in the fall of 2001.
These activities dealt with contaminated soils from various remediation projects as outlined in the
2000 Land Treatment Activities. Two areas were set aside for land treatment activities –
Condensate Loading Area and over the South Landfill Area. Komex Report: Balzac Gas Plant – Land treatment Activities – File No. C-2553-1211
Methanol Tank Investigation/Remediation – LPG Unit
Remediation work had begun in this general area in 2001. The Field Methanol Tank was removed
in 2001. During the investigation phase approximately 1000 m3 of methanol impacted soil was
discovered and the impacted soil was segregated into the same land treatment area as the
Condensate Loading Area material. The remediation of the methanol area was combined with the
Condensate Loading Area Remediation and both were completed in the fall of 2001. Komex Report: Balzac Gas Plant – Methanol Storage Tank Investigation - File No. 25531306
Field Inhibitor Tank Investigation/Remediation – LPG Unit
Remediation work had begun in this general area (Condensate Loading Area) in 2001.
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The inhibitor tank and sump were also removed in the fall of 2001. The inhibitor tank remediation
activities were transferred to 2002 as the soil was determined to have heavier end contaminants
and this required landfill acceptance. Komex Report: Balzac Gas Plant – Inhibitor Tank Remediation – File No. 25531408
Lean Oil Collection System – LPG
The Lean Oil Collection System was run throughout 2001. Komex Report: 2001 Performance Report - Free Phase Recovery - LPG Recovery Area C25531303
Hydrocarbon Monitoring Results Waterline Installation – Balzac Power Station
During the construction of the water supply line to the Balzac Power Station, a previously
unknown landfill was discovered. The landfill was delineated - see above “Balzac Gas Plant –
North and South Landfill Characterization Program”. Komex Report: Hydrocarbon Monitoring Results Waterline Installation C25531307
Hydrocarbon Monitoring Results Fuel Gas Line Installation – Balzac Power Station
During the construction of the fuel gas supply line from the Balzac Gas Plant to the Balzac Power
Station two pockets of contaminated soil was encountered. The line intersected an area of known
contamination “Lean Oil Collection System – LPG” and another area that was addressed in 2004
activities “L.P. Surge Review – Remediation Plan”. Komex Report: Hydrocarbon Monitoring Results Fuel Gas Line Installation C25531307
Arsenic Detections in the S.W. Dugout
A report was issued in 2001 on the elevated arsenic values in the S.W. dugout. It was
recommended that further sampling be conducted on the dugout which was done approximately
every two to three weeks during the summer 2001. Arsenic values were below Canadian
Livestock Watering Guidelines for the first part of the year and again in the fall the arsenic values
went above the guidelines. The resident was notified immediately. They removed cattle upon
verbal discussions. Komex Report: Arsenic Detection’s in S.W. Dugout – Review and Recommendations C25531302
2002 Activities: In April 2002, a soil quality investigation was conducted around the main
electrical sub-station during plant turnaround. Trace amounts of PCBs (polychlorinated
biphenyls) and above AENV criteria heavy-end hydrocarbons were noted. Due to the complexity
of overhead and underground utilities, complete soil remediation is not an option until Plant
closure.
During August 2002, the field inhibitor storage tank and sump, located south of the LPG bullets,
were removed. Approximately 300 m3 of the surrounding impacted soil was excavated and
disposed of at the BFI landfill in Calgary.
Lean Oil Collection System – LPG
The Lean Oil Collection System was operated throughout 2002. Trenches and Collection Points
were installed three years ago to collect free product (lean oil) from the groundwater in the LPG
unit. An air-operated pump collected the lean oil/groundwater and it was pumped to a 400 Bbl.
tank SV 19-23 located in the LPG.
The second phase of the system was installed in December of 2000 and it continued to run
throughout 2002. This phase consisted of a trench and gate collection system which should cut-
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off the flow of lean oil and any minor contaminants in the groundwater. One culvert (between
tank #5 and #6) acted as a collection point and one culvert (under tank #7) had a continuous
supply of air injected into the culvert. (N.B. This remediation system was featured in a
“Remediation Technologies Symposium” entitled “In-Situ Containment & Treatment of a Free
Phase Hydrocarbon Plume Beneath Plant Infrastructure” in Banff, October 2002. The paper was
presented by Mike Brewster of Komex International Ltd.) Komex Report: Installation and 1999 Performance Review LPG Recovery Area Free Phase Recovery System Komex Report: 2000 Performance Review Phase I and Phase II Installation - LPG Recovery Area Free Phase Recovery System
C25531212 Komex Report: 2001 Performance Report - Free Phase Recovery - LPG Recovery Area C25531303
Field Inhibitor Tank Remediation – LPG Unit
Remediation work had begun in this general area (Condensate Loading Area) in 2001. The
inhibitor tank and sump were also removed in the fall of 2001. The inhibitor tank remediation was
completed in the summer of 2002. Remediation consisted of removing contaminated soil for
testing to determine remediation options. The inhibitor contained some heavy end contaminates
that were not amenable to land treatment. The contaminated soil was temporarily stored just plant
south of the propane/butane truck loading area. The testing determined that off-site disposal was
the suitable disposal option. The contaminated soil was sent to the BFI landfill. Komex Report: Balzac Gas Plant – Inhibitor Tank Remediation – File No. 25531408
Sulphur Vat Pond Sludge (South of Wellsite 2-2)
Sludge from the Sulphur Vat Pond was evaluated and excavated and stored until 2003. (See
below)
Temporary Land Treatment Area (Adjacent to 2-2-26)
Contaminated soils from two pipeline failures (1-8-27 & 16-3-25) and a flare knockout
underground tank failure remediation project (6-23-27) were brought to the plant for land
treatment. The soils were treated throughout the summer and fall of 2002. The contamination
was condensate based and it was shown to be quickly treated using heavy equipment (tractor with
rotovator and lift removal with a dozer). Worley Parsons Komex Report: Remediation Status Report 01-08-027-27 W4M and 06-23-027-27 W4M. File No. C25532006. (In
Draft).
PCB Soil/Debris Disposal from new Electrical Substation Revamp at Turnaround During the 2002 turnaround, low level PCB’s were discovered in the soil and some concrete
during a new substation upgrade. The concrete pads that housed the old transformer and capacitor
were removed; testing confirmed low level PCB’s were present on some of the concrete pads. A
new grounding grid was required around the new substation. To facilitate the grid installation a
trench was required. Soils around the substation were tested and low levels of PCB’s were
discovered in some areas.
The majority of the samples contained non-detect levels of PCB’s. The soil was transferred to soil
bins and off-site disposal was arranged. Komex Report: Balzac Gas Plant – PCB Soil Sampling and Delineation – File No. C25531403
Arsenic Detection’s in the S.W. Dugout
The recommended further sampling program continued through the summer 2002. Arsenic
values were below Canadian Livestock Watering Guidelines for the first part of the year and
again in the fall the arsenic values went above the guidelines. Resident notification again was
undertaken.
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2003 Activities: Phase III of the remediation system was designed to remove free product from
multiple vertical wells within the LPG area lean oil plum. Three new extraction wells (LPG-2,
LPG-3, and LPG-4) were installed. A Skimmer System was installed and rotated between the
three vertical wells on a regular basis throughout 2003 and 2004, removing the entire free product
thickness from wells LPG-2 and LPG-4.
Piezometers 92-12A, 98-24A, and 93-15C were replaced in June 2003.
In response to questions raised by AENV in a letter dated November 26, 2002, Komex issued an
‘Environmental Summary Update’ for the Balzac Gas Plant in June 2003, updating environmental
work completed and planned in the 5-year EMP. After review, AENV requested a further update
of more recent remedial work conducted in 2003/2004 (AENV letter dated March 3, 2004),
specifically including areas associated with the Sulphur Handling Facility. An ‘Environmental
Summary Update” was issued to address these requests, and update requirements of Section 5.3.2
of the Approval (AENV Approval No. 155-01-08). A ‘2005 Environmental Summary Update’
was prepared in July 2005, after a meeting and site tour was conducted with AENV.
A Flare area delineation program involving both soils and groundwater was conducted in
November 2003 as a continuation of the program initiated in September 1999. The purpose of the
program was to determine the lateral extent of the impact between the Flare area and McDonald
Lake. The program involved 14 soil sampling boreholes and the installation of seven piezometers;
one piezometer nest (03-39A/B) and five single piezometers (03-36A, 03-37A, 03-38A, 03-40A,
and 03-41A.
Remediation and reclamation of the North Landfill cell was completed in December 2003. In
addition, one down gradient piezometer was added to the Plant monitoring network (04-42A).
North Landfill Remediation
The North Landfill remediation was completed in 2003 except for topsoil dressing and seeding
which occurred in 2004. The area that the North Landfill was situated in was characterized and
delineated in environmental reports as listed below. Komex Report: Balzac Gas Plant – North and South Landfill Characterization Program – File No. 25531309
Komex Report: Balzac Gas Plant – 1998 Integrated Soil and Groundwater Investigation Program Volume 1 of 2 - File No. KI-2553-9
T01/T02 (Page 50 and Photos Section) Komex Report: Balzac Gas Plant – North Landfill Closure Report - File No. 25531505
Sulphur Vat Pond Sludge (South of Wellsite 2-2-26)
Approximately 6,926 tonnes of sludge from the Sulphur Vat Pond was sent to the BFI landfill in
2003. This material was removed from the Sulphur Vat Pond in 2002 and it was then evaluated
and stored temporarily over old Balzac South Landfill until a disposal option could be
determined.
Expand LPG Recovery System and Investigate Groundwater Treatment
Three additional collection points (perforated wells) for capturing contaminated groundwater
were completed in 2003 (Phase III work). The option of treating contaminated groundwater and
releasing it back to environment was assessed. Komex Report: Balzac Gas Plant – 2002 Performance Report – Free Phase Recovery System LPG Recovery Area Balzac Gas Plant –
File No. C25531407 – Draft Report
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Flare Area Review – and Remediation Plan and/or Risk Assessment
The existing groundwater contaminant situation was reviewed and an expanded assessment
program was developed. The expanded assessment program included an extensive soil
investigation and groundwater monitoring network that were completed in November 2003 to
help develop a monitoring and remediation plan. Komex Report: Balzac Gas Plant – Delineation of the Flare Area and Condensate Loading Areas – File No. C25531104 – Draft
Report
Komex Report: Balzac Gas Plant – 2003/2004 Soil and Groundwater Investigation in the Flare Area - File No. C25531504
Waste Storage Area (Adjacent to 2-2-26)
Contaminated soils from two pipeline failures (1-8-27 & 16-3-25) and a flare knockout
underground tank failure remediation project (6-23-27) were brought to the plant for land
treatment in 2001. The contamination was condensate based and it was shown to be quickly
treated using heavy equipment. The area is a waste storage pad approved to store waste but its
not a Land Treatment Area (LTA). The area is a double lined collection area approved by ERCB
for containment. Waste is then hauled off quarterly/annually depending on volumes Worley Parsons Komex Report: Remediation Status Report 01-08-027-27 W4M and 06-23-027-27 W4M. File No. C25532006. (In Draft).
Environmental Assessment of Soils for Proposed Sulphur Forming Facilities
AMEC Environmental conducted a subsurface soil assessment in an area designated for the
construction of a new sulphur forming facility. Completed – AMEC Earth and Environmental Ltd. February 2003 – CE02621
2004 Activities: In December 2004, Nexen submitted a Decommissioning and Reclamation plan
to AENV designed to remove the existing sulphur area slating units and replace them with three
enclosed GXM2 sulphur granulator units. Remediation and reclamation planning was an integral
component of the plan. In March 2006, the plan was updated and resubmitted to AENV.
Updated Risk Assessment (3 Ponds)
The Updated Risk Assessment Report was completed during 2004. Komex Report: Balzac Gas Plant – Updated Risk Assessment – C25531301 June 2004
Sulphur Handling Area - Demolition & Remediation Plan for Enersul Slating Facilities
A Decommissioning and Reclamation plan was developed for the Sulphur Handling Area. This
plan was submitted to Alberta Environment per Approval Number 155-01-05.
The Approval (155-01-05) required the following items to be submitted by December 1, 2004 in
regards to the Sulphur Handing Area:
Industrial Runoff Control System Upgrade. (5.4.1)
Decommissioning Plan (6.2.1)
Land Reclamation Plan (6.3.1) Komex Report: Balzac Gas Plant – Decommissioning and Reclamation Plan – Sulphur Handling Facility - File No. C25531604
LPG Recovery System
The Phase III groundwater collection system continued to operate. To ensure Nexen is operating
within our remediation objectives, the LPG Recovery System was re-evaluated. Monitoring of the
LPG Recovery System continued. Komex Report: Balzac Gas Plant – 2003/2004 Performance Report – Lean Oil Remediation System – LPG Recovery Area – File No.
C25531605
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Flare Area Review – and Remediation Plan
Komex issued a Flare Area Review – and Remediation Plan report in December 2004. Komex Report: Balzac Gas Plant – 2003/2004 Soil and Groundwater Investigation in the Flare Area - File No. C25531504
2005 Activities: the Skimmer System installed in 2003 successfully recovered additional free
product. Two deep cathodic protection wells (CPW) were installed at the Plant.
Flare Area Remediation
The draft Flare Area Investigation Report was finalized. Komex Report: Balzac Gas Plant – 2003/2004 Soil and Groundwater Investigation in the Flare Area - File No. C25531504
LPG Recovery System – On-going
Nexen continued to pump contaminated groundwater and to monitor the LPG Recovery System.
In 2005, two collection wells were added under the LPG Bullets as part of the Phase III
groundwater collection system (skimming portion). Worley Parsons Komex Report: Balzac Gas Plant – 2005-2008 Performance Report Lean Oil Remediation System - File No.
C25532004 (Draft)
Topsoil from 6-33-25 Reclamation
During Field A & R activities at wellsite 6-33-25, clean topsoil (2500 m3) was discovered and
brought to the plant for storage adjacent to the South landfill Area.
Alberta Environment Summary Update
AENV formally requested an update of recent remedial work conducted or planned for 2004/
2005/2006. Nexen conducted a tour for AENV officials (soils & groundwater experts) at the Plant
to discuss specific contaminate issues to support the reports and work that has been conducted at
the facility over numerous years. Komex Report: Balzac Gas Plant – 2005 Environmental Summary Update- File No. C25531700
2006 Activities: As part of the LPG Recovery System two new vertical extraction wells (LPG-5
and LPG-6) were added to expand Phase III of the remediation system.
In April 2006, a soil investigation was conducted in a pit area (Unknown Sump), situated west of
the holding pond in the Flare Area. Exploratory trenching was completed to investigate chloride
and hydrocarbon facility-related impacts. The investigation identified an approximate total in-situ
volume of 6,300 m3 of impacted materials. The boundaries of the excavation all met Tier I
guidelines with the exception of soils along the eastern wall of the excavation, where physical
constraints (roadway and pipeline) limited excavation in this direction. Assessment of an insitu
groundwater extraction system along the eastern wall of the excavation is under review.
A Site Specific Liability Assessment (SSLA) was completed (as required in support of the
Alberta Energy and Utilities Board (EUB) Large Facility Liability Management Program as
detailed in Directives 001 and 024). As a part of this Assessment, site-specific environmental
costs for reclamation and for soil and groundwater quality issues at the Site were estimated.
As a part of the 2006 Environmental Assessment for Management of Contaminated Sulphur and
Materials Contaminated with Sulphur, 34 boreholes were advanced throughout the Sulphur
Handling and Sulphur Block/Basepad Areas of the Plant. As outlined in the D&R Plan for the
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Sulphur Handling Facility, the results of the assessment program were used to define remedial
requirements for soil impacted by sulphur.
The 2006 Soil Monitoring Program involved the sampling of 49 boreholes throughout the Site, in
addition to two background boreholes/piezometers. The most significant chloride and/or
hydrocarbon impacts to soil were observed in the Evaporation Pond, Flare and Formation Water
Handling, and Process Areas. In addition, sulphur impacts in soil were identified in the
Cooling/Blowdown, Plant Maintenance and Sulphur Plant Areas.
As a result of these programs seven new single piezometers (06-43A through 06-49A) were
installed across the Site. Piezometer 93-15A was also re-drilled as it had been damaged by frost-
jacking.
Soil Monitoring Program – Plant Overall
The Soil Monitoring Program was completed throughout the Plant Site per Plant Operating
Approval with Alberta Environment in the fall of 2006. Worley Parsons Komex Report: Balzac Gas Plant – 2006 Soil Monitoring Program - File No. C25531803
Environmental Assessment for the Management of Contaminated Sulphur and Materials
Contaminated with Sulphur
This assessment program was an operating approval requirement. Included in the assessment was
assessment at the following locations:
the sulphur block
sulphur basepad
the slater units
sulphur load out areas
the sulphur soil piles Worley Parsons Komex Report: Balzac Gas Plant – 2006 Environmental Assessment for the Management of Contaminated Sulphur
and Materials Contaminated with Sulphur - File No. C25531803
Decommissioning and Reclamation Plan Sulphur Handling Facility
This report was issued to Alberta Environment (Mar. 2006) as per operating approval conditions.
The D&R Plan was approved by Alberta Environment in June 2006. Removal of the Enersul
Slating Facilities was completed (see below). Future work looked at Industrial Runoff and Site
Reclamation in the Sulphur Handling Area. Worley Parsons Komex Report: Balzac Gas Plant – Decommissioning and Reclamation Plan Sulphur Handling Facility
- File No. C25531604
Sulphur Contaminated Infrastructure - Enersul Slating Facilities
The D&R plan was submitted to Alberta Environment in December 2004. Demolition of Enersul
surface sulphur slating facilities began July 2006. The Enersul Slater building was removed and
water tanks, belts, power, etc. were either disconnected or removed. Alberta Environment
required dust control measures had to be undertaken during the removal of the slater building.
Remediation of the Slater Area and upgrading (removing sulphur contaminated sediment from
ditches and installing lined ditches) was completed in 2009.
Unknown Sump Area Assessment - Flare Area
Assessment was completed on area of contamination based on previous flare area soils and
groundwater investigations.
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Worley Parsons Komex Report: Balzac Gas Plant – 2006 Soil Investigation in Unknown Pit Area - File No. C25531802
2006 Industrial Runoff Assessment
This assessment was a licence requirement as per current operating approval (155-02-00) with
Alberta Environment. The purpose of the report was to review runoff management at the Plant
and evaluate current practices to determine what improvements could be made to positively
impact the site and the watershed downstream of the plant. Worley Parsons Komex Report: Balzac Gas Plant – 2006 industrial Runoff Assessment - File No. C25531806
Flare Area Remediation Follow-up
Nexen continued to monitor this area to ensure impacts have been minimized and review how
effective remediation activities have been. Overall soils management program conducted in the
fall of 2006 added some piezometers and soil borehole locations.
LPG Recovery System – On-going
Nexen continued to monitor the LPG Recovery. The lean oil collection system (collection of lean
oil which is situated on top of the groundwater table) in the LPG Unit was run throughout the
2006 season (early spring - April to late fall – October). The system was functioning as designed
with minor levels of BTEX showing up in the primary collection system and no BTEX levels in
the aerated discharge point (Trench and Gate System). As well the Phase III lean oil collection
system was run during 2006. The one skimmer pump (pumps only lean oil product) was
transported to various wells throughout the collection season. Worley Parsons Komex Report: Balzac Gas Plant – 2005-2008 Performance Report Lean Oil Remediation System - File No. C25532004 (Draft)
EUB Directive 001 Site Specific Liability Assessment
The A&R Group in Calgary started the Directive 001 study in conjunction with a consultant and
Plant input. Nexen conducted this EUB compliant study to perform an overall site assessment of
the Plant with all collected data to date.
2007 Activities:
Soil Monitoring Management Plan
Subsequent to the completion of the 2006 Soil Monitoring Program, the soil management plan
was submitted to Alberta Environment within six months of the Soil Monitoring Program that
was conducted in 2006 per Plant Operating Approval with Alberta Environment. Worley Parsons Komex Report: Balzac Gas Plant – Soil Management Plan - File No. C25531901
Sulphur Contaminated Soil Pile Disposal - Phase I
Phase I removal of sulphur contaminated sulphur/soil storage pile located on the plant site began
in the fall of 2007 and continued with Phase II in the first quarter of 2008. Phase I saw 27,395.95
tonnes (16,305 m3) of sulphur contaminated soil pile removed to CCS Rocky Mountain House. Worley Parsons Report: Balzac Gas Plant – Sulphur Soil Pile Closure Sampling - File No. C25532001
EUB Directive 001 Site Specific Liability Assessment
A report was issued to the EUB on 001 Liability Assessment as per the Large Facility Liability
Management Program per EUB’s Guide 024. Worley Parsons Komex Report: Balzac Gas Plant – Directive 001 Site Specific Liability Assessment - File No. C25531801
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LPG Recovery System
Nexen continued to pump contaminated groundwater and to monitor the LPG Recovery System. Worley Parsons Komex Report: Balzac Gas Plant – 2005-2008 Performance Report Lean Oil Remediation System - File No.
C25532004 (In Draft)
New Underground Sulphur Pit Construction
Soils were assessed during the construction of the new underground sulphur pit. Some soil was
sulphur contaminated and segregation and delineation activities were conducted during the
preparation for construction. Some sulphur contaminated soil was removed and placed on the
Sulphur Contaminated Soil Pile (see above). Approximately 3,950 m3 of soil was excavated
during the sulphur pit excavation. Analytical results indicate hydrocarbon and sulphur impacts
remained in the excavation wall and base. Worley Parsons Report: Balzac Gas Plant – Sulphur Pit Construction - File No. 25531902 (In Draft)
2008 Activities:
Sulphur Contaminated Soil Pile Disposal – Phase II
Phase II removal of sulphur contaminated sulphur/soil storage pile located on the plant site began
in the Jan 2008 and was completed April 2008. Phase II saw 58,234 tonnes (~32,352 m3) of
sulphur contaminated soil pile removed to CCS Rocky Mountain House. Worley Parsons Report: Balzac Gas Plant – Sulphur Soil Pile Closure Sampling - File No. C25532001
Suspected Topsoil StockPile Disposal
During the 2006 Soil Monitoring Program (SMP), sulphur and salinity impacts were identified
within a soil stockpile (previously referred to as “suspected topsoil stockpile”) in the sulphur
handling facility area.
Excavation and off site removal of the soil stockpile and underlying and adjacent material took
place from November 12 to 26, 2008. Excavated material was transported to BFI Landfill south
of Calgary. The volume received by the landfill was 15,086 tonnes. Worley Parsons: Sulphur Impacted Soil Stockpile Removal in Sulphur Handling Facility at Balzac Sour Gas Plant. File No. C25532007. (In Draft)
Sulphur Contaminated Soil Remediation - Enersul Slating Facilities
Started remediation program based on Sulphur Area Decommissioning and Reclamation Plan
conducted in 2004 and Environmental Assessment for the Management of Contaminated Sulphur
and Materials Contaminated with Sulphur conducted in 2006. The purpose of the report was to
assess areas of the Plant with sulphur contamination issues and provide the following: estimated
volumes of contaminated material, schedule for removal, evaluation of the permeability of the
area storing sulphur, upgrading of ditches, schedule of activities, etc. Worley Parson Komex Report: Balzac Gas Plant – Decommissioning and Reclamation Plan – Sulphur Handling Facility - File No.
C25531604
Worley Parsons Komex Report: Balzac Gas Plant – 2006 Environmental Assessment for the Management of Contaminated Sulphur and Materials Contaminated with Sulphur - File No. C25531803
Worley Parsons Komex Report: Balzac Gas Plant – Confirmatory Soil Sampling – Balzac Plant Ditch Excavation - File No.
C25532106
LPG Recovery System
Nexen continued to pump contaminated groundwater and to monitor the LPG Recovery System. Worley Parsons Komex Report: Balzac Gas Plant – 2005-2008 Performance Report Lean Oil Remediation System - File No. C25532004 (Draft)
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Unknown Pit Remediation - Flare Area
Remediation of a previously unknown pit in the flare area began in 2008 and continued in 2009.
Remediation continued in 2010 however remediation on hold pending overall strategy
development. Further remediation activities will be reviewed as part of the overall Plant
remediation assessment activities. Worley Parsons Report: Balzac Gas Plant – 2006 Soil Investigation in Unknown Pit Area - File No. C25531802
Industrial Runoff Upgrades
Based on the 2006 Industrial Runoff Assessment the upgrades in the Enersul Area were
commenced in conjunction with the Sulphur Soil Remediation of the Enersul Facilities. Worley Parsons Komex Report: Balzac Gas Plant – 2006 Industrial Runoff Assessment - File No. C25531806
Land Treatment Activities Pipeline Failure 7-15-25 Nov 2007
Land and treatment activities on the soils brought from the 7-15-25 pipeline failure that occurred
December 2007 were completed in September 2008. The soils were treated and then stockpiled
beside the treatment area. Worley Parsons Komex Report: Balzac Gas Field – Pipeline Release Remediation Program at 7-15-25-28 W4M Wellsite - File No.
C50920500
Land Treatment Activities Pipeline Failure 1-8-27 & 6-23 KO Drum Removal
A total of approximately 7,700m3 of excavated soils from 01-08-027-27 W4M (4, 100m
3) and 06-
23-027-27 W4M (3,600m3 ), as well as excess drilling mud from re-entry activities at the BGP,
was treated from 2002 to 2009. The material was initially land surface treated in the TTA next to
the 02-02-026-29 W4M well site, and then stockpiled in an area adjacent to the well site once
remediation guidelines at the time of sampling were met.
Untreated soil was moved within the Plant in 2008, land surface treated, and piled once Tier 1
Guidelines were met. Treated soil hydrocarbon concentrations in analysed samples were below
Tier I guidelines. Worley Parsons Komex Report: Remediation Status Report 01-08-027-27 W4M and 06-23-027-27 W4M. File No. C25532006.
(Draft).
2009 Activities: a sulphur base pad assessment was completed to quantify the amount of possible
recoverable sulphur on the base pads, and the extent of impacts to soil underlying the sulphur. A
total of 23 boreholes were advanced within the east base pad area. Elemental sulphur impacts
above the AENV Tier I guideline were identified to an average depth of 0.65 mbgs in soil
underlying the current base pad.
In 2009, upgrading of the surface water drainage ditch system in the sulphur handling facility
commenced. Impacted soil was also excavated from the drainage system, the underground rail
car, the old slating units and poured sulphur pad within the sulphur handling facility.
The current groundwater monitoring network comprises of 68 piezometers, three culverts and 13
surface water sampling locations. Seasonal groundwater monitoring (fall and spring) was
completed in 2009. The most significant chloride impacted groundwater was present during
these monitoring events in the Flare Area, the Former Process Ponds, and the Evaporation Pond.
The most significant hydrocarbon impacts in groundwater were present in the Flare Area, the
Former Process Ponds, the Plant Recovery area and the LPG Recovery Area.
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Sulphur Contaminated Soil Remediation - Enersul Slating Facilities
Complete remediation program that was started in 2008 along with Industrial Runoff Upgrades in
the Enersul Area. Komex Report: Balzac Gas Plant – Decommissioning and Reclamation Plan – Sulphur Handling Facility - File No. C25531604 Worley Parsons Komex Report: Balzac Gas Plant – 2006 Environmental Assessment for the Management of Contaminated Sulphur
and Materials Contaminated with Sulphur - File No. C25531803
Worley Parsons Komex Report: Balzac Gas Plant – Topsoil Stockpile Removal - File No. C25532007 DRAFT Worley Parsons Komex Report: Balzac Gas Plant – Sulphur Ditch Assessment - File No. C25532106
Sulphur Contaminated Soil Remediation - Sulphur Block and Sulphur Basepad
Continue to develop a plan for basepad reclamation and sulphur block/basepad reclamation.
South Landfill Remediation
The South Landfill remediation was originally planned for 2009 but not competed. Remediation
of this landfill is on hold pending overall strategy development. The area that the landfills are
situated on was characterized and delineated in environmental reports as listed below. Komex Report: Balzac Gas Plant – North and South Landfill Characterisation Program – File No. 25531309
Komex Report: Balzac Gas Plant – 1998 Integrated Soil and Groundwater Investigation Program Volume 1 of 2 - File No. KI-2553-9 T01/T02
Sulphur Contaminated Soil Remediation – Weigh Scale
Conducted minor clean-up activities of sulphur and soil just outside the fence near Plant weigh
scale.
LPG Recovery System – On-going
Continued to pump contaminated groundwater and monitor the LPG Recovery System. Worley Parsons Komex Report: Balzac Gas Plant – 2009-201 Performance Report Lean Oil Remediation System - File No.
C25532104 (Draft)
Unknown Pit Remediation - Flare Area
Remediation of a previously unknown pit in the flare area began in 2008 and continued in 2009. Worley Parsons Report: Balzac Gas Plant – Unknown Sump Excavation Update - File No. C25531802
Confirmatory Soil Sampling Summary, Balzac Plant Ditch Excavation
Began the excavation and removal of soil impacts related to sulphur production. Collected
confirmatory samples in conjunction with this ditch upgrade work. Remedial excavation work
was carried out from August – December 2009. Approximately 29,000 tonnes of sulphur-
impacted soil was excavated and hauled to the BFI Canada Inc. Calgary landfill. Worley Parsons Report: Confirmatory Soil Sampling Summary, Balzac Plant Ditch Excavation – File No.C25532106, 23-March-
2011.
Worley Parsons: Interim As-Built Drawings of Surface Water Collection Ditches Constructed During 2009 at the Balzac Gas Plant -. Report C25532005. December 23, 2009.
DEA UST Removal and Replacement
In 2009 the DEA UST was pressure tested and failed. Since the reason for failure could not be
determined, Nexen implemented replacement plans for the UST. On Sept. 3-4, 2009, the
excavation and installation of a new tank occurred. During excavation soil and groundwater
sampling was conducted and a groundwater extraction system was installed. Approximately
50m3 of impacted soil was excavated from the new DEA UST. Wall and base soil sampling
indicated soil met Tier 1 Guidelines for all parameters except EC at four of the five sample
locations and PHC F2 at a single sample location. Worley Parsons-2009 DEA UST Removal and Replacement - Letter Report. Report C25532107. May 10, 2011. DRAFT
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2010 Activities:
Unknown Pit Remediation - Flare Area
Remediation of a previously unknown pit in the flare area began in 2008 and continued in 2009.
In 2010, approximately 700 m3 of soil from the Unknown Sump was treated.
LPG Recovery System – On-going
Continued to pump contaminated groundwater and monitor the LPG Recovery System. Worley Parsons Komex Report: Balzac Gas Plant – 2009-201 Performance Report Lean Oil Remediation System - File No.
C25532104 (Draft)
2011 Activities:
No update as plant shutdown was being planned.
The figure on the following page provides a cursory outline of past remediation programs.
TABLE 5.PREVIOUS ENVIRONMENTAL INVESTIGATIONS BY LOCATION AND YEAR
LSU Description 1989 1991 1992 1993 1994
General Various Locations of the Site
Hydrogeological assessment, installation and sampling of 11 monitoring wells (UMA,
1989)
Assessment of hydrogeological conditions (Piteau, 1992a)
Upgrade of the groundwater monitoring network, installation of 18 observation wells (Piteau 1993a). Geophysical surveys conducted near
the buried south landfills, south of the main Process Area, and down gradient of North and South Cooling Tower Blowdown Ponds (Piteau
1992b).
Piezometers installed on the west side of McDonald Lake (93-15A (R)/C (R) and 93-16A/C) to further
define local background conditions (Komex 1995a). Groundwater monitoring program (Piteau 1993b/c)
Geophysical investigation south of the main Process area to assess the extent of potential subsurface impact associated with a number of former wastewater and surface runoff
ponds (Komex 1995b). Stable isotope investigation in and around the plant ponds, sulphur storage and sulphur loading areas (Komex 1995c). Groundwater monitoring program
(Komex 1995a)
1 Southwest Quadrant
2 South Landfill Install 94-17C bedrock piezometer (Komex 1995b).
3 2-2 Pits/ Treatment Area
4 Evaporation Pond
5 Southeast Quadrant Install 94-19C bedrock piezometer (Komex 1995b).
6 North Landfill
7 Drilling Mud Sump
8 Boneyard/Field Maintenance
9 Flare & Formation Water Handling Area
10 Riparian/Shoreline11 Firewater Reservoir
12 Southeast Process Pond
13 Cooling/Blowdown
14 Plant Maintenance
15 Inlet Compression/Sales
16 Condensate Storage Area
17 LPG/Condensate Loadout
18 Sulphur Block/Basepad Geophysical survey in the vicinity of the Sulphur Block storage area (Komex 1994). Install 94-18C bedrock piezometer (Komex 1995b).
19 Sulphur Plant
20 Office Control/Room
21 Process Area
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TABLE 5.PREVIOUS ENVIRONMENTAL INVESTIGATIONS BY LOCATION AND YEAR
LSU Description 1989 1991 1992 1993 1994
22 LPG Unit
23 Power Station Three underground storage tanks containing diesel and gasoline in parking lot were removed (Komex 2000g and 2000h).
24 Sulphur Vat Pond
25 Sulphur Handling Facility
2 of 10 10/11/2011 12:13 PM
TABLE 5.PREVIOUS ENVIRONMENTAL INVESTIGATIONS BY LOCATION AND YEAR
LSU Description
General Various Locations of the Site
1 Southwest Quadrant
2 South Landfill
3 2-2 Pits/ Treatment Area
4 Evaporation Pond
5 Southeast Quadrant
6 North Landfill
7 Drilling Mud Sump
8 Boneyard/Field Maintenance
9 Flare & Formation Water Handling Area
10 Riparian/Shoreline11 Firewater Reservoir
12 Southeast Process Pond
13 Cooling/Blowdown
14 Plant Maintenance
15 Inlet Compression/Sales
16 Condensate Storage Area
17 LPG/Condensate Loadout
18 Sulphur Block/Basepad
19 Sulphur Plant
20 Office Control/Room
21 Process Area
1995 1996 1997 1998 1999
Groundwater monitoring program (Komex 1996) Groundwater monitoring program (Komex 1997a). First soil monitoring program (Komex 1997b).
Groundwater monitoring program (Komex 1998a). Soil management plan (Komex 1997c) and remedial program work plan
(Komex 1997d).
Groundwater monitoring program (Komex 1999a). Integrated soil and groundwater investigation, twelve piezometers were installed (Komex
1998b). A 5 year environment management plan for the Site developed (Komex 1998d).
Groundwater monitoring program (Komex 2000a).
Soil monitoring program (Komex 1997b).
Identified soil contamination in two former flare pits southwest of the boneyard (Komex 1998b)
Former 2-2 North and South Flare Pits were remediated. Approximately 4600 m3
excavated (Komex 2000c).
Soil sampling program (Komex 1995b) Integrated soil and groundwater investigation (Komex 1998b).
Soil and sludge sampling program (Komex 1995b) Remediation program of the Drilling Mud Pit, soils treated with lime (Komex 1999c).
Soil monitoring program (Komex 1997b). Integrated soil and groundwater investigation (Komex 1998b).
Soil and sludge sampling program (Komex 1995b). Temporary piezometer (95‑20A) installed south of piezometer nest 92‑8A/B
(Komex 1996). Soil monitoring program (Komex 1997b).
Remediation program of the Hydrocarbon Burn Pit (Komex 1999c). Approximately 1600
m3 of accessible soil excavated next to LP flare knockout drum (Komex 1998b).
Remediation programs of the Hydrocarbon Burn Pit (2850 m3 excavated) , the Filter Cake Pond (1400 m3 excavated), the Chemical Pond (2250 m3
excavated) and Slop Tank (excavated 850 m3) (Komex 1999c). Integrated soil and groundwater investigation (Komex 1998b).
Soil and groundwater investigation to delineate known contaminant situations
(Komex 2000d).
Soil monitoring program (Komex 1997b).
Remediation of soil adjacent to the southeast Process Pond. Excavation of 2200 m3. Area was contaminated by a release from a Anderson Exploration Ltd. condensate pipeline. Piezometer 98-29A was installed (Komex 1999d).
Integrated soil and groundwater investigation (Komex 1998b).
Temporary piezometers (96‑21A and 96‑22A) installed down‑gradient of the North and South Cooling Tower Blowdown
Ponds (Komex 1997a).Integrated soil and groundwater investigation (Komex 1998b).
Soil monitoring program (Komex 1997b). Integrated soil and groundwater investigation (Komex 1998b).
Soil monitoring program (Komex 1997b).
Soil monitoring program (Komex 1997b). Integrated soil and groundwater investigation (Komex 1998b). Soil and groundwater investigation to
delineate known contaminant situations in Condensate Loading Area (Komex 2000d).
Soil monitoring program (Komex 1997b). Investigation to determine potential impact to shallow soil (Komex 1997e)
Soil monitoring program (Komex 1997b).
Soil monitoring program (Komex 1997b). Integrated soil and groundwater investigation (Komex 1998b).
3 of 10 10/11/2011 12:13 PM
TABLE 5.PREVIOUS ENVIRONMENTAL INVESTIGATIONS BY LOCATION AND YEAR
LSU Description
22 LPG Unit
23 Power Station
24 Sulphur Vat Pond
25 Sulphur Handling Facility
1995 1996 1997 1998 1999
Soil monitoring program (Komex 1997b). Identified free phase hydrocarbon product contamination in the LPG
Recovery area (Komex 1998c). Integrated soil and groundwater investigation (Komex 1998b).
Three phase remediation plan implemented. Phase I consisted of a free product recovery
trench and recovery well (Komex 2000e).
Soil monitoring program (Komex 1997b).
Soil monitoring program (Komex 1997b).
4 of 10 10/11/2011 12:13 PM
TABLE 5.PREVIOUS ENVIRONMENTAL INVESTIGATIONS BY LOCATION AND YEAR
LSU Description
General Various Locations of the Site
1 Southwest Quadrant
2 South Landfill
3 2-2 Pits/ Treatment Area
4 Evaporation Pond
5 Southeast Quadrant
6 North Landfill
7 Drilling Mud Sump
8 Boneyard/Field Maintenance
9 Flare & Formation Water Handling Area
10 Riparian/Shoreline11 Firewater Reservoir
12 Southeast Process Pond
13 Cooling/Blowdown
14 Plant Maintenance
15 Inlet Compression/Sales
16 Condensate Storage Area
17 LPG/Condensate Loadout
18 Sulphur Block/Basepad
19 Sulphur Plant
20 Office Control/Room
21 Process Area
2000 2001 2002 2003
Groundwater monitoring program (Komex 2001a). Update of thee nvironmental management plan for the
Site(Komex 2000b)
Groundwater monitoring program (Komex 2002a). Revised environmental management plan, extending to 2005
(Komex 2001c). Piezometer replacement program (Komex 2003e).
Groundwater monitoring program (Komex 2003a).
Groundwater monitoring program (Komex 2004a). Environmental Summary Update issued for the Site, updating
environmental work completed and planned in the 5‑year environmental management plan (Komex 2003g). Piezometer
replacement as recommended (Komex 2003a).
Ex-situ remediation of hydrocarbon impacted soils from Main Parking Lot, LPG Surge Tank and Condensate Loading Area (Komex 2003b). Characterization and delineation of South
Landfill (Komex 2002c).
A risk assessment of the Evaporation pond initiated in 1998 and updated in 2001. Pond sampled and evaluated for potential to
adversely impact aquatic life due to salinity or metals (Komex 2002d).
Landfill east of the Evaporation Pond discovered along the planned route of the water pipeline (2001d and 2001e).
Characterization and delineation of the North Landfill (Komex 2002c)
Remediation and reclamation of the North Landfill, approximately 8700 m3 excavated (Komex 2004e).
A risk assessment of the Holding pond initiated in 1998 and updated in 2001. Pond sampled and evaluated for potential to
adversely impact aquatic life due to salinity or metals (Komex 2002d).
Delineation program involving both soils and groundwater. The program involved 14 soil sampling boreholes and the
installation of seven piezometers (Komex 2004d).
A risk assessment of the Southeast pond initiated in 1998 and updated in 2001. Pond sampled and evaluated for potential to
adversely impact aquatic life due to salinity or metals (Komex 2002d).
Removal of the surficial sediment layer from the Southeast Process Pond (Komex 2005c)
Sludge layer removed from ponds. North Pond reconstructed with a compacted clay liner (Komex, 2005c)
KVSR sump tank removed, approximately 340 m3
impacted soils excavated where possible (Komex 2003d)
Condensate impact encountered along the fuel gas pipeline path (2001d and 2001e).
Remediation program of condensate loading area, hydrocarbon (4900 m3) and sulphur (2500 m3) impacted
soils excavated (WorleyParsons 2011f).
Removal of two above ground methanol storage tanks, excavation (1000 m3) and soil treatment program conducted on
the underlying methanol impacted soils (Komex 2002b)
Field inhibitor storage tank and sump removed. Impacted soil excavated (345 m3) and disposed
of at the BFI landfill (Komex 2003f).
Soil quality investigation around the main electrical sub-station, trace amounts of
polychlorinated biphenyls (PCBs) and heavy‑end hydrocarbons noted. Approximately 5900 kg of
soil excavated (Komex 2004b).
RDS Sump Tank Excavation (Komex 2003d).
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TABLE 5.PREVIOUS ENVIRONMENTAL INVESTIGATIONS BY LOCATION AND YEAR
LSU Description
22 LPG Unit
23 Power Station
24 Sulphur Vat Pond
25 Sulphur Handling Facility
2000 2001 2002 2003
Phase II of the remediation plan, which included installation of a trench and gate system down‑gradient of
the free product plume (Komex 2001f). LP Surge excavation approximately 900 m3 raw condensate/waste
oil impacted soils excavated (Komex 2003d).
Free phase recovery system performance (Komex 2003c)
Phase III of the remediation system was initiated, system designed to remove free product from multiple vertical wells
within the LPG area lean oil plume (Komex 2005b).
Soil quality delineation and remediation programs were implemented to ensure that the Site was suitable for Power Station construction. Approximately 4000 m3
excavated (Komex 2000g and 2000h).
Soil assessment to document pre-development soil conditions (AMEC 2003).
6 of 10 10/11/2011 12:13 PM
TABLE 5.PREVIOUS ENVIRONMENTAL INVESTIGATIONS BY LOCATION AND YEAR
LSU Description
General Various Locations of the Site
1 Southwest Quadrant
2 South Landfill
3 2-2 Pits/ Treatment Area
4 Evaporation Pond
5 Southeast Quadrant
6 North Landfill
7 Drilling Mud Sump
8 Boneyard/Field Maintenance
9 Flare & Formation Water Handling Area
10 Riparian/Shoreline11 Firewater Reservoir
12 Southeast Process Pond
13 Cooling/Blowdown
14 Plant Maintenance
15 Inlet Compression/Sales
16 Condensate Storage Area
17 LPG/Condensate Loadout
18 Sulphur Block/Basepad
19 Sulphur Plant
20 Office Control/Room
21 Process Area
2004 2005 2006 2007 2008
Groundwater monitoring program (Komex 2005a). Environmental Summary Update issued to address Alberta Environment requests
(Komex 2004c). Decommissioning and reclamation plan submitted to Alberta Environment for removal and replacement of the sulphur area
slating units (Komex 2004f).
Groundwater monitoring program (WorleyParsons Komex 2006a). 2005 Environmental Summary
Update prepared, after a meeting and Site tour with Alberta Environment (Komex 2005c).
Groundwater monitoring program (WorleyParsons Komex 2007a). Soil monitoring program and install of seven piezometers
(WorleyParsons Komex 2006c and 2006d). Decommissioning and reclamation plan updated and resubmitted to Alberta Environment
(WorleyParsons Komex 2006b). Phase 1 Environmental Site Assessment (WorleyParsons Komex 2006e).
Groundwater monitoring program (WorleyParsons Komex 2008a). Soil Management Plan developed (WorleyParsons Komex 2007b). Soil management activities summary (WorleyParsons Komex 2008c)
Groundwater monitoring program (WorleyParsons 2009a). Soil management activities summary
(WorleyParsons 2009d)
Soil monitoring program (WorleyParsons Komex 2006d).
Soil monitoring program (WorleyParsons Komex 2006d).
Soil monitoring program (WorleyParsons Komex 2006d).
Soil investigation in the Unknown Sump (pit) area (WorleyParsons 2009f). Soil monitoring program (WorleyParsons
Komex 2006d).
Excavation of the Unknown Sump, portion of the impacted material sent off Site for disposal,
remaining material stockpiled on Site for treatment (WorleyParsons 2011b)
Soil monitoring program (WorleyParsons Komex 2006d).
Soil monitoring program (WorleyParsons Komex 2006d).
Soil monitoring program (WorleyParsons Komex 2006d).
Soil monitoring program (WorleyParsons Komex 2006d).
Soil monitoring program (WorleyParsons Komex 2006d).
Soil monitoring program (WorleyParsons Komex 2006d).
Baseline assessment of soil and groundwater conditions in the vicinity of Sulphur Handling Facility (AMEC 2004) Soil monitoring program (WorleyParsons Komex 2006c).
Removal and off Site disposal of the sulphur/soil stockpiles located southwest of the existing Sulphur
Block (WorleyParsons 2009c).
Soil monitoring program (WorleyParsons Komex 2006c).Construction of a new sulphur pit, impacted soil (3950 m3) excavated (WorleyParsons 2011c).
Soil monitoring program (WorleyParsons Komex 2006d). Installed two vertical remediation Stabilizer Culverts down‑gradient of the stabilizer towers.
7 of 10 10/11/2011 12:13 PM
TABLE 5.PREVIOUS ENVIRONMENTAL INVESTIGATIONS BY LOCATION AND YEAR
LSU Description
22 LPG Unit
23 Power Station
24 Sulphur Vat Pond
25 Sulphur Handling Facility
2004 2005 2006 2007 2008
Soil monitoring program (WorleyParsons Komex 2006d).Installed three remediation culverts around the CHD system in the LPG area, which are included in the
operation of the LPG remediation system.
Soil monitoring program (WorleyParsons Komex 2006d).
Baseline assessment of soil and groundwater conditions in the vicinity of Sulphur Handling Facility (AMEC 2004) Soil monitoring program (WorleyParsons Komex 2006c).
Suspected topsoil stockpiles removed from Site and sent for off Site disposal Impacted soil underlying and adjacent to the stockpile was also
removed from Site (WorleyParsons 2011e).
Notes Indicates Assessment WorkIndicates Remediation Work
8 of 10 10/11/2011 12:13 PM
TABLE 5.PREVIOUS ENVIRONMENTAL INVESTIGATIONS BY LOCATION AND YEAR
LSU Description
General Various Locations of the Site
1 Southwest Quadrant
2 South Landfill
3 2-2 Pits/ Treatment Area
4 Evaporation Pond
5 Southeast Quadrant
6 North Landfill
7 Drilling Mud Sump
8 Boneyard/Field Maintenance
9 Flare & Formation Water Handling Area
10 Riparian/Shoreline11 Firewater Reservoir
12 Southeast Process Pond
13 Cooling/Blowdown
14 Plant Maintenance
15 Inlet Compression/Sales
16 Condensate Storage Area
17 LPG/Condensate Loadout
18 Sulphur Block/Basepad
19 Sulphur Plant
20 Office Control/Room
21 Process Area
2009 2010
Groundwater monitoring program (WorleyParsons 2010a). Soil management activities summary
(WorleyParsons 2010b)
Groundwater monitoring program (WorleyParsons 2011a). Soil
management activities summary (WorleyParsons 2011d).
Environmental assessment of the east and west sulphur base pads (WorleyParsons 2009e).
9 of 10 10/11/2011 12:13 PM
TABLE 5.PREVIOUS ENVIRONMENTAL INVESTIGATIONS BY LOCATION AND YEAR
LSU Description
22 LPG Unit
23 Power Station
24 Sulphur Vat Pond
25 Sulphur Handling Facility
2009 2010
Upgrading of the surface water drainage ditch system, impacted soil was excavated (29000
tonnes) within the drainage system and within the sulphur handling facility. Impacted soil was sent off
Site for disposal (WorleyParsons 2010c).
10 of 10 10/11/2011 12:13 PM
CONDENSATE SPILL-FEDERATED/ANDERSONREMEDIATION 1998.
REPORT TO ANDERSON NOV 1999KOMEX REPORT C47480100
UNDERGROUND STORAGE TANKS REMOVAL -UPGRADE EXCAVATE CONTAMINATED SOILS
FOR LAND TRT. 2000 & 2001 KOMEXREPORT C2553-1206 RERUN SUMP
SALES GAS OIL SUMP ELKTONKVSR OIL SUMP SITE 'G' SUMP FURTHER
DELINEATION COMPLETED IN2006 ON: TRIM SUMP, BULK SUMP
UNDERGROUND STORAGE TANKSREMOVAL - UPGRADE EXCAVATE
CONTAMINATED SOILS FOR LANDTRT. 2000 & 2001 KOMEX REPORT
C2553-1206 RERUN SUMPSALES GAS OIL SUMP ELKTON KVSR
OIL SUMP SITE 'G' SUMP FURTHERDELINEATION COMPLETED IN
2006 ON: TRIM SUMP, BULK SUMP
UNDERGROUND STORAGE TANKS REMOVAL- UPGRADE EXCAVATE CONTAMINATED SOILSFOR LAND TRT. 2000 & 2001 KOMEXREPORT C2553-1206 RERUN SUMPSALES GAS OIL SUMP ELKTONKVSR OIL SUMP SITE 'G'SUMP FURTHER DELINEATION COMPLETED IN2006 ON: TRIM SUMP, BULK SUMP
HOLDING POND RISK ASSESSMENT-1998
KOMEX REPORT KI-98-4683KOMEX REPORT C25531301
2-2 PIT NORTH REMEDIATED 1999-2000 OFFSITE TREATMENT OF SLUDGE - THERMAL DESORPTION LAND TREATMENT FOR REMAINING SOILS COMPLETED 2000KOMEX REPORT C25521103KOMEX REPORT C25531204
FILTER CAKE POND REMEDIATED 1998OFFSITE DISPOSAL OF SLUDGES
LAND SURFACE TREATMENT OF REMAINING SOILS KOMEX REPORT KI-2553-10-2
NEW CONSTRUCTION IN FLARE AREA APPROX. 850m .EXCAVATED (1997) AND LAND SURFACE TREATMENT WITH OTHER PIT/POND MATERIAL (1998)
KOMEX REPORT KI-2553-10-02
CHEMICAL POND REMEDIATED 1998OFFSITE DISPOSAL OF SLUDGES
LAND SURFACE TREATMENT OF REMAINING SOILS KOMEX REPORT KI-2553-10-2
2-2 PIT SOUTH REMEDIATED 1999-2000 OFFSITE TREATMENT OF SLUDGE-THERMAL DESORPTION
LAND TREATMENT FOR REMAINING SOILS KOMEX REPORT C25521103 & C25531204
-INHIBITOR TANK & METHANOL TANK REMOVED 2001 UPGRADED CONTAINMENT & STORAGE FOR BOTH TANKS NOW LOCATED IN FIELD BONEYARD. -METHANOL TANK REMEDIATION - 2001 KOMEX REPORT 25531306 -INHIBITOR TANK REMEDIATION COMPLETED 2002.KOMEX REPORT 25531408NEW FACILITIES - DOUBLE WALLED TANKSFIELD BONEYARD
BALZAC PARKING LOTUNDERGROUND PETROLEUM TANK INVESTIGATIONREMEDIATION SEPT/OCT 2000 KOMEX REPORT 25531208
CONDENSATE LOADING AREA DELINEATION COMPLETE IN 1999
EXCAVATION 2000 SULPHUR CONTAMINATED SOILS TO PILE.
KOMEX REPORT C2553-1211 & C25531104
REMOVAL OF SOIL TO FACILITATE CONSTRUCTION OF NEW
SULPHUR PIT - 2007 WPK REPORT 25531902
HYDROCARBON BURN PIT & DITCHES REMEDIATED 1997-1998 OFFSITE DISPOSAL OF SLUDGES LAND SURFACE TREATMENT OF REMAINING SOILS LAND TREATMENT OF DITCHES KOMEX REPORT KI-2553-10-2
LPG RECOVERY AREA-LEAN OIL COLLECTION REMEDIATION ACTIVITIES *DELINEATION OF FREE PRODUCT CONTAMINATION IN LPG RECOVERY AREA-BALZAC GAS PLANT-1999 KOMEX REPORT KI-2553-10-05 *PHASE 1-RECOVERY TRENCH - 1999 KOMEX REPORT C-2553-1106 *DELINEATION OF FREE PRODUCT CONTAMINATION IN CLA AND FLARE AREA-MAY 1999 KOMEX REPORT KI-2553-1104 *PHASE 2-TRENCH & GATE COLLECTION SYSTEM-2000 KOMEX REPORT C-2553-1212 TRENCH & GATE COLLECTION SYSTEM 2001 KOMEX REPORT C-2553-1303 *PHASE 3-2003 EXPAND LPG RECOVERY SYSTEM KOMEX REPORT C-2553-1503 *REMEDIATION OPTIONS ANALYSIS-LPG RECOVER AREA KOMEX REPOT 2553-1102 *PROPOSED EXPANSION OF FREE PRODUCT RECOVERY SYSTEM KOMEX REPORT 2553-1206 *2003-2004 PERFORMANCE REPORT-LEAN OIL REMEDIATION SYSTEM - LPG RECOVERY AREA KOMEX REPORT 2553-1605 *2005 PERFORMANCE REPORT LEAN OIL - REMEDIATION SYSTEM KOMEX REPORT 2553-1702
DRILLING MUD SUMP REMEDIATED 1998 CALCIUM AMENDMENTKOMEX REPORT KI-2553-10-2
TEMPORARY LAND TREATMENT AREA SOILS STORAGE (CLEAN)PARKING LOT SOILS ~3600m3 LP SURGE SOILS ~900m3CONDENSATE LOADING SOILS ~1000m3SOUTH BLOWDOWN POND SLUDGE/SOIL ~1000m3COMPLETED FALL 2001 KOMEX REPORT C2553-1211
EVAPORATION POND RISK ASSESSMENT - 1998 KOMEX REPORT KI98-4683KOMEX REPORT C25531301
SOUTHEAST PROCESS AREA RUNOFF PONDRISK ASSESSMENT - 1998
KOMEX REPORT KI-98-4683 KOMEX REPORT C25531301
SEDIMENT REMOVAL 2002/2003
ENVIRONMENTALSOILS ASSESSMENTFOR NEW SULPHURFORMING FACILITY- 2003 AMEC AMECREPORT: CE02621
PHASE 1 / 11 ENVIRO. SITE ASSESSMENT PROPOSED BALZAC POWER STATION. JACQUES WHITFORD REPORT: ABC50167-9
WATERLINE INSTALLATIONHYDROCARBON RESULTS - 2001KOMEX REPORT C2553-1307
- SOIL QUAILITY ADJACENT TO SULPHUR CONTAMINATED SOIL PILE - 1997 KOMEX REPORT 2553-8-2 - SULPHUR CONTAMINATED SOIL PILE EVALUATE COST EFFECTIVE DISPOSAL OPTIONS BENCH TESTING CONDUCTED 2000 - SULPHUR SOIL PILE RESAMPLED AS PART OF "2006 ENVIROMENTAL ASSESS FOR MGM OF CONTAMINATED SULPHUR" WPK REPORT 25531803 KOMEX REPORT KI-2553-1104 - SULPHUR PILE REMOVAL TO LANDFILL PHASE 1 - STARTED OCT. 2007 SULPHUR SOIL REMOVED 16,305m3 (27,394 tonnes) - PHASE 2 - STARTED JAN. 2008 SULPHUR SOIL REMOVED 29,171m3 (58,234 tonnes) SULPHUR SOIL REMEDIATION WPK REPORT 25532001 REPORT PENDING
NORTH LANDFILL AREACHARACTERIZATION PROGRAM
COMPLETED 2001 KOMEX REPORT C25531309 &
KI-2553-9REMEDIATION COMPLETED 2003-2004
CLOSURE SAMPLING REPORT KOMEX REPORT C25531505
UPGRADE RUNOFF WATER CONTROLAROUND SULPHUR BLOCK AREA 1994-1995
PETROGAS REPORT: C. FILE 001-02
SOIL ASSESSMENT & GROUNDWATERBASE-LINE DATA
AMEC PROPOSAL & REPORT CE2004/173
SOIL MONITORING (AMD)1988-PRESENT
MATRIX SOLUTIONS/JIM LORE & ASSOC. LIMING PROGRAMS
1990, 1992, 1995, 2004
SULPHUR CONTAMINATED SOIL REMEDIATION TECH - 2001PROCESS RESEARCH ASSOC. REPORT PROJECT 00-05207
FUEL GAS INSTALLATIONHYDROCARBON MONITORING RESULTS - 2001 KOMEX REPORT C25531307
ARSENIC DETECTIONS IN SW DUGOUT KOMEX REPORT 2553-1302CONTINUE TO MONITOR
BONEYARD: RESAMPLED 2006KOMEX REPORT C25531901
FLARE AREA DELINEATION OF CONTAMINATION IN FLARE AREA & CLA KOMEXE REPORT 25531104 - 2000 2003 SOILS & GROUNDWATER INVESTIGATION IN THE FLARE AREA - BALZAC GAS PLANT KOMEX REPORT 2551504
SOUTH BLOWDOWNPOND SLUDGE REMOVAL NOV.2000
SULPHER RECOVERY AREARESAMPLED 2006 2006SOIL MGM PLAN WPKREPORT C25531901
PCB REMOVALSUBSTATION #6-2000 & 2002
NORTH BLOWNDOWNPOND SLUDGE REMOVAL & DISPOSAL SEPT.2000
STUDY OF SOIL, SLUDGE AND GROUNDWATER AROUND TEH BLOWDOWN PONDS KOMEX REPORT 2553-7-2
CONDENSATE STORAGE TANK/ LP SURGE FURTHER DELINEATION COMPLETE
2006 SOIL MGM PLANWPK REPORT C25531901
REMOVAL OF PCB CONTAMINATED SOIL IN ELECTRICAL SUBSTATION GROUND GRID-2002 (PARTIAL) PCB REMOVAL CAPAC. BANK MAIN SUBSTATION - 2002
SULPHUR AREA DECOMMISSIONING& RECLAIMATION PLAN - PROPOSALKOMEX C25531604
EFFECTS OF ACID CONITIONS ON ELEMENT DISTRIBUTION BENEATH A SULPHUR BASEPAD KOMEX REPORT K1964374 - 1996
SOUTH LANDFILL AREA (5 CELLS) CHARACTERIZATION PROGRAM COMPLETED 2001 KOMEX REPORT C25531309 7 KI-2553-9
0 100 200 30050Meters
Author: R. McCallumGIS Analyst : M. JanickDept.: GIS Services
Date: June 10, 2011File No: A12780.mxd
NEXEN INC. 801-7th Ave S.W. Calgary, AB. Canada T2P 3P7T. 403.699.4000 www.nexeninc.com
Figure 4.COMPLETE OR
ASSESSED PROGRAMS
Nexen Inc.Canadian Oil & Gas Division
Scale:1:2,500
services
LegendComplete or Assessed Programs
DEA UST REMOVALWP REPORT C25532107 - DRAFT
CONFIRMATORY SOIL SAMPLINGSUMMARY
WP Report C25532106
SULPHUR IMPACTED SOIL STOCKPILE REMOVALWP REPORT C25532007-DRAFT
SULPHUR BASE PAD ASSESSMENTWP 25532102, 2009
SULPHUR PILE CLOSURE REPORT
DRAFT
UNKNOWN SUMP SOIL INVESTIGATIONWP REPORT C25531802SOIL REMEDIATIONWP REPORT PENDING
LAND TREATMENT FOR PIPELINE FAILURE01-08-27-27W4 & 06-23-027-27W4WP REPORT C25532006 - DRAFTWP REPORT C25531409 - PENDING
WP REPORT C25531403 - DRAFT
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8 CURRENT STATE OF PROPERTY
This section outlines the current known state of soil, groundwater and surface water based upon
completed investigative and remedial projects to date at the BGP. The BGP has been divided into
the following Liability Sub-Units:
Table 6. Liability Sub-Units (“LSU”)
Liability Subunit(s)
1. Southwest Quadrant 2. South Landfill 3. 2-2 Pits/Treatment Area
4. Evaporation Pond 5. Southeast Quadrant 6. North Landfill
7. Drilling Mud Sump 8. Boneyard/Field Maintenance 9. Flare & Formation Water
Handling Area
10. Riparian/Shoreline 11. Firewater Reservoir 12. Southeast Process Pond
13. Cooling/Blowdown 14. Plant Maintenance 15. Inlet Compression/Sales
16. Condensate Storage Area 17. LPG/Condensate Loadout 18. Sulphur Block/Basepad
19. Sulphur Plant 20. Office/Control Room 21. Process Area
22. LPG Unit 23. Balzac Power Station 24. Sulphur Vat Pond
25. Sulphur Handling Facility Entire Site
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8.1 Primary Sources of Contamination Potential sources of contamination and location within the Site are summarized in the following
table.
Table 7. Summary of Potential Environmental Issues
LSU LSU
Reference
Source Issue
Entire Site Deep wells Potential cross-contamination due to improper
abandonment
South Landfill 2 Former landfill Impacts associated with former landfill
Evaporation Pond 4 Evaporation pond Impacts associated with surface water and sediments
Land treatment area Treatment of hydrocarbon and condensate-impacted
soils
Boneyard/Field
Maintenance
8 AST area Hydrocarbon impacts associated with bulk storage of
fluids
Spills/leaks Impacts associated with spills and leaks
Flare & Formation
Water Handling Area
9
Unknown Sump area Impacts associated with a former buried sump
Holding pond Impacts associated with sediments and surface water
Pits and ponds Impacts associated with former burn pit and chemical
pond
Collection pond,
tanks, equipment,
spills, leaks
Impacts associated with equipment, tankage, and plant
processes in area
Sludge Impacts associated with sediments
Pond water Impacts associated with surface water
Chemical spill Impacts associated with catalyst spill
Cooling/Blowdown 13 Blowdown Pond Impacts associated with unlined blowdown pond
Plant Maintenance 14 Former sulphur pit Potential migration from the former sulphur pit
Former storage docks Potential impacts associated with former storage docks
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LSU LSU
Reference
Source Issue
Inlet Compression/
Sales
15 KSVR Compressors Faulty floor drains/hydrocarbon staining
Site ‘G’ Comp.
Building
Minor hydrocarbon staining/potential tank leakage
RDS Sales Gas Area Potential drips/leaks from chemicals stored at the pad
and associated with the drain
Diethanolamine
(DEA) coolers
Impacts associated with historical cleaning practices of
the bundles from the DEA coolers
Former tankage Potential drips/leaks from former oil sump and
separator sump
Condensate Storage
Area
16 Condensate Storage
Tanks
Drips/leaks from condensate storage tanks and spills in
general area
Bundle wash area Impacts associated with bundle washing
Sulphur Block/
Basepad
18 Sulphur Blocks –
East and West
Unlined sulphur blocks
Sulphur Soil Piles Stockpiles of sulphur-impacted soil
Sulphur Block carry-
over
Surface soil impacts
Sulphur Plant 19 Spills, leaks, tanks Impacts associated with tankage, drainage system, and
truck loading
Sulphur Pit Impacts associated with sulphur pit
Office/Control Room 20 Transformers/
Electrical Substation
Drips/leaks from Polychlorinated Biphenyls (PCB)-
containing equipment
Process Area 21 Treater Building Impacts associated with equipment and processes in
and north of Treater building
DEA Storage Area Impacts associated with equipment and processes in the
DEA storage area
Stabilizer Towers Impacts associated with equipment and processes in the
Stab towers area
Salt Bath Heaters Impacts associated with historical spills at the Salt bath
heaters
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LSU LSU
Reference
Source Issue
LPG Unit 22 Lean oil plume Lean oil plume
Sulphur Vat Pond 24 Sulphur Vat Pond Impacts associated with sediment and surface water in
pond
Sulphur Handling
Facility
25 Sulphur Handling
Facility
Impacts in the load out, sulphur pile, and former slating
facilities
Sulphur Handling
Facility
Surface soil impacts
Sulphur Handling
Facility
Impacts associated with facility buildings and former
sulphur pad area
Sterilants were identified as likely having been used on Site for vegetation control in the past.
Current vegetation control includes non-persistent herbicides.
Asbestos insulation and presence of naturally occurring radioactive material (NORMS) have also
previously been identified on the Site
8.2 Summary of COPCs A summary of identified COPCs in soil and groundwater identified in LSUs of the Site is
provided in Table 8 (below). Groundwater COPCs identified in the table are based on analytical
data from monitoring wells installed within a LSU. Some parameters have recorded
concentrations above guidelines in background locations and therefore elevated concentrations
within the Site may not necessarily be attributable to facility-related impacts. A detailed analysis
of background conditions is required to confirm and or disregard select COPCs.
Table 8. Contaminants of Potential Concern in Soil and Groundwater
LSU Description Petroleum Hydrocarbons
Free Phase Hydrocarbon
LiquidsPAHs VOCs Metals Glycols Amines Methanol Sulphur PCBs Debris Catalyst Salinity Indicators
/ Nitrogen
1 Southwest Quadrant
2 South Landfill S S W S S S W
3 2-2 Pits/ Treatment Area W W
4 Evaporation Pond S S W S W
5 Southeast Quadrant
6 North Landfill W W
7 Drilling Mud Sump
8 Boneyard/Field Maintenance S S W S S W
9 Flare & Formation Water Handling Area S W W S S W S W S W S S W
10 Riparian/Shoreline
11 Firewater Reservoir
12 Southeast Process Pond S S
13 Cooling/Blowdown S W S S W
14 Plant Maintenance S S S
15 Inlet Compression/Sales S W S W S S S W
16 Condensate Storage Area S S S S
17 LPG/Condensate Loadout S S W S S W
18 Sulphur Block/Basepad S W S S W
19 Sulphur Plant S S S S W
20 Office Control/Room S
21 Process Area S W W S W S W S S S W
22 LPG Unit S W W S W S W
23 Power Station
24 Sulphur Vat Pond W S W
25 Sulphur Handling Facility S S S S W S S WLSU = Liability Subunit S = Soil W = Groundwater PAHs = Polycyclic Aromatic Hydrocarbons VOCs = Volatile Organic Compounds
Notes: PCBs = Polychlorinated Biphenyls Salinity = pH, electrical conductance, major ions Indicators/Nitrogen = major ions, nitrate, nitrite, ammonia
Contaminants of Potential Concern
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8.3 Soil Conditions
Soil conditions across the property are reasonably understood, with assessment activities having
taking place in most areas over the past ten years. Full delineation of identified soil
contamination has not been completed in most cases due to the presence of infrastructure, lack of
activity within the area, or areas that were deemed to be low risk in the past. With the exception
of the south landfill and the sulphur block/basepad, where delineation efforts have been
completed, and remedial volumes are reasonably understood.
Most point sources of soil contamination are understood across the property, with the exception
of the following locations, where assessment has not yet been completed or has been limited due
to the presence of existing infrastructure that prevented sampling:
Flare/Formation Water Handling Area: various impacts to soil (hydrocarbon, salinity,
alcohol, glycol, PAH, VOCs, amines and metals) at various selected locations. Detailed
assessment as to the extent of each of these contaminants has not been undertaken to date
due to congestion of infrastructure and underground utilities;
Flare/Formation Water Handling Area (unknown sump): soil excavation has been
completed in this area, but was limited along the eastern extent by the presence of
pipelines. Assessment was not feasible under the pipelines at the time of remediation;
Southeast Process Pond: a partial remediation was completed on the southeast process
pond in 2002, but assessment is still required to confirm and better understand salinity
impacts to soil and sediment;
Inlet Compression/Sales: soil impacts (hydrocarbon and boron) were not fully assessed
due to the presence of Building #3-#4 (KVSR);
Process Area: suspected hydrocarbon impacts at the DEA UST. The presence of the UST
has limited assessment to date;
Process Area: general remediation of soil impacts (arsenic, barium, boron, molybdedum,
and hydrocarbon) is not currently possible due to facility operations. The extent of these
soil impacts is not known; and,
Sulphur Handling Facility: sulphur impacted soils around current GXM2 building.
Building is limiting further assessment and delineation.
Numerous other areas across the property have identified soil contamination and delineation is
required to fully characterize the extents of the plume. This assessment work will be completed
in the coming years in order to finalize remedial planning for an appropriate end land use once
equipment and infrastructure has been removed. As this occurs, the remedial plan will be
revisited and revised as necessary.
Sulphur Base Pads
Still marketable sulphur remaining and Nexen is working on a marketing strategy to remove this
material through 2012-2014. This will allow Nexen to attempt to reduce remediation and
disposal options for this material during the remediation time frames.
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8.3.1 Contaminants of Potential Concern in Soil
Several soil, groundwater and surface water environmental investigations have been completed at
the Site. Soil, surface water and groundwater monitoring locations are shown on Figure 6. Based
on findings of the investigations, remedial activities have also been implemented during operation
of the Site. Significant environmental investigations and remedial work since 1989 has been
summarized.
The Plant has been subdivided into component areas and processes and were termed "Liability
Subunits" (LSUs). For the purpose of this report, the LSUs are used to associate areas of concern
(AOC) and COPC with locations of the Site.
A listing of the LSUs for the Site and a plot plan showing the physical location and size of each
LSU are provided in Tables 5, 8, 9, 10 and 11 and Figure 5, respectively. In addition, one non-
traditional LSU was used. This LSU was termed the "Entire Site" and was used for issues or
findings that applied to the Site as a whole (i.e. groundwater impacts underlying several LSUs) or
for concerns/activities that cannot readily be assigned to a specific component area or process.
This LSU is not depicted on the accompanying figures, as it is conceptual in nature.
Previously identified background locations are located in the southwest (LSU 1), southeast (LSU
5) and on the west end of McDonald Lake in areas believed to be undisturbed by Site activities.
Analytical data from these background locations were used in evaluation of COPCs associated
with the Site. Parameters that were identified as COPCs in soil include:
hydrocarbons;
polycyclic aromatic hydrocarbons (PAHs);
volatile organic compounds (VOCs);
metals;
glycols;
amines;
methanol;
salinity (pH, electrical conductivity [EC], major ions);
sulphur; and,
PCBs.
Soil data indicate background sodium adsorption ratios (SAR) in topsoil and subsoil are generally
in the unsuitable category. SAR concentrations reported across the Site are generally consistent
with background conditions, as such, SAR was excluded as a COPC for the Site. EC
concentrations in topsoil and subsoil background samples range from good to unsuitable category
ratings, the variance is likely due to varying concentrations of sulphate in the soil. Background
soil data is limited and, based on the variation observed, it is possible that background
concentrations of sulphate may be higher than currently reported. Therefore, EC concentrations
BALZAC GAS PLANT
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across the Site, exceeding currently reported background concentrations may not necessarily be
attributable to historical activities, depending on the ions influencing the EC concentration.
Elevated EC concentrations in some areas of the Site may be attributable to naturally occurring
sulphate concentrations that were not captured in available background soil data. Further
background soil data of the area is required to confirm.
The Balzac Power Station (LSU 23) and 2-2 well site (LSU 3) have been included in subdivision
of the Site as they are functionally attached to the Site. However, the Balzac Power Station
operates under a separate license or approval from the BGP under AEPEA Approval # 136858-
00-00. The 2-2 well site also operates under a separate ERCB well licence # 0022533.
LSU Description AOC Source Issue COPC Type Above Tier 1 - 2010 Parkland/ Residential Above Background
Background (S06-1)
Entire Site 1 Deep cathodic wells
Potential cross-contamination due to improper abandonment Hydrocarbons, salts Potential
1 Southwest Quadrant (S96-19- Background)
2 South Landfill 2 Former landfill Impacts associated with former landfill
Hydrocarbons, salts, metals, debris, catalyst Proven
3 2-2 Pits/ Treatment Area Not Included in Assessment
4 Evaporation Pond 3 Evaporation pond
Impacts associated with surface water and sediments Salts, metals Contingent chloride, sulphate, Cobalt, lead, zinc
4 Land treatment area
Treatment of hydrocarbon and condensate-impacted soils Hydrocarbons Proven
5 Southeast Quadrant (95-1, S06-2 -Background)6 North Landfill7 Drilling Mud Sump
8 Boneyard/Field Maintenance 5 AST area Hydrocarbon impacts associated with bulk storage of fluids Hydrocarbons Proven Molybedum & Cobalt molybdenum, cobalt, Chloride, mdea
6 Spills/ leaks Impacts associated with spills and leaks
Hydrocarbons, salts, amines Potential
9 Flare & Formation Water Handling Area 7 Unknown pit area
Impacts associated with a former buried sump Hydrocarbons, salts Proven
8 Holding pond Impacts associated with sediments and surface water Salts, metals Proven
9 Pits and ponds Impacts associated with former burn pit, chemical pond and ditches
Hydrocarbons, waste oil, disposal water,
aminesProven
10
Collection pond, tanks, equipment, spills, leaks
Impacts associated with equipment, tankage, and plant processes in area
Hydrocarbons, salts (biocide) Proven
10.1 Sludge Impacts associated with sediments Hydrocarbons, metals, salts Potential
10.2 Pond Water Impacts associated with surface water
Hydrocarbons, metals, salts Proven
11 Chemical spill Impacts associated with catalyst spill Catalyst Proven
EC, Boron, BTEX, TEH, TPH, F1-F4, PAHs -
Fluoranthene, Fluorene, Naphthalene,
Phenanthrene, Pyrene
Chloride, Sulphate, Cadmium, Lead, Berylium, Molybedum, Cobalt. Verification sampling of metals
removal from Ponds was not completed several metals exceeded 95-7 Burn Pit, 95-9 Filter Cake Pond, 95-10
Chemical Pond). PAHs - Acenaphthene, benzo(e)pyrene, 2-methylnaphthalene, benzo(ghi)perylene,
benzon(a)anthracene, chrysene. VOC - 1,2,4-Trimethybenzene, 1,3,5-Trimethylbenzene.
Phase 1/ Liability Assesment Soils Tables - Based on SMP data and limited projects as noted
EC, Boron
LSU Description AOC Source Issue COPC Type Above Tier 1 - 2010 Parkland/ Residential Above Background
10 Riparian/Shoreline11 Firewater Reservoir
12 Southeast Process Pond EC, pH, Molybdenum chloride, sulphate, boron, cadmiuim, copper, lead
13 Cooling/Blowdown 12 Blowdown pond Impacts associated with unlined blowdown pond Salts, metals Potential Elemetal Sulphur,
molybdenum Total sulphur, chloride, chromium
14 Plant Maintenance 14 Former sulphur pit
Potential migration from the former sulphur pit
Waste oil, elemental sulphur Potential Elemetal Sulphur Total sulphur, molybdenum, TEH
15 Former storage docks
Potential impacts associated with former storage docks Hydrocarbons, metals Potential
15 Inlet Compression/Sales 16 KSVR Compressor
Faulty floor drains/ hydrocarbon staining Hydrocarbons, glycol Proven
17 Site G Building Minor hydrocarbon staining/ potential tank leakage Hydrocarbons Potential
18 RDS sales gas area
Potential drips/ leaks from chemicals stored at the pad and associated with
the drainHydrocarbons Proven
19 DEA coolersImpacts associated with historical cleaning practices of the bundles
from the DEA coolersAmine Potential
20 Former tankage Potential drips/ leaks from former oil sump and separator sump Hydrocarbons Potential
16 Condensate Storage Area 21 Condensate storage tanks
Drips/ leaks from condensate storage tanks and spills in general area
Hydrocarbons, condensate Proven
22 Bundle wash area
Impacts associated with bundle washing Salts, metals, amines Potential
17 LPG/Condensate Loadout EC, Benzene & Ethylbenzene
Sulphate, Sulphur Potential, xylenes, PAHS - not analyzed during excavation, inibitor tank removal included PAH
exceedanes of characterization but below DL for confirmatory
18 Sulphur Block/Basepad 23 Sulphur blocks – east and west Unlined sulphur blocks Elemental sulphur Proven EC, pH, elemental Sulphur,
Molybdenum, Sulphate, Total Sulphur,
24 Sulphur soil piles Stockpiles of sulphur-impacted soil Elemental sulphur Proven Boron S06-87, Selenium S06-93, Hydrocarbon detection
S06-95
25 Sulphur block carry-over Surface soil impacts Elemental sulphur Proven
Phase 1/ Liability Assesment Soils Tables - Based on SMP data and limited projects as noted
EC, boron, molybdenum, BEX, F1-F2
chloride, sulphate, chromium,copper, lead, zinc, toluene, PHC F3, F4
EC, arsenic, boron, molybdenum, BTEX, PHC
F1-F3sulphate, chromium, nickel, zinc, thalium, PHC F4
LSU Description AOC Source Issue COPC Type Above Tier 1 - 2010 Parkland/ Residential Above Background
19 Sulphur Plant 13 Spills, leaks, tanks
Impacts associated with tankage, drainage system, and truck loading
Metals, elemental sulphur Proven
26 Sulphur pit Impacts associated with sulphur pit Elemental sulphur Potential
20 Office Control/Room 27Transformers/
electrical substation
Drips/ leaks from PCB-containing equipment PCBs Proven
21 Process Area 28 Treater buildingImpacts associated with equipment
and processes in and north of Treater building
Hydrocarbon, glycol, lube oil Proven
29 DEA storage area
Impacts associated with equipment and processes in the DEA storage
areaAmines Proven
30 Stabilizer towers
Impacts associated with equipment and processes in the Stab towers
area
Hydrocarbons, salts, glycols Proven
31 Salt bath heaters
Impacts associated with historical spills at the Salt bath heaters Salts Potential
21 Process Area
Phase 1 Indicates Methonal Spilled to
ground in 2001 -150 Liters
22 LPG Unit 32 Lean oil plume Lean oil plume Hydrocarbons Proven
EC (adjacent to LPG Loadout), hexavalent chromium, selenium, thallium, BTEX, F1
Sulphate, boron
23 Power Station Not Included in Assessment
24 Sulphur Vat Pond 33 Sulphur vat pond
Impacts associated with sediment and surface water in pond Sulphate, salts Potential EC Sulphate, Total Sulphur, Xylenes
25 Sulphur Handling Facility 34Sulphur Handling Facility
Impacts in the load out, sulphur pile, and former slating facilities
Hydrocarbons, elemental sulphur Proven
35Sulphur Handling Facility
Surface soil impacts Elemental sulphur Proven
36Sulphur Handling Facility
Impacts associated with facility buildings and former sulphur pad
areaElemental sulphur Proven
Phase 1/ Liability Assesment Soils Tables - Based on SMP data and limited projects as noted
lead, mercury, chromium, TEH, F3, F4
EC, pH, elemental Sulphur, PAHs (Fluorene,
Naphthalene, Phenanthrene, Pyrene), Chromium, PHC F2, F3
Sulphate, Total Sulphur, Chromium, PAHs (2-Methylnaphthalene, benzo(b&j)fluoranthene, chrysene),
Arsenic, Copper, Vanadium, Zinc, Molybdenum & Barium, Tetrachlorethene, Ethylbenzene, Xylenes, F1, Boron
excavated
EC, Elemental Sulphur, mercury, molybdenum,
thalium, selenum,
Total Sulphur, sulphate, boron, chromium, copper, lead, zinc, F1, F2
Boron, molybdenum, BTEX, DEA, MDEA
Table 10. Summary of COPCs in Soils
Soils COPC BTEX, F1-F4 PAHs VOCs Metals Glycols Amines Salinity Sulphur PCBs Debris CatalystLSU Description
Background Entire Site
1 Southwest Quadrant 2 South Landfill X X X X X3 2-2 Pits/ Treatment Area4 Evaporation Pond X X X5 Southeast Quadrant 6 North Landfill7 Drilling Mud Sump8 Boneyard/Field Maintenance X X X X9 Flare & Formation Water Handling Area X X X X X X X10 Riparian/Shoreline11 Firewater Reservoir12 Southeast Process Pond X X13 Cooling/Blowdown X X X14 Plant Maintenance X X X15 Inlet Compression/Sales X X X X16 Condensate Storage Area X X X X17 LPG/Condensate Loadout X X X X18 Sulphur Block/Basepad X X X19 Sulphur Plant X X X X20 Office Control/Room X21 Process Area X X X X X22 LPG Unit X X X23 Power Station No Assessment24 Sulphur Vat Pond X25 Sulphur Handling Facility X X X X X X
Salinty - includes EC, pH, chloride, sulphate
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8.4 Groundwater Conditions
UMA conducted a hydrogeological assessment in 1989: installing the initial 11 groundwater
wells. Piteau Engineering (Komex) took over the management of the groundwater monitoring
network in 1992. The groundwater monitoring program has evolved from 1989 to the current
program (2011) with slight analytical modifications taking place over the last 22 years with
approval from Alberta Environment.
Impacts to groundwater have also been assessed over the past ten years, with 68 piezometers
across the property: 48 completed in the weathered till horizon (A-series); 9 at the till/bedrock
contact (B-series); and 11 in the bedrock strata (C-series). The most recent sampling event was
completed in 2011, with groundwater samples (67), culvert samples (3) and surface water bodies
samples (12) collected and analysed.
8.4.1 COPCs in Groundwater
Previously identified groundwater monitoring locations in the southeast (LSU 5) and on the west
end of McDonald Lake are believed to represent background quality for the Site on the basis they
are located up-gradient. Background locations have been identified in the weathered till horizon
(A-series) and bedrock (C-series). Background concentrations for a number of parameters exceed
their respective AENV Tier 1 guidelines (AENV 2010a), indicating naturally elevated
concentrations. Groundwater parameters exceeding generic guidelines were only considered
COPCs if concentrations were also generally exceeded reported background concentrations.
Parameters with no guidelines were considered COPCs if concentrations generally exceeded
background concentrations. Parameters that were identified as COPCs in groundwater include:
hydrocarbons;
VOCs;
metals;
glycols;
amines;
indicators (major ions); and
nitrogen parameters.
A number of metals in particular aluminum, antimony, cadmium, chromium, lead, selenium,
silver, thallium, tin, titanium and zinc record concentrations that are generally consistent with
background concentrations and therefore are not considered to be COPCs; however, a more
detailed statistical analysis of background is required to confirm this conclusion, such a study
may also identify other metals and indicator parameters that should not be considered COPCs
based on their background concentrations and associations with other parameters. Concentrations
of nitrate and sulphate (included as nitrogen parameters and indicators, respectively) vary
considerably in background locations and sometimes exceed guidelines. Therefore, it is possible
that elevated concentrations of sulphate and nitrate at the Site may not necessarily represent
facility-related impact.
Table 11. Detailed Summary of COPCs in Groundwater by LSU
MW GW ReportWell Associated with
LSU Description AOC Source Issue COPC Type
Background
Entire Site 1 Deep cathodic wellsPotential cross-contamination due to improper abandonment
Hydrocarbons, salts Potential
1 Southwest Quadrant
2 South Landfill 2 Former landfill Impacts associated with former landfill
Hydrocarbons, salts, metals, debris, catalyst Proven 92-1A, MW-9A/B, 94-17C Buried Landfill Cells
3 2-2 Pits/ Treatment Area Not Included in Assessment 92-2A, 92-3A/B, MW-4A MW-4A - Evaporation Pond
4 Evaporation Pond 3 Evaporation pondImpacts associated
with surface water and sediments
Salts, metals Contingent 92-5A, MW-3A
5 Southeast Quadrant MW11A, 06-44A & 94-19C (Background locations)
6 North Landfill 04-42A
7 Drilling Mud Sump 92-14A
8 Boneyard/Field Maintenance 5 AST areaHydrocarbon impacts associated with bulk
storage of fluidsHydrocarbons Proven 92-4A
Phase 1/ Liability Assesment
93-15A/C, 93-16A/C, 94-19C, MW-11A, 06-43A, 06-
44A
Table 11. Detailed Summary of COPCs in Groundwater by LSU
MW GW ReportWell Associated with
LSU Description AOC Source Issue COPC Type
Phase 1/ Liability Assesment
6 Spills/ leaks Impacts associated with spills and leaks
Hydrocarbons, salts, amines Potential
9 Flare & Formation Water Hand 7 Unknown pit areaImpacts associated with a former buried
sumpHydrocarbons, salts Proven
92-6A, 92-7A, 92-8A/B, 99-30A/C, 99-31A, 99-32A, 01-35A, 03-36A, 03-37A, 03-38A, 03-39A/B, 03-
40A, 03-41A, 06-45A, 06-46A, MW-5A, 98-8C
92-7A - Burn Pit, 92-6A & 06-46A - Chemical Pond, MW-5A -
Filter Cake Pond, 06-45A - Holding Pond
10 Riparian/Shoreline11 Firewater Reservoir12 Southeast Process Pond
13 Cooling/Blowdown 12 Blowdown pondImpacts associated
with unlined blowdown pond
Salts, metals Potential 96-22A, Process Area
14 Plant Maintenance 14 Former sulphur pitPotential migration
from the former sulphur pit
Waste oil, elemental sulphur Potential
15 Inlet Compression/Sales 16 KSVR Compressor Faulty floor drains/ hydrocarbon staining Hydrocarbons, glycol Proven 92-9A, 98-25A/B , 06-47A Process Area
20 Former tankagePotential drips/ leaks from former oil sump and separator sump
Hydrocarbons Potential
16 Condensate Storage Area 21 Condensate storage tanks
Drips/ leaks from condensate storage tanks and spills in
general area
Hydrocarbons, condensate Proven
22 Bundle wash area Impacts associated with bundle washing Salts, metals, amines Potential
Table 11. Detailed Summary of COPCs in Groundwater by LSU
MW GW ReportWell Associated with
LSU Description AOC Source Issue COPC Type
Phase 1/ Liability Assesment
17 LPG/Condensate Loadout 92-12A/B, 98-23A/B 92-12 - Sulphur Block, 98-23 - Process Area
18 Sulphur Block/Basepad 23 Sulphur blocks – east and west Unlined sulphur blocks Elemental sulphur Proven 92-26A, MW-1A, MW-8A,
MW-10A, 94-18C, 98-26C
19 Sulphur Plant 13 Spills, leaks, tanks
Impacts associated with tankage, drainage
system, and truck loading
Metals, elemental sulphur Proven 92-11A/B Process Area
20 Office Control/Room 27 Transformers/ electrical substation
Drips/ leaks from PCB-containing equipment PCBs Proven
21 Process Area 28 Treater building
Impacts associated with equipment and
processes in and north of Treater building
Hydrocarbon, glycol, lube oil Proven 01-34A, 06-48A, 06-49A,
Stab Culvert 1/2 06-48A - LPG Recovery
22 LPG Unit 32 Lean oil plume Lean oil plume Hydrocarbons Proven 98-24A/B/C, LPG Surge Culvert MW-1A - Sulphur Block
23 Power Station Not Included in Assessment
24 Sulphur Vat Pond 33 Sulphur vat pondImpacts associated with sediment and
surface water in pondSulphate, salts Potential 92-13A
25 Sulphur Handling Facility 34 Sulphur Handling Facility
Impacts in the load out, sulphur pile, and
former slating facilities
Hydrocarbons, elemental sulphur Proven 01-33A Sulphur Block
Notes PAH analysis not completed.Metals - compared results to background 95th percentile - considered above Tier 1 Guideline of background if at least two samples exceeded guideline or background (included manganese, iron)Indicators/Nitrogen - exceeding background - generally above the highest background concentration (chloride, sodium,sulphate, TDS, nitrite, nitrate, ammonia)Organics - exceeding background - above detection limit
Table 11. Detailed Summary of COPCs in Groundwater by LSU
LSU Description A unit B unit C unit A unit B unit C unit
Background
Entire Site
1 Southwest Quadrant
2 South LandfillCl, SO4, Fe, Mn, TDS, Na, Fluoride, NO2, Al, Cd, Cr, Cu, Se, U, Zn
SO4, TDS, Fluoride, Na, Mn, NH3 (only 1994
measurement), As, Cd, Cr, Cu, Se, Zn
pH (high), TDS, Na, Fluoride, NH3 (Only
2001) As, Cd
Cl, SO4, Fe, Mn, TDS, Na, No2, Al, Cr, Cu, Mo, Ni
Cl, SO4,TDS, Na, As, Cr, Cu, Ni, Zn Fluoride, As
3 2-2 Pits/ Treatment AreaCl, SO4,Mn, TDS, Na,
NH3 (only 1994) Fluoride, Phenols
SO4, TDS, Fluoride, Na, Mn Cl, SO4, Mn, TDS, Na, SO4, TDS, Na, Mn
4 Evaporation PondCl, SO4,Mn, TDS, Na,
Fluoride, NH3 (only 1994) Cr, U,
Cl, Mn, Cr, B, Mo,
5 Southeast Quadrant
6 North LandfillCl, SO4,Fe, Mn, TDS,
Na, As, Cd, Cr, Cu, Se, U, Zn
Cl, SO4, Fe, Mn, TDS, Na, As, Co, Cu, U, Zn
7 Drilling Mud Sump SO4, Mn, TDS, Na, Fluoride
8 Boneyard/Field Maintenance
S04, Fe, Mn,TDS, Na, Fluoride, NO2/NO3, NH3 9only 1994) Sb, As, Cd,
Cr, Cu, Se, U, Zn
Cl, Fe, Na, Fluoride, NO2/NO3, Sb, As, Cd, Cu,
Mo, Se, U
Groundwater Tables Groundwater Tables - Based on GW Monitoring ReportsAbove Tier 1 - 2010 Parkland/ Residential Above Background
SO4, TDS, Fluoride, Na, NO3, NH3 (only 1994), Mn, Cd, Cr, Cu, Se, U,
Zn
No selected well assume same as A unit
SO4, TDS, Fluoride, Na, NO3, Mn, Cd, Se
Table 11. Detailed Summary of COPCs in Groundwater by LSU
LSU Description A unit B unit C unit A unit B unit C unit
Groundwater Tables Groundwater Tables - Based on GW Monitoring ReportsAbove Tier 1 - 2010 Parkland/ Residential Above Background
One Benzene detection in 2006 at DL
9 Flare & Formation Water Hand
Cl, SO4, Fe, Mn, TDS, Na, Fluoride, NO2, NO3,
NH3 (wells & pond & burn pit culvert), BTEX,
F1, F2, MEA, DEA, Phenols, VOCs - (1,2 -
Dichoroethane, Tetrachloroethene), Al - (08 measurements only),
Sb, As, B, Ba, Cd, Cr, Cu, Ni, Se, Ag, U, Zn
pH (high), Cl, SO4, Fe, Mn, TDS, Na, Fluoride, NO2, BTEX, F1, DEA, Sb, As, Cd, Cr, Cu, Se,
Zn
Cl, S04, Fe, Mn, TDS, Na, DEA, As, Cu, Se,
Zn
Cl, Fe, Mn, NO2, NH3 (pond & burn pit culvert), BTEX, F1, F2, VOCs - (Chloromethane, 1-1 Dichloroethane, 1,2 -
Dichoroethane, , 1,2,4 Trimethylbenzene, 1,3,5-
Trimethylbenzene), MDEA, Sb, As, B, Ba, Cr, Cu, Mo,
Ni, Se, U
Cl, SO4, Fe, TDS, Na, NO2, Sb, As, Cu, Se,
BTEX, F1
Cl, S04, Fe, Mn, TDS, Na, Benzene, As, Cu, Zn
10 Riparian/Shoreline11 Firewater Reservoir12 Southeast Process Pond
13 Cooling/Blowdown SO4, Mn, TDS, Na, Cd, Ni, U Cl, SO4, TDS, Na, Ni, U
14 Plant Maintenance
15 Inlet Compression/Sales Cl, SO4, Fe, Mn, TDS, Na SO4, Mn, TDS, Na, Cl, Fe Cl, Mn, TDS
BTEX, F2, As, Cd, Se, Ni, Phenols, NH3
F1, As, B, Ni, Zn, BTEX, F1, F2
16 Condensate Storage Area
Table 11. Detailed Summary of COPCs in Groundwater by LSU
LSU Description A unit B unit C unit A unit B unit C unit
Groundwater Tables Groundwater Tables - Based on GW Monitoring ReportsAbove Tier 1 - 2010 Parkland/ Residential Above Background
17 LPG/Condensate LoadoutSO4, Fe, Mn, TDS, Na, Fluoride, As, Cd, Cr, Cu,
Se, Ag, Zn
SO4, Fe, Mn, TDS, Na, Fluoride, As, Cd, Cu, Se,
Zn
Cl, SO4, Fe, Mn, TDS, As, Cu, Ag, Zn
SO4, Fe, Mn, TDS, Na, Fluoride, As, Zn
18 Sulphur Block/BasepadSO4, Fe, Mn, TDS, Na,
Fluoride, NO3, Cd, Se, U, Cr, Ag, U, Zn
SO4, Mn, TDS, Fluoride, Na, NO2/NO3, Cl, SO4, Fe, Ag, U Cl, S04, Mn TDS, Na,
19 Sulphur Plant Cl, SO4, TDS, Na, Fluoride, NO2/NO3
SO4, Mn, TDS, Na, Fluoride, Cl, NO2/ NO3 Cl,
20 Office Control/Room
21 Process Area
ph (low), SO4, Fe, Mn, TDS, Na, NO2, BTEX,
F1, F2, Glycols (ethylene, diethylene), Al, Sb, As, Ba, Cd, Cu, Ni, Se, Zn
(Stab culvert)
Cl, Fe, Mn, NO2, Al, Sb, As, Ba, Ni, Mo, Zn (Stab culvert), BTEX, F1, F2,
Glycols
22 LPG UnitSO4, Fe, Mn, TDS, Na, Fluoride, NH3 (surge
culvert), BTEX, F1, F2,
TDS (only Cl and TDS measured), BTEX, F1, F2
TDS, SO4, Fe, Mn, Na, BTEX, F1, F2 Cl, Fe, BTEX, F1, F2 Cl, TDS Cl, TDS, SO4, Fe, Mn,
Na, BTEX, F1, F2
23 Power Station
24 Sulphur Vat Pond SO4, Mn, TDS, Na, Fluoride Cl, Mn
25 Sulphur Handling Facility SO4, Fe, Mn, TDS, Na, Al, Cd, Cr, Cu, Se, U , Zn Cl, Fe, Al, B
Notes PAH analysis not completed.Metals - compared results to background 95th percentile - considered above Tier 1 Guideline of background if at least two samples exceeded guideline or background (included manganese, iron)Indicators/Nitrogen - exceeding background - generally above the highest background concentration (chloride, sodium,sulphate, TDS, nitrite, nitrate, ammonia)Organics - exceeding background - above detection limit
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Chloride in groundwater has been identified in the Flare Area, Former Process Ponds and the
Evaporation Pond. The most groundwater report (2010) shows that chloride is present above
AENV Tier I guidelines in the upper water-bearing zone across the Evaporation Pond area, and
the Flare and Formation Water Handling Area. Elevated chloride concentrations (but not above
Tier I guidelines) are also present across the majority of the property in the upper water-bearing
zone.
In the lower water-bearing zone, the chloride plume is more limited to the Flare and Formation
Water Handling Area (above AENV Tier I guidelines). There is also elevated concentrations of
chloride present across the Process Area and the Sulphur Plant. Finally, in the bedrock zone,
there is a smaller plume of chloride that exceeds the AENV Tier I guidelines, located in the Flare
and Formation Water Handling Area (near McDonald Lake). A few additional isolated areas
across the property also show elevated chloride levels in groundwater in bedrock.
Based on assessment to date, chloride appears to have the greatest potential for reaching
McDonald Lake. Considering the age of the BGP and the estimated groundwater flow velocities
in the weathered till (~2.2m/year), total potential lateral migration of this inorganic constituent is
approximately 100 metres, assuming an immediate release following plant commissioning. It is
possible that chloride from the Flare Area has approached the shoreline of McDonald Lake. No
assessment of McDonald Lake has been completed to date to confirm whether chloride impacted
groundwater is discharging into the Lake.
In the upper water-bearing zone, there were more than ten (10) occurrences of elevated
concentrations of benzene above the Tier I guidelines during the 2010 groundwater monitoring
event. No specific plume boundaries have been defined at this time. In the lower water-bearing
zone, there were only a few locations with elevated concentrations of benzene reported, and only
one location was reported in the bedrock zone.
There is a plume of hydrocarbons in the LPG Recovery Area that has shown in the past (2008) to
have measurable thickness of free phase hydrocarbons. There is an operational remediation
system in place in this area to remove free phased product, when identified. Elevated
concentrations of dissolved phase hydrocarbons and benzene and ethylbenzene are also present in
this area.
Table 12. COPCs in Groundwater by LSU
GW COPCs BTEX, F1-F2 VOCs Phenols Metals Glycols Amines Indicators NitrogenLSU Description
Background (S06-1)Entire Site
1 Southwest Quadrant 2 South Landfill X X X3 2-2 Pits/ Treatment Area X X X4 Evaporation Pond X X X5 Southeast Quadrant (Background)6 North Landfill X X7 Drilling Mud Sump X8 Boneyard/Field Maintenance X X X9 Flare & Formation Water Handling Area X X X X X X X10 Riparian/Shoreline11 Firewater Reservoir12 Southeast Process Pond13 Cooling/Blowdown X X14 Plant Maintenance15 Inlet Compression/Sales X X X X16 Condensate Storage Area17 LPG/Condensate Loadout X X18 Sulphur Block/Basepad X X19 Sulphur Plant X X20 Office Control/Room21 Process Area X X X X X22 LPG Unit X X X X23 Power Station24 Sulphur Vat Pond X X25 Sulphur Handling Facility X X
Indicators/Nitrogen - exceeding background - generally above the highest background concentration (chloride, sodium,sulphate, TDS, nitrite, nitrate, ammonia)Glycols - MEA, DEA, MDEA,Metals - includes Iron, Manganese, ....Phenols - likely from organic decay - excluded
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8.5 Surface Water Conditions
Little topographic gradient can be seen across the Site, although the Process area in the northwest
is slightly elevated with respect to the rest of the Site. Surface water often ponds on Site and is
controlled by mechanical pumping.
Currently there are seven open water surface collection areas on the BGP:
Open Drain Collection Ponds
Fire Water Reservoir
North Blowdown Pond
South Blowdown Pond
Sulphur Block Runoff Pond
Sulphur Vat Treated Water Pond
McDonald Lake.
The most important surface drainage feature near the Site is McDonald Lake located on the
western edge of the Process area. No streams enter or leave the lake, and therefore, it is assumed
that the lake is groundwater fed. Overland drainage from adjacent agricultural and pastureland is
also known to accumulate in this depression. Surface runoff occurs mainly during the spring
snowmelt, or immediately following periods of heavy precipitation. Water levels within
MacDonald Lake vary, at the time of writing, the water levels in MacDonald Lake are unusually
high and have partially flooded some areas in the west of the Site.
Table 13. COPC in Surface Water Bodies
Surface Water Pond Groundwater TablesSurface Water Surface Water Guidelines
LSU Description AOC Source Issue COPC Type
Background McDonald Lake
Entire Site 1 Deep cathodic wells
Potential cross-contamination due to improper abandonment
Hydrocarbons, salts Potential
1 Southwest Quadrant
2 South Landfill 2 Former landfill Impacts associated with former landfill
Hydrocarbons, salts, metals, debris, catalyst Proven
3 2-2 Pits/ Treatment Area Not Included in Assessment
4 Evaporation Pond 3 Evaporation pond
Impacts associated with surface water and
sedimentsSalts, metals Contingent
5 Southeast Quadrant 6 North Landfill7 Drilling Mud Sump
8 Boneyard/Field Maintenance 5 AST areaHydrocarbon impacts associated with bulk
storage of fluidsHydrocarbons Proven
6 Spills/ leaks Impacts associated with spills and leaks
Hydrocarbons, salts, amines Potential
pH (high), chloride, SO4, Fe, Mn, TDS, NA, Ammonia, Al, Ar, Cd, Cu, Se, Zn
Phase 1/ Liability Assesment
Table 13. COPC in Surface Water Bodies
Surface Water Pond Groundwater TablesSurface Water Surface Water Guidelines
LSU Description AOC Source Issue COPC Type
Phase 1/ Liability Assesment
9 Flare & Formation Water Ha 7 Unknown pit area
Impacts associated with a former buried
sumpHydrocarbons, salts Proven Open Drain Collection
Ponds Chloride, SO4, TDS, NH3, BTEX, F1
10 Riparian/Shoreline11 Firewater Reservoir Fire Water Reservoir12 Southeast Process Pond
13 Cooling/Blowdown 12 Blowdown pondImpacts associated
with unlined blowdown pond
Salts, metals Potential North Blowdown Pond SO4, TDS, NH3
South Blowdown Pond SO4, TDS, NH3
14 Plant Maintenance 14 Former sulphur pit
Potential migration from the former
sulphur pit
Waste oil, elemental sulphur Potential
15 Inlet Compression/Sales 16 KSVR Compressor
Faulty floor drains/ hydrocarbon staining Hydrocarbons, glycol Proven
20 Former tankagePotential drips/ leaks from former oil sump and separator sump
Hydrocarbons Potential
16 Condensate Storage Area 21 Condensate storage tanks
Drips/ leaks from condensate storage tanks and spills in
general area
Hydrocarbons, condensate Proven
22 Bundle wash area
Impacts associated with bundle washing Salts, metals, amines Potential
17 LPG/Condensate Loadout Sulphur Block Runoff Pond pH (low), sulphate, TDS, NH3
18 Sulphur Block/Basepad 23 Sulphur blocks – east and west Unlined sulphur blocks Elemental sulphur Proven
19 Sulphur Plant 13 Spills, leaks, tanks
Impacts associated with tankage, drainage
system, and truck loading
Metals, elemental sulphur Proven
Table 13. COPC in Surface Water Bodies
Surface Water Pond Groundwater TablesSurface Water Surface Water Guidelines
LSU Description AOC Source Issue COPC Type
Phase 1/ Liability Assesment
20 Office Control/Room 27Transformers/
electrical substation
Drips/ leaks from PCB-containing equipment PCBs Proven
21 Process Area 28 Treater building
Impacts associated with equipment and
processes in and north of Treater building
Hydrocarbon, glycol, lube oil Proven
22 LPG Unit 32 Lean oil plume Lean oil plume Hydrocarbons Proven23 Power Station Not Included in Assessment
24 Sulphur Vat Pond 33 Sulphur vat pond
Impacts associated with sediment and
surface water in pondSulphate, salts Potential Sulphur Vat Treated
Water Pond SO4, TDS, NH3
25 Sulphur Handling Facility 34 Sulphur Handling Facility
Impacts in the load out, sulphur pile, and
former slating facilities
Hydrocarbons, elemental sulphur Proven
Notes Oragnics - exceeding background - above detection limit
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8.5.1 McDonald Lake
McDonald Lake is considered a stagnant water body, and as such may tend to concentrate
inorganic groundwater contaminants through evaporation. Currently McDonald Lake supports a
limited aquatic community of saline-adapted plants. No fish species are known to occupy the
lake.
A significant decrease in routine indicator parameters (EC, chloride, sulphate, sodium and TDS)
was observed at McDonald Lake in October 2005 following significant precipitation that June.
Since then, levels have generally stabilized.
The measured chloride concentrations in spring and fall 2009 were 310 and 450 mg/L,
respectively. The laboratory-reported pH in McDonald Lake was reported within surface water
guidelines (8.67, spring and 8.33, fall). Chloride, sulphate, iron (fall only), manganese (fall only),
TDS and sodium exceeded the respective surface water guidelines in 2009.
All hydrocarbon parameters remained below laboratory MDLs in 2009. In October 2009,
dissolved arsenic and cadmium concentrations exceeded the applicable surface water guidelines.
Dissolved antimony, chromium, lead, selenium, silver and zinc were reported below laboratory
MDLs; however, the MDLs exceeded guidelines. All other metal parameters were below surface
water guidelines.
Amines have been analyzed at McDonald Lake since 2003. Historically, MEA, DEA and MDEA
were reported below laboratory MDLs. In November 2008, a single instance detectable MEA
concentration was reported. The lake was re-sampled on December 11, 2008, and again in
October 2009. Results reported values below laboratory MDLs; however, detection limits were
raised (<10 mg/L in 2008 and <5 mg/L in 2009).
Elevated chloride, TDS, sulphate and sodium concentrations have been historically reported at
McDonald Lake. Historic dissolved arsenic concentrations exceeded the applicable surface water
guidelines. Metals concentrations were generally reported within historical ranges. The
Government of Alberta, Agriculture & Rural Development indicates that “groundwater in gray-
coloured clay-rich aquitards with low oxygen levels in southern Alberta sometimes contain
naturally-occurring arsenic at levels that exceed the drinking-water guideline.”
(http://www1.agric.gov.ab.ca/$department/deptdocs.nsf/all/irr4452, November 2011).
McDonald Lake, which is a saline slough, has elevated salt concentrations in the surface water
and sediment, likely due to the natural evaporative process. Dissolved salts in the waters of
McDonald Lake are a sodium sulphate type, which is typical for an evaporative slough. Organic
compounds are assumed to naturally degrade over time.
BALZAC GAS PLANT
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8.6 Secondary Sources of Contamination Assessment and remediation work indicate that activities at the Site have impacted soil,
groundwater and potentially soil vapour. COPCs at the Site were identified on the basis of the
following:
comparison of previous analytical data, from environmental assessment and
remediation work, with generic guidelines;
comparison of analytical data with previously established background conditions;
and,
anecdotal evidence or professional judgement with similar facilities and/or
operations.
8.6.1 Free Phase Hydrocarbon Liquids
A plume of free phase hydrocarbon product was detected during the 1998 soil and groundwater
investigation as a light non-aqueous phase liquid (LNAPL: Komex 1998b), immediately
down-gradient of the LPG Recovery area (LSU 22). Subsequent investigation programs were
undertaken to delineate the extent of free product in the LPG Recovery area and remediate the
impact.
A three phased remedial approach for free phase hydrocarbon containment and plume mass
recovery was implemented. The remediation approach included the following:
Phase 1: installation of a product recovery trench;
Phase 2: installation of a free phase hydrocarbon extraction and dissolved phase
hydrocarbon treatment system using trench and gate technology; and
Phase 3: installation of vertical recovery wells for free phase hydrocarbon extraction
using an in situ skimmer pump.
To date, approximately 12 m
3 of free phase hydrocarbon liquids have been removed from the
LPG recovery area. As of fall 2010 hydrocarbon liquids continue to be measured in recovery
wells and monitoring well 98-24A installed within the till groundwater unit of the LPG area.
Measurable free phase hydrocarbon liquids have been noted in monitoring wells installed within
the till/bedrock (98-24B: 1998-1999) and bedrock (98-24C:1998, 1999, 2002 and 2007) of the
LPG plume. Field observations (sheen and hydrocarbon odour) and elevated hydrocarbon
groundwater concentrations reported at 98-24B and 98-24C indicate free phase hydrocarbon
liquids may have been present during monitoring events where measurable product was not
reported. Free phase hydrocarbon liquids have also been noted in the surge culvert of the LPG
area.
North of the LPG Unit, free phase hydrocarbon liquids have been measured in the Process area
(LSU 21) at 06-48A (2006-2010). In the Flare and Formation Water Handling area (LSU 9), free
phase hydrocarbon liquids were measured at 99-32A in 2000. Field observations (sheen and
hydrocarbon odour) and elevated hydrocarbon groundwater concentrations reported in 99-32A
BALZAC GAS PLANT
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and other select wells in the Flare and Formation Water Handling area (2000–2010), Process area
(2006-2010) and Inlet Compression/Sales (LSU 15: 2006-2010) may also indicate the presence of
free phase hydrocarbon liquids in the vicinity of the wells.
8.7 Data Gaps A review of historical information for the Site has identified gaps in available data for the Site.
8.7.1 Background Data
Limited background soil data for the Site is available. Four sampling locations located in the
southwest (LSU 1), southeast (LSU 5) and on the west end of McDonald Lake have been
identified as background locations. Additional analytical data of the surrounding area and Site is
necessary to evaluate natural salinity and inorganic parameters.
Groundwater monitoring locations in the southeast (LSU 5) of the Site and on the west end of
McDonald Lake are believed to represent background quality for the Site on the basis they are
located up-gradient. Several indicator and metal parameters have been historically reported above
Tier 1 guidelines (AENV 2010a) in background monitoring locations and likely indicate these
parameters are naturally elevated in the area of the Site. Due to variations in background
concentrations, select parameters at the Site exceeding available background data may not
necessarily represent an impact associated with Site activities. Further collection and statistical
analysis of background data is required to confirm natural groundwater quality.
8.7.2 Bedrock Flow Mechanism
Limited information on fracture flow mechanisms within bedrock beneath the Site is available.
The upper surface, till/bedrock contact, is likely highly weathered and is likely to act as an
equivalent porous media. Deeper bedrock is likely dominated by fracture flow.
Impacts have been identified within the bedrock zone of the Site, including free phase
hydrocarbon product in the bedrock of the LPG Unit (LSU 22); however, the relationship
between the free product and deeper fracture flow has not been established. Further information
regarding fracture density, orientation, and flow rates are required for a site-specific risk
assessment to determine if fracture flow is a dominant migration pathway at the Site.
8.7.3 Geographical and Temporal Data Coverage
Overall there is reasonably good areal coverage of intrusive and or excavation data across the
Site. However, once remedial objectives for the Site have been established, further investigation
may be required of previous remedial excavations and/or delineation of impacts. Areas with
limited data or requiring further evaluation include the following:
Previously excavated areas. Excavation limits and treatment of excavated soil were
typically guided by assessment criteria current at the time the excavation was
completed as a source removal program. Since completion of an excavation, clean
backfilled soil may have been impacted by broader scale contamination in the soil
and groundwater surrounding the excavated area. Excavation soil quality, including
BALZAC GAS PLANT
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backfill should be verified to confirm if the soils meet remedial objectives for the
Site; and,
Soil underlying process buildings. Previous intrusive investigations have not
included assessment beneath process buildings.
Limited or no analytical data is available for some parameters identified as COPCs at the Site.
These parameters include:
PAHs in groundwater. Previous detections of PAH parameters in soil have been
identified in LSUs 9, 17 and 25. PAHs have not been analyzed in groundwater
across the Site;
Methanol is a process chemical used at the Site and a methanol spill in the Process
area was previously identified in the Phase 1 ESA. Limited analytical data for
methanol in soil is available for the Site;
NORM Surveys have been completed in 2011 at the Balzac Gas Plant. A typical
source of NORM in the oil and gas industry is radon gas decay products, including
Lead-210 (NORMCAM 2006). (Naturally occurring radionuclides (``NORMs``)
are present at varying concentrations in the Earth’s crust and can be concentrated
and enhanced by processes associated with the recovery of oil and gas.
Radioactive materials such as Uranium and Thorium were incorporated in the
Earth’s crust when it was formed; these normally exist at trace (parts per million –
ppm) concentrations in rock formations. Decay of these unstable radioactive
elements produces other radionuclides that, under certain conditions (dependent
upon pressure, temperature, acidity etc) in the subsurface environment are mobile
and can be transported from the reservoir to the surface with the oil & gas
products being recovered. During the production process, NORM flows with the
oil, gas and water mixture and accumulates in scale, sludge and scrapings. It can
also form a thin film on the interior surfaces of gas processing equipment and
vessels. The level of NORM accumulation can vary substantially from one facility
to another depending on geological formation, operational and other factors. To
determine whether or not a facility has NORM contamination, NORM survey,
sampling and analysis needs to be conducted There are various national and
international regulations and guidelines on radiation protection in general and
NORM in particular. These are not specific to the oil & gas industry and there are
variations in the methods of control adopted.)
Historical surveys have been referenced and utilized to support the 2011 surveys.
2011 surveys where completed at various phases of the plant shutdown and
decommissioning stages. Surveys were initially executed in April and then again in
May, June, July, August and September. This method of survey allowed for the
identification of potential NORM in various operating conditions and confirmed
previous surveys as being accurate.
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o The initial 2011 survey was completed in April while the plant was still in
operation. This allowed the personnel to determine possible NORM
locations before any equipment or piping was opened and exposed to
atmosphere. Once this survey was completed areas that detected NORM
where opened with extreme care and caution. A third party company with
NORM expertise was present and did all NORM testing (NORMCAN – A
CCS Company). If NORM was detected the equipment/piping was
immediately closed, sealed and labeled. All testing was recorded and is
still maintained for future reference. Once all possible NORM
contaminated equipment and piping was tested it was re-tested to verify if
there were detections from the previous survey. This re-testing method was
executed monthly until the end of September. Any equipment or piping
that still detected NORM was sealed and labeled as NORM containing. If
piping was loose it was segregated, sealed and labeled. This piping was
located in a central location that has been isolated and clearly labeled as
NORM containing.
o Future NORM surveys will be executed prior to any exposure, handling or
movement of NORM containing materials. Routine checks on all stored
NORM-contaminated equipment will be undertaken to ensure that the
integrity of the protective measures is adequate. Detailed and verifiable
records will be maintained of all stored NORM contaminated equipment.
o Any NORM containing equipment that was sold was decontaminated prior
to the sale and prior to the removal from site. NORMCAN and CSC
completed the decontamination and all water was then taken to the
NORMCAN approved disposal site in Standard, Alberta. This equipment
included four (4) horizontal vessels or bullets used to store propane and
butane. There is currently an ongoing search for buyers that are willing to
purchase the four NORM contaminated propane bullets. If a buyer is
willing to accept the units in the declared state, the bullets would be
transferred from one contaminated propane process to another
contaminated propane process and therefore no attempt would be made to
decontaminate them. If a buyer for contaminated bullets cannot be found,
or if decontamination is attempted but unsuccessful, worse-case scenario is
that these contaminated units would have to be released to a landfill.
NORM surveying of the soil will be completed to confirm if further
analytical testing of soil is required. In some cases of NORMS remediation
involves the systematic removal of NORM contamination from the area in a
controlled manner, with the contaminated soil/material becoming part of the
NORM waste stream,
Sterilants were identified as likely used on Site in the past; however soil analytical
data for sterilants is not available.
Hydrocarbon product laboratory analysis. A hydrocarbon breakdown analysis of
the free product measured in the LPG Unit (LSU 22) was completed in 1998.
Additional analysis of the LNAPL should be conducted to evaluate how the
product has weathered since initial assessment in 1998.
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8.7.4 Survey Data
An orthographic aerial photo and survey of the Site has been completed and is used to establish
topographic features of the Site. The existing survey data will be compiled to support this and
further surveying may occur if deemed necessary.
8.7.5 McDonald Lake
Annual data of water levels within McDonald Lake is available; however additional data on
seasonal fluctuations of the lake may be obtained.
9 REMEDIAL OPTIONS
Once the decommissioning, dismantling, and removal of the majority of the infrastructure has
taken place across the property, more detailed delineation assessments will be initiated. The
general plan and criteria to be used for remediation of soils, groundwater, surface water, and
possibly sediment are described in this section.
There are four options available to Nexen for remediation of the BGP. Each of these options is
discussed in greater detail in the Tier I and Tier II Soil and Groundwater Remediation Guidelines
(AENV, December 2010). These options include:
1. Remediation (insitu or exsitu) of soil, groundwater, surface water, and sediment to
the AENV Tier I guidelines (or the CCME environmental quality guideline for
parameters not included in the AENV guidelines).
2. Remediation (insitu or exsitu) of soil, groundwater, surface water, and sediment to
AENV Tier II site specific guidelines which would be developed for the BGP site for
each COPC. Tier II site specific guidelines would be established through pathway
exclusion and/or parameter adjustment in consultation with AENV.
3. Completion of a Tier II Site Specific Risk Assessment (SSRA), possibly allowing for
soils, groundwater, surface water and/or sediment to remain in place. Remediation,
where necessary (insitu or exsitu), would be completed to the Tier II site specific
guidelines. This option will almost always require a monitoring plan until stable end
points are demonstrated.
4. Exposure Control and Long Term Risk Management (Human Health) and Ecological
Risk Assessment (Ecological Health and McDonald Lake).
Options 1 to 3 allow for full regulatory closure under the Alberta Environment Environmental
Site Assessment Program (Record of Site Condition). Regulatory closure would allow Nexen to
divest of the property in the future. Option 4 does not allow for regulatory closure. It is fully
protective of human and ecological health, with a management plan/exposure control plan in
place. This option would allow Nexen to redevelop and/or lease the property in the future.
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9.1 Determination of End Land Use & Remediation Criteria
In order to determine the best final option for remediation at the Balzac Gas Plant, several steps
are required to be completed. These steps will allow for full understanding of the contaminant
picture across the property, in turn allowing a detailed analysis for each of the options outlined
above. This is a phased approach that CANNOT be completed until demolition is complete and
as each phase of demolition and testing occurs, the information will be used to support future and
final site remediation.
End land use is a key component in the larger process of decommissioning the BGP and is also a
key component in determining the appropriate route forward for remediation. End land use will,
in part, determine acceptable remedial options. However, what remedial options are practical,
cost effective, and reasonable will also have an impact on choices associated with end land use at
the property. In other words, end land use and remedial options need to be reviewed together in
order to find the correct balance and the best route forward for Nexen, the property, the
surrounding properties, and community. This process has begun at Nexen, but before it can be
fully completed, certain assessment and exploration steps are still required at the BGP.
End land use will be determined as a function of surrounding land use at the time the BGP is
going through the remediation and reclamation processes. Current land use plans provided in the
following Balzac East Area Structure Plan figure clearly demonstrate a surrounding land use
zoned, or to be zoned, as industrial. Therefore, at this time, end land use for the BGP is expected
to be industrial. End land use will be determined as a function of municipal development plans
for the area and the landowner(s).
The Balzac Power Station (BPS) will remain active during decommissioning of the BGP and
remediation and reclamation of the larger property parcel. There is no current plan to
decommission the BPS. There is associated infrastructure (pipelines carrying gas, firewater,
water disposal and water supply; above ground electrical transmission lines – see figure on
following pages) running to and from the BPS that travel above grade across the larger property
that will remain in place after decommissioning of the Gas Plant. (FIGURE 6) This
infrastructure has been considered during the development of the remedial plan, as impacted soils
and groundwater are known to be present under or around this infrastructure. Some excavation
might be possible and completed as part of remedial objectives, but the majority of the impacts
located under this infrastructure is expected to be managed in place through risk assessment and
exposure control methods.
Given the large size of the property, and the impacts that have been already identified across the
property, it is very likely that remediation to Tier I guideline criteria will not be the most cost
effective and practical choice for Nexen.
MCDONALD
LAKE
226-29-4
PipelineR/W (031
0629)
PipelineR/W (031 0391)
GasPipeline R/W (4609
JK)
Pipeline R/W(791
0816)
Gas Pipeline R/W(851
0253)
Gas TransmissionLine R/W(299 JK)
PipelineR/W (791 0816)
Oil PipelineR/W (754
JK)
PipelineR/W (031 0174)
PipelineR/W
(1547 JK)
Gas TransmissionLine R/W(686 JK)
PipelineR/W (101
2606)
Pipeline R/W(502 JK)
PipelineR/W (061 2620)
PipelineR/W (921 0545)
PipelineR/W (821 0555)
CanadianPacific Railway
(871 JK)
Pipeline R/W(081
5893)
PipelineR/W (081
3328)
GasPipeline R/W (791
0816)
PipelineR/W
(500 JK)
Pipeline R/W(500JK)
Gas PipelineR/W
Gas PipelineR/W
Admin Building
Power Station
FiberOptic Pipeline
(10m R/W)
FiberOptic Pipeline (10m
R/W)
Building
Pipeline R/W
PowerlineR/W
PowerlineR/W (9012327
UR/W)
Pipeline R/W
Well Site 2-2
PipelineR/W (931
2570)
0 100 200 30050Meters
±
LegendDisposition - Operator
Atco
Canadian Pacific Railway
City of Calgary
Fortis
Nexen
Pembina
Telus
services
Nexen Inc.
NEXEN INC. 801-7th Ave S.W. Calgary, AB. Canada T2P 3P7T. 403.699.4000 www.nexeninc.com
BalzacFigure 3
Existing InfrastructureExpected to Remain
Author: R. McCallumGIS Specialist: A. JackDept: GIS Services
Date: November 24, 2011Updated: February 6, 2012File No : CA13581.mxd
NAD 1983 UTM Zone 12NProjection: Transverse Mercator
Imagery provided by ValtusDate Collected: September 22, 2009VISTA Alberta UTM 12 0.3m 2009
Scale: 1:2,500
144th Avenue
2 W
ire O
/H P
ow
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ine
Twp. 26
Twp. 25
S.W.1/4 Sec.2-26-29-4
McDonald Lake
Cha in L ink
GATE
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EN
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/W P
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S
NEXEN 8" H
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RO
M B
PS
EXPO
CR
ETE
FLARE AREA SEE DETAIL 'C' (AS-BUILT NOT MAINTAINED LAST REVISION MAR. 2010)
NEXEN SALES P/LCROSSING(FORMERLY AGTL)SEE DETAIL 'A'
JUNCTION 11SEE DWG.BLZ-H11-A-001-A
JUNCTION 2SEE DWG.BLZ-H02-A-001-A
FIRE WATER PONDSEE DETAIL 'B'
JUNCTION 1ASEE DETAIL 'F'
LPG AREASEE DETAIL 'D' (AS-BUILT NOT MAINTAINED LAST REVISION MAR. 2010)
JUNCTION 2ASEE DWG.BLZ-H02-A-001-A
JUNCTION 15ASEE DWG.BLZ-H15A-A-001-A
BALZAC POWER STATIONSEE DWG.BLZ-P200-A-011-A
BALZAC GAS PLANT SEE DRAWING CONTROL
Airdrie Modelers Aircraft Society
RANCHER'S BEEF FACILITY
CALGARY ENERGY CENTER (ENMAX)
NEXEN BALZAC COMPLEX ENTRANCE
LP F lareKO B ldg .
LPFW Fl ash Ta nk B ldg.
Fla re A re a Sw itchge ar Bu ild ing
Fla re Heater Treater B ld g.
Fla re Pond Pu m p B ldg.
Wash Ba y
CP Po st
CP Po st
CP Po st
CP Po st
CP Po st
2" F/G TO J11 & 2-2-26
2" GLYCOL (ABND)
8" S ELKTON S/G FROM J12
2" GLYCOL (ABND)
2" GLYCOL (ABND)3" S/G FROM 10-35-25 (ABND)2" GLYCOL (ABND)
2" F/G FR
OM
2-2-26 CU
LVERT
6" S/G (ABN
D)
2" F/G FR
OM
J1A
2" GLYC
OL (ABN
D)
NEXEN 22" SALES TO TCPL
2" F
/G R
ISE
R
C/W
VA
LVE
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ND
GLYCOL JUMPOVER DETAILWITHIN WEST DITCHNOT TO SCALE
4" L
.P. X
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/G F
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ITY
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2" FRESH
ENERSULFACILITY
CAUTION:Buried Fibre Optic Cable
TELEMETRY CABLE FROM TCPL
22" SALES GAS TO TCPL
TELEMETRY CABLE FROM TCPLNEXEN 22" SALES GAS TO TCPL
Gat e
Gat e
Gate
Gat e
Gate
Gat e
Ab ove groun d Waste Oi l Ta nk Ab ove grou nd
Waste Oi l Se tt li ng Tank
Wel ding Te nt
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Se para to r
LPG Tru ck Load ing Do ck Bu ild ing
LPG Lo adin g MC C Build ing
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Ab ove groun d Lean Oil Ta nk
Bu ried
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)
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8" STE
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6" STE
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6" FIR
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8" FIRE WATER (ABND)
6" FIRE WATER (ABND)
6" F
IRE W
ATER
6" FIRE WATER
6" FIRE WATER
6" F
IRE W
ATER L
INE
Ab and oned C abl es
6" FIRE WATER
P.P.
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P.P.
P.P.
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Te lus JB
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Vi deoCam era
2" FIRE WATER
Ab and oned Cabl es
Ho H
2H
3
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Ba lzac Po wer S tati on Cool er
FW V
FWV
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FW V
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P.P.
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P.P.
P.P.
P.P.
P.P.
P.P.
P.P.
Vi deoCam era
Vi deoCam era
Te lus Pe destal
Te lus Pe destal
Telus Pedestal
Te lus Pe destal
Te lus Pe destal
FW V
FW V
FW V
6" HDPE FIRE WATER
8" HDPE FIRE WATER
6" ST EEL FIRE WATER
8" S
T EEL FI
RE WATE
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2" Waterli ne Dead En dedU/G
En ersul Su lph ur
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Elec. Panel
P.P.
P.P.
P.P.
P.P. P.P.P.P.P.P.P.P.P.P.P.P.
P.P.
P.P.P.P.
P.P.
P.P.
P.P.
P.P.
P.P.
P.P.
P.P.
P.P.
P.P.
P.P.
P.P.
P.P.
P.P.
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P.P.P.P.
P.P. P.P.
P.P.
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P.P.
P.P.
P.P.
P.P.
P.P.
P.P.
P.P.
P.P.
P.P.
P.P.
P.P.
P.P.
P.P.
P.P.
P.P.
P.P.
P.P.
P.P.
P.P.
P.P.
P.P.
P.P.
P.P.
P.P.
P.P.
P.P.
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P.P.
P.P.
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Se rvice Hatch
P.P.
P.P.
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Ele ctr ica l Pa ne l
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Telem
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able
(Ab n'd
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NEXEN 8" STEEL WASTE
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TELEMET RY C
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e &
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s Pe
dest
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i pe Rack li quid
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A/G P i pe Rack li quid su lph ur l ine
A/G P
i pe Rack li quid
sulph
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A/G Pipe Rack liquid sulphur line
A/G
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ack
liqu
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ulph
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VAT Pum
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VAT Po nd
Caust ic Stora ge Ta nk
Se pt ic Ta nk
Win d Fen ce
Su lph ur Hopp er
Eye W ash Stat io n
Ba lzac Gas P la nt Water Pum p Stat io n
Cat Walk
Retain
ing W
all
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Se curit y Sta.
Ski m Po nd
A/G P i pe Rack li quid su lph ur l ine
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Man Gate
Te lus Pe destal
Te lus Pe destal
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Bu ild
i ng
Win d Fe nce
2" FIRE WATER (ABND)
2" FIRE WATER
EAST SU LPHU R BLOC K PAD
RAN
GE
RO
AD
291
01 -33A
92-9A
98-25 B
98-25 A
01-35 A
99-32 A
99-30 A99-30 C
92-6A92-8B92-8A
92-8C
99-31 A
92-7A
MW -3A
92-14 A
92-3A
92 -3B
M W 8A
94 -18C
M W -10A
M W 5A
M W 11A
92 -5A
92 -2A
M W 4A
94 -17C
92 -1A
M W 9A M W 9B
92-4A
06-45 A
06-46 A
03-41 A
03-40 A
04-42 A
MW -1A
03-38 A
P2
P1
RG1
98-2
4 C98-2
4 B
98-2
4 A
No.19
No.18
Mi chig anBu ild ing
92-13 A
liquid sul phur li ne A/G
Pi pe R
ack
No.17
No.9
No.10
No.6
No.16
No.3
No.12
No.11
Bu ild ing
Bu ild ing
JU NCT ION 2 C ELLAR
Fire Water
Reservo ir
Pu mp Build ing
El ect rical F ire Water Pum p Bu ild ing
Diese l Fi re Water Pum p Bu ild ing
Bu ild ing
Me te rBu ild ing
Sw itch Gea r Bu ild ing
So uth Depro p. Cond . Buil din g
Gas Cool er Bu ild ing
Sa lesBu ild ing
#5 Su b-S tat ion Sw itch Gea r Bu ild ing
Crushe r Pu m p Bu ild ing
Gara ge
Ener
sul O
ff ice
NEXEN PLAN 59 LK
NEXEN PLAN 502 JK
PEMBINA PLAN 754 JK
NEXEN MARKETING R/W PLAN 031 0629
NEXE
N M
ARKE
TING
R/W
PLA
N 03
1 06
29
CANADIAN PACIFIC RAILWAY PLAN 871 JK
NEXEN PLAN 502 JK
NEXEN MARKETING R/W PLAN 031 0391
NEXE
N MAR
KETI
NG R
/W P
LAN 0
31 0
391
NEXEN PLAN 4965 JK
NEXEN PLAN 502 JK
NORTH CANADIAN PLAN 851 0253
HOME OIL PLAN 821 0555NEXEN PLAN 4957 JK(NO PIPE IN R/W)
NEX
EN
PLA
N 0
31 0
174
NEXEN PLAN 4965 JK
NEXEN PLAN 931 2570
NEXEN PLAN 502 JK
NEX
EN
PLA
N 6
86 J
K
NEXEN
PLAN 1547 JK
ATCO PLAN 851 0253
PIPE LINE R/W 500 JK
NEX
EN
PLA
N 4
53 L
K
NEXEN PLA
N 500 J
K
ATC
O P
LAN
791
081
6
ACCESS TO ELKTON WELL10-35-25-29 W4M
ATC
O P
LAN
851
025
3
NEX
EN
PLA
N 0
61 2
620
NEX
EN
PLA
N 9
21 0
545
68th
STR
EE
T N
.E.
NEX
EN
PLA
N 5
02 J
K
UNDEVELOPED 144th AVENUE N.E. UNDEVELOPED 144th AVENUE N.E.
TRANSALTA PARCEL 'A' PLAN 811 1282
NEXEN PLAN 851 1017
TRANSCANADA PIPELINE METER STATION
ATCO PLAN 791 0816
ATCO METER STATIONPLAN 791 0816
TRANSALTA PARCEL 'B' PLAN 811 1282
GO
VER
NM
EN
T R
OA
D A
LLO
WA
NC
E
PON D
Drain
age C
ourse
Drain age Co urse
O/H
Cab
le
Bu ried Power Cab le
3-Cab les2-C
ab les
2-Cab les
En d of
Win ch
Burie
d P
ower
Cab
les
El ec. Pa nel
Burie
d
P ow
e r
Cab
le
El ect rical Pa nel
El ect rical Riser
El ect rical Ju nct ion
Win ch
U/G
Cab
le
Lina log Laun cher
2" F
uel G
a s
VENT RISERS ON8" WASTE WATER FROM BPS
TEST POST
TEST POST
Lina log Laun cher
VEN T RISER SON 8" WASTE WAT ER PL
Bu ried P i pe & C able
2" D
ISPO
SAL TO
11-1
3-25
-29
W.4
M. (
ABND)
NEXEN 12" BQ S /G FR OM J80C
VEN T RISERS O N
8" WASTE WATER F RO M
BAL ZAC PO WER STATIO N
3" A
/ G L
VP
LI N
E T
O P
LAIN
S
2" F / G ( A B N D )
NEXEN 22" SALES GAS TO T CPL
2" GLYCO L (ABN D)8" S ELKT ON S /G F RO M J12
2" GLYCO L (ABN D)2" F/G TO J11
SU RG E 6" S /G TO J13" FIBER GLASS (ABND)2" FIBER GLASS (ABND)
2" G
lyco
l3"
Pi p
e2"
Gly
col
2" Pi pe
Unkno wn P ipe
Unkno wn P ipe
2" Pi pe
14" S /G FR
OM J39
3" F/G TO J39
Bu ried Re co very D it ch
10" F
/G T
O BPS
10" F
/G T
O BPS
NEXEN 6" S
/G F
ROM
2-2
-26 T
O U/G
TIE
-IN @
J1A
6" K
AL
IST
O S
/G F
RO
M J
11
Unk
now
n P
ipe
Unk
now
n P
ipe
s (2
)
Unk
now
n P
ipe
3" PL A IN S M IDST REAM (D ISCO NT INUED)
8" PL A IN S M IDST REAM
3" PL A IN S M IDST REAM P IPELINE (DISC ON TINUED )
8" PL A IN S M IDST REAM P IPELINE
8" PL A IN S M IDST REAM P /L
CIT Y OF C ALGAR Y 18 " PL ASTIC WATERL IN E
2 ATC O P IPEL INES
1 ATCO PIPELINE
NEXEN 8" S/G (ABND)
CIT Y OF C ALGAR Y 18 " PL ASTIC WATERL IN E
PLAIN
S 3" (A
BND)
PL A INS 3" (ABND
)
2 A /G LINES (ABND)
3" A /G LVP L IN E T O PLA INS
NE
XE
N 2
2" S
ALE
S T
O T
CP
L
3" A /G LVP L INE TO PLAINS
10" F
/G T
O BPS
Burie
d P
i pe
& C
able
6" E E
LKT
ON
10"/
12"
FLA
RE
LIN
E10
"/12
" F
LAR
E L
INE
Bu riedConcre te
Vau lt
2" F
/G T
O J
11
& 2-
2-2
6
An ode Bed
Anod
e B
ed
Cathod ic Cabl e
Anod
e Bed
Cathod ic Cabl e
Concre te Enca sed Con dui t
Concre te Enca sed Con dui t
Guard
Rail
Gua rd R
ail
Concre
te E
ncased C
ondui t
8" FRE
SH
WAT
ER
TO
BP
S
6" FIR
E WATER
LPG Pum pCont rol Swi tch
SURG
E TANK
BUTA
NE TANK
BUTA
NE TANK
BUTA
NE TANK
BUTA
NE TANK
PROPANE T
ANK
PROPANE T
ANK
PROPANE T
ANK
PROPANE T
ANK
7000BBL
7000BBL
Pe rfo rated
Culve rt
Pe rfo rated
Culve rt
Si dewa lk
Perfo
rate
d
Culve rt
Perfo
rate
d
Culve rt
Burie
d Re co
very
Ditc
h
Bu ried
Recovery
Ditch
<STE
ELHDPE
>
Elec. C
ont rol
Pa nel
A/G
Pi p
e Rac
k / C
able
Tra
y
A/G P i pe Rack / C able T ray
A/G P i pe Rack / C
able T ray
A/G P ip e Rack / Cab le Tray
W1
W2
W3
8" WA
STE
WA
TER
FR
OM
BP
S
8" FRE
SH
WAT
ER
TO
BP
S
CP Po st
CP Po st
CP Po st
CP Po st
CP Po st
CP Po st
CP Po st
CP Po st
3 Wir e O
/H P
owe
r
Cabl e
Tra
y
A/G P i pe Rack / C able T ray
A/G P i pe Rack / C able T ray
A/G P i pe Rack / C able T ray (5 )
TELEMET RY CABLE T O T CPL
Oil
Se
ttlin
g Ta
nk
Ta nks
Ta nks
3" W AT E R D I S P O S A L TO 10 - 36 - 2 5
Elec. Pedestal
A/G
Cab
l e T
ray
A/G
Pi p
e Rac
k
A/G
Cab
l e T
ray
Cattle Guard
Bridge
P.P.
P.P.
BERM
Concrete Vault (Suspended)
PON D
10" BURIED PVC DRAIN LINE
Ma nho le
Ma nho le
6" FIRE WATER LINE
Wood Retaining Wall
Wood Retaining Wall
Woo
d Re
taini
ng W
all
Transformer
Plas
tic P
ipe
Aban
don
ed C
abl e
s
Aban
don
ed C
abl e
s
Aban
done
d C
abl
es
8" F
RE
SH
WAT
ER
TO
BPS
P.P.P.P.
P.P.
P.P.
P.P.
P.P.P.P.
P.P.
P.P.
P.P.
P.P.
P.P.
P.P.P.P.
P.P.P.P.
P.P.P.P. P.P. P.P.
P.P.
P.P.
P.P.
P.P.
P.P.
P.P.
P.P.
P.P.
P.P.
P.P.
P.P.
P.P.
P.P.
P.P.
P.P.
P.P.
P.P.
P.P.
P.P.
L.P.
L.P.
L.P.
L.P.
L.P.
L.P.
L.P.
L.P.
L.P.
L.P.
L.P.
L.P.
L.P.
L.P.
L.P.
L.P.
L.P.
L.P.
L.P.
L.P.
L.P.
L.P.
L.P.
L.P.
L.P.L.P.
L.P.
L.P.
L.P.
L.P.
L.P.
L.P.
Railcar Sulphur
Loading Building
EnersulStand Pipe
EVAPORATION POND NOT IN SERVICE
RAN
GE
RO
AD
291
G
OV
ER
NM
EN
T R
OA
D A
LLO
WA
NC
E
2" FIRE
WATE
R
A/G P
i pe Rack
3" PLAINS (ABND)
BONEYARD
Gate
8" STEEL FIRE W
ATER
6" STEEL FIRE W
ATER
Cat
hod
ic C
abl e
6" F W V
6" F W V
Bu ried Re co very D itch
Airdrie Modelers Helipad
Airdrie Modelers Airstrip
CAUTION:Buried Fibre Optic Cable
CAUTION:Buried Fibre Optic Cable
CAUTION:Buried Fibre Optic Cable
8" W A S TE W A TE R F R O M
BA L Z A C P O W E R S TA T I O N
P.P.
P.P.
P.P.
P.P.
L.P.
L.P.
L.P.
L.P.
P.P.
EAST
FE
NC
E
SEE
DE
TAIL
'E'
AGTL PLAN 299 JK
P.P.
L.P.
8" HDPE FIRE WATER
6" HDPE FIRE WATER
VAT PUMP D ISCHARGE LINE
(PVC) <CONFIRMED>
DRAINVALVE
VAT
PUM
P D
ISCH
ARG
E LI
NE
(PVC
) <UN
CONF
IRM
ED>
COMPLEX ENTRANCE SEE DETAIL 'H'
HP.Fla reStack
LP.Fla reStack
3" Dispo sal PL and Vent Riser
3" L
.P. S
UR
GE
(A
BND
)
2" F
OR
MAT
ION
WAT
ER
FRO
M IN
LE
T S
EPA
RA
TO
RS
FILTER CAKE DRAIN (ABND)
2" F/G (ABND)
24" C
OOLI
NG W
ATER (A
BND)
24" C
OOLI
NG W
ATER (A
BND)
2 A /G Pi pes
Zap ata Riser & ESD Va lve
4" C
LOSED H
C DRAIN
FR
OM IN
LET
SEPARAT
OR B
UILD
ING
4" C
LOSED H
C DRAIN
TO
L.P
. SURG
E DRUM
CITY OF CALGARY R/W PLAN 901 2327
FORTIS R/W PLAN 081 3328
FORTIS R/W PLAN 081 5893
2 26-29-4
LIFT STATION SITE PLAN 071 0376
R/W PLAN 071 1197
NEXEN
MAR
KETING
R/W
PLAN 031 0629
Buried Power Cable
Su lph ur Crushe r/Lo ade r
NEXEN MARKETING R/W PLAN 031 0391
NEXEN MARKETING R/W PLAN 031 0391
No.20
Pu m p Bu ild ing
6" STE
EL FIR
E W
ATE
R
Transformer P.P.
F/WRiser
2" FIRE
WATE
R
UgP
2" FIRE
WATE
R
(ABN
D)
NEXEN 8" HDPE WAST E WAT ER F RO M BPS
Asp hal t Pa d
Low G
rade Gravel R
oad
Asp
hal t
Sw
ale
Asp hal t Swal e
Asp
hal t
Sw
ale
Pave
d P
lan
t Acc
ess
8" N. ELKTON S/G TO BGP
6" FRESH WATER TO BGP
2" F/G FROM BGP
2" GLYCOL (ABND)
2" FORMATION WATER (ABND)
8" L.P. XFLD S/G TO PLANT (SUSP)
2" GLYCOL FROM BGP
6" E. ELKTON S/G FROM 11-01-26
2" GLYCOL FROM J15
10" L.P. XFLD S/G FROM J32
2" FLASH GAS (ABND)
2
NORTH DITCH
SEPARATE DITCHSOUTH DITCH
SEPARATE DITCH
S.E.1/4 Sec.2-26-29-4
WELLSITE 2-2-26-29-W.4M. SEE DWG. BLZ-W120-A-001-A
NORTH DITCH
SEPARATE DITCH
SOUTH DITCH
(OLD AGTL R/W)
SEPARATE DITCH
3" WATER DISPOSAL TO 10-36-25
2" FIBER GLASS (ABND)
3" FIBER GLASS (ABND)
SURGE 6" S/G TO J1
2" F/G TO J11
2" GLYCOL (ABND)
8" S ELKTON S/G FROM J12
2" GLYCOL (ABND)
2" F/G (ABND)
8" WASTE WATER FROM BALZAC POWER STATION
TELEMETRY CABLE FROM TCPL
NEXEN ��SEPARATE DITCH
NORTH D
ITCH
SEPARAT
E DITC
HSOUTH
DIT
CH
3" WAT
ER DIS
POSAL TO 10
-36-25
2" FIB
ER GLA
SS (ABND)
3" FIB
ER GLA
SS (ABND)
SURGE 6" S
/G TO
J1
2" F/G
TO J1
1
2" GLY
COL (ABND)
8" S E
LKTO
N S/G
FROM J1
2
2" GLY
COL (ABND)
2" F/G
(ABND)
8" WASTE W
ATER FROM B
ALZAC P
OWER S
TATIO
N
SEPARAT
E DITC
H
8" W ELKTO
N (ABND)
8" W E
LKTON (A
BND)
6" E ELKTON S/G
F ROM
11-1 -26
16" P IPE (ABND)
16" P IPE (ABND)
16" P IPE (ABN D)
Culvert withU/G IsolationValves
2" F/G TO ENERSUL FROM J15
Pu m ps
Pu m ps
FROM J2WATER
16" P IPE (ABND)
NEXEN 6" S
/G F
ROM
2-2
-26
2" G
LYC
OL
FRO
M B
GP
2" F
/G F
RO
M J
158"
N. E
LKTO
N S
/G F
RO
M J
15
2" F
RE
SH
WAT
ER
TO
EN
ER
SU
L2"
GLY
CO
L (A
BN
D)
2" G
LYC
OL
TO J
15
6" L
.P. X
FLD
S/G
FR
OM
J32
2" G
LYC
OL
FRO
M J
15
10" L
.P. X
FLD
S/G
FR
OM
J32
abovegroun d
8" N. ELKTON S/G TO BGP
6" FRESH WATER TO BGP
2" F/G FROM BGP
2" GLYCOL (ABND)
2" FORMATION WATER (ABND)
8" L.P. XFLD S/G TO PLANT (SUSP)
2" GLYCOL FROM BGP 2" GLYCOL TO J15
GLYCOL JUMPOVER DETAILWITHIN NORTH DITCHNOT TO SCALE
Fue l Ga sHead er
P.P. P.P.P.P.P.P.P.P.P.P.P.P.
06-43A
93-15A93-15C
93-16A
93-16C
NEXEN 4" L.P. XFLD S/G FROM 11-36-25-29W4M
6" KAL IS
T O S/G
FROM
J11
2" H
DPE
U/G
WAT
ER L
INE
<CON
FIR
MED
>
2" H
DPE
U/G
WAT
ER L
INE
<UNC
ONFI
RM
ED>
Culvert
ENERSUL SULPHUR STORAGE AREA
BPS WASTE WATER CONCRETE VAULT
ATCO METER SITE EXTENSION
P.P.
P.P.P.P.
P.P.
P.P.P.P.
P.P.
P.P.P.P.
P.P.
P.P.P.P.
P.P.
P.P.P.P.
P.P.
P.P.P.P.
P.P.
P.P.P.P.
ATCO PIPELINES
ATCO METER SITE EXTENSION ATC
O PLAN
4609 JK
Anod
e B
ed
Cathod ic Cabl e
Cathod
ic Cabl e
Cat
hod
ic C
abl e
Cat
hod
ic C
abl e
An ode Bed
An ode Bed
Rect if ierAn
ode B
edAn
ode B
ed
Anod
e B
ed03-39 A
03-39 B
8" S ELKTON S/G FROM J12
2" HDPE Water Line
Po rta ble Em e rgen cySh owe r
Dra
ina g
e D
itch
to M
cDon
ald
Lake
1 ATC O P IPEL INE
P.P.
MCDONALD
LAKE
PipelineR/W (031
0629)
PipelineR/W (031 0391)
GasPipeline R/W
(4609 JK)
Pipeline R/W(791 0816)
Gas PipelineR/W (851 0253)
Gas TransmissionLine R/W (299 JK)
PipelineR/W (791
0816)
Oil PipelineR/W (754 JK)
Pipeline R/W(031 0174)
PipelineR/W
(1547 JK)
Gas TransmissionLine R/W (686 JK)
PipelineR/W (101
2606)
PipelineR/W
(502 JK)
PipelineR/W (061
2620)
PipelineR/W (921
0545)
PipelineR/W (821
0555)
CanadianPacific Railway (871
JK)
PipelineR/W (081
5893)
PipelineR/W (081 3328)
Gas Pipeline R/W(791 0816)
PipelineR/W
(500 JK)
Pipeline R/W(500 JK)
GasPipeline R/W
GasPipeline
R/W
Admin Building
PowerStation
Fiber OpticPipeline
(10m R/W)
Fiber Optic Pipeline(10m R/W)
Building
Pipeline R/W
PowerlineR/W
PowerlineR/W (9012327 UR/W)
Pipeline R/W
WellSite2-2
PipelineR/W (931
2570)
0 100 200 30050Meters
±CONTINUOUS, 190, 25
TEL, 210, 25
CONTINUOUS, 90, 25
CONTINUOUS, 142, 25
DASH_5-1, 24, 25
DASH_5-1, 94, 25
PIPE-B, 10, 25
POWER, 190, 25
CABLE-ABD, 210, 25
CONTINUOUS, 50, 25
ANCHOR, 190, 25
ROAD-G, 90, 25
DASH_1-1, 142, 25
CONTINUOUS, 24, 25
CONTINUOUS, 94, 25
PIPE-B, 4, 25
ROAD-G, 10, 25
CONTINUOUS, 110, 25
CONTINUOUS, 252, 25
CONTINUOUS, 101, 25
CONTINUOUS, 36, 25
CONTINUOUS, 31, 25
CONTINUOUS, 140, 25
CONTINUOUS, 251, 25
WATER, 10, 25
CONTINUOUS, 141, 25
CABLE-OH, 190, 25
CONTINUOUS, 253, 25
TRACK, 7, 25
CONTINUOUS, 230, 25
CONTINUOUS, 221, 25
CONTINUOUS, 112, 25
CONTINUOUS, 121, 25
DASH_1-1, 7, 25
DASH_5-1, 160, 25
Q-LINE, 7, 25
POWER, 181, 25
DASH_1-1, 10, 25
CONTINUOUS, 6, 25
DASH_5-1, 240, 25
CONTINUOUS, 51, 25
CONTINUOUS, 193, 25
BLZ-F004-B-020-B.DWG MultiPatch<all other values>
Cad Renderer
CONTINUOUS, 7, 25
CONTINUOUS, 96, 25
CONTINUOUS, 91, 25
CONTINUOUS, 242, 25
CONTINUOUS, 241, 25
CONTINUOUS, 132, 25
CONTINUOUS, 131, 25
CONTINUOUS, 10, 25
CONTINUOUS, 20, 25
CONTINUOUS, 210, 25
CONTINUOUS, 211, 25
CABLE-B, 211, 25
CONTINUOUS, 130, 25
CONTINUOUS, 2, 25
CONTINUOUS, 1, 25
CONTINUOUS, 11, 25
ANODE, 220, 25
CONTINUOUS, 254, 25
CONTINUOUS, 4, 25
CABLE-B, 210, 25
CONTINUOUS, 5, 25
PIPE-B, 90, 25
CONTINUOUS, 160, 25
CONTINUOUS, 34, 25
CONTINUOUS, 170, 25
FENCE, 150, 25
CONTINUOUS, 150, 25
CONTINUOUS, 190, 25
TEL, 210, 25
CONTINUOUS, 90, 25
CONTINUOUS, 142, 25
DASH_5-1, 24, 25
DASH_5-1, 94, 25
PIPE-B, 10, 25
POWER, 190, 25
CABLE-ABD, 210, 25
CONTINUOUS, 50, 25
ANCHOR, 190, 25
ROAD-G, 90, 25
DASH_1-1, 142, 25
CONTINUOUS, 24, 25
CONTINUOUS, 94, 25
PIPE-B, 4, 25
ROAD-G, 10, 25
CONTINUOUS, 110, 25
CONTINUOUS, 252, 25
CONTINUOUS, 101, 25
CONTINUOUS, 36, 25
CONTINUOUS, 31, 25
CONTINUOUS, 140, 25
CONTINUOUS, 251, 25
WATER, 10, 25
CONTINUOUS, 141, 25
CABLE-OH, 190, 25
CONTINUOUS, 253, 25
TRACK, 7, 25
CONTINUOUS, 230, 25
CONTINUOUS, 221, 25
CONTINUOUS, 112, 25
CONTINUOUS, 121, 25
DASH_1-1, 7, 25
DASH_5-1, 160, 25
Q-LINE, 7, 25
POWER, 181, 25
DASH_1-1, 10, 25
CONTINUOUS, 6, 25
DASH_5-1, 240, 25
CONTINUOUS, 51, 25
CONTINUOUS, 193, 25
Disposition - Operator
Atco
Canadian Pacific Railway
City of Calgary
Fortis
Nexen
Pembina
Telus
services
Nexen Inc.
NEXEN INC. 801-7th Ave S.W. Calgary, AB. Canada T2P 3P7T. 403.699.4000 www.nexeninc.com
BalzacFigure 3
Existing InfrastructureExpected to Remain
Author: R. McCallumGIS Specialist: A. JackDept: GIS Services
Date: November 24, 2011Updated: File No : CA13581.mxd
Scale: 1:2,500NAD 1983 UTM Zone 12N
Projection: Transverse Mercator
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The following steps are required to better understand the characteristics at the BGP, allowing for
remedial options to be compared, end land use to be further explored and discussed, and
ultimately, a detailed remedial plan to emerge. This is a phased approach that CANNOT be
completed until demolition is complete and as each phase of demolition and testing occurs, the
information will be used to support future and final site remediation:
1. Completion of an environmental site assessment for the BGP as a whole to ensure that all
areas of possible contamination across the property have been identified and assessed.
Finalize the list of unknowns/areas for investigation due to infrastructure limitations or
operations (Gap Analysis) and complete Phase II activities to determine if contamination
is present in these areas.
2. Develop a remedial action plan to determine and/or establish specific guidelines for each
Contaminant of Concern (as required for soil, groundwater, surface water and sediment).
Once these above steps have been completed, soil, groundwater, surface water and sediment
plumes will be understood. Confirmation of the specific details and methodologies of the
remedial plan can be completed at that time, in conjunction with final end land use planning.
10 REMEDIATION PLAN
10.1 General Options analyses for remediation planning have been conducted since decommissioning and
remediation at the Balzac Gas Plant was first contemplated. The following remedial strategy has
been developed to allow safe, effective, and efficient remediation and subsequent redevelopment
of the land. The following bullets summarize the tasks involved in the overall program, which
includes a remediation communication plan.
A remediation execution plan will be developed defining the areas requiring remediation,
the technical approach(es) that will be used, environmental monitoring and occupational
health and safety precautions to be undertaken. The execution plan will also define
requirements for confirmatory sampling for verification that remedial objectives have
been achieved.
All buildings and other surface and subsurface infrastructure, that are no longer required
will be demolished and waste materials either recycled or legally disposed.
Soil and soil stockpiles that are currently present within the boundaries of the BGP will
likely be remediated as follows:
o Soil will be excavated as needed, and processed to achieve volume reduction.
o Soils with organic contaminants above the Tier II guidelines established for the
site will be remediated in-situ wherever possible. If in-situ remedial options are
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not available for a certain contaminant, or not cost effective, ex-situ remediation
(still on site) will be considered (biopiles, etc). As possible, all organic
contamination will be dealt with on site.
o Inorganic contaminants in soil will be removed from site if necessary and may be
taken to a registered landfill facility as per the Nexen BGP Waste Management
Plan. Other options will be to stockpile in a specific area and risk manage
(perhaps in conjunction with the areas used by the operating Power Station and
associated pipelines).
o Further and more detailed remedial options will be established once further
assessment work and land use planning has been completed for the BGP.
Processed soil may be reused to establish development grades across the property,
consistent with tested contaminant characteristics and as verified by an appropriate
testing program.
Excess soil or other material that cannot or will not be reused to meet development grades
will be legally disposed off-site at an approved landfill facility. This includes debris,
hazardous waste, soil that does not meet geotechnical requirements for Site
redevelopment, and salvaged crushed rock.
Dust and noise management and mitigation are activities integral to remedial operations.
Monitoring measures will be implemented to verify that acceptable noise and air quality
is maintained during remediation activities.
Industrial water runoff will be controlled during remediation to prevent its contamination
by travelling over or through impacted materials. If needed, accumulations will be
removed from contaminated areas and treated as required, prior to release or disposal.
Groundwater remediation may include, but will not be limited to, the following:
o The existing groundwater remediation system present in the LPG area will
continue to be operated, both to recover NAPL (none was observed in 2009) and
dissolved phased contamination present in the groundwater. Groundwater
monitoring activities will also continue.
o Based on the results of site assessment and RAP, appropriate plans will be
implemented to best remediate and reduce risk to receptors. Receptors and risk
pathways will be evaluated to ensure no risk is present to human receptors, the
general environment and/or McDonald Lake. Ecological risk assessment
techniques will be utilized whenever possible to quantify actual risk to receptors.
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10.2 Sulphur Handling Facility As operations at the BGP have terminated, Nexen has assumed responsibility for the sulphur
handling facilities. As the approval holder Nexen has sole responsibility for the management and
control of the sulphur handling facility and the sulphur handling facility will be managed
consistent with the remainder of the gas plant.
A comprehensive assessment program will be undertaken to determine the nature, degree and
extent of contamination associated with the Sulphur Handling Facility. Decontamination of areas
directly associated with the sulphur slating plant and maintenance buildings, etc. will be the
overall responsibility of Nexen.
10.3 McDonald Lake
As per the Amending Approval 155-02-06, Nexen will continue to monitor McDonald Lake for
parameters outlined in Table 4.2-B of that approval. Annual reporting of findings will continue.
In addition to approved releases and influences from the BGP, McDonald Lake is known to
receive surface water inputs from industrial lands located south of the BGP, through surface water
drainage, and from the industrial park, located on the north-west shore of the lake. The industrial
park on the northwest shore of the lake includes a surface water retention pond, located directly
on the shore of the lake, which releases into the Lake. Furthermore, surface water drainage from
this same industrial park also influences McDonald Lake.
In addition, there is clear release of other users into McDonald Lake. It is Nexen`s understanding
that these other releases are not monitored or reported to AENV. Nexen would look to AENV to
develop a McDonald Lake monitoring strategy that would incorporate all Industrial influences to
ensure they are managed, monitored, and information pooled from all users to determine how all
contributors have affected/are effecting McDonald Lake.
10.4 Noise Management Noise assessment and mitigation will be addressed by complying with the Site's Health and
Safety Plan. The project will conduct noise-generating operations only within the standard
construction hours of 7:00 AM to 7:00 PM on weekdays and 8:30 AM to 7:00 PM on Saturdays
as per the Municipal District of Rockyview No. 44 Bylaw No. C-5772-2003 (aka “Noise Control
Bylaw”).
Noise will be monitored as required through established monitoring programs that may be
deemed appropriate at the time.
10.5 Industrial Runoff Management Industrial runoff control systems will continue as per the existing AEPEA approvals.
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Industrial water run-off will be controlled during remediation to prevent its contamination by
manipulating site grade (e.g. berm or channelling) to redirect potential run-off around the areas to
be remediated or in the process thereof. Industrial water control measures will be available and
will be installed as required and will be optimized as appropriate. These may include the use of
the existing catchment areas, or alterations to the catchment areas mentioned in Section 6.5, to
best manage surface water on the BGP.
Stockpiles of contaminated soils will be placed with proper grading to control Industrial water.
All stockpiles with contaminated soil (processed and unprocessed) will be located in a dedicated
areas a central location to minimize the risk of run-off of contaminants.
Industrial wastewater that accumulates around stockpiles or in excavation areas and requires
removal will be transported and/or pumped to a designated area. This captured water may be
treated using bag filters and activated carbon or disposed at an approved facility. The treated
water will only be reused for dust control in areas or on materials requiring or undergoing
remediation. No Industrial water will be discharged to McDonald Lake without appropriate
testing to ensure acceptable conditions.
10.6 Monitoring Programs
All of Nexen’s monitoring programs will be implemented in accordance with a Site Specific
Health and Safety Plan that will account for all of the physical and chemical hazards that may be
present. The health and safety program will be consistent with the following primary goals: no
accidents, no harm to people and no damage to the environment. The Health and Safety Plan has
been developed in accordance with all Provincial Occupation Health & Safety requirements and
regulations.
Nexen uses a defined Hazard Assessment process to identify any potential hazards. In the event a
hazard is identified (i.e. airborne contaminants) Nexen will conduct baseline surveys to determine
the likelihood of potential problems/exceedances. If the baseline survey identifies the hazard is
present in quantities of concern (50% of the Occupational Exposure Limit) Nexen will develop a
specific plan to eliminate/reduce, control and monitor exposure to the hazard. For example, while
operating and during SDS Nexen had specific monitoring plans for Noise, Asbestos, Benzene,
SO2, H2S, CO and Hydrocarbons.
During the course of the remedial program at the BGP, appropriate monitoring will take place to
ensure the workers and the public are not exposed to air borne contaminants or noise in excess of
regulations or guidelines in place at the time. These monitoring programs may include sampling
to ensure worker occupational exposure limits are not exceeded, organic air sampling, and/or
particulate sampling to ensure compliance with the Occupational Health and Safety Act,
Occupational Health and Safety Code 2009, or any updated versions thereof.
As per the requirements outlined in the existing AEPEA approval 155-02-00, and subsequent
amendments, soils will be sampled once in-situ or ex-situ remediation is complete, to document
soil conditions and ensure acceptable risk an all groundwater will be sampled prior to release.
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11 RECLAMATION PLAN The determination of a successful outcome of reclamation at the BGP will be dependent upon the
end land use agreed to by Nexen, working interest partners, and regulatory agencies (including
municipal bodies) and the regulatory criteria in effect at the time.
The exact date of reclamation commencement is currently unknown due to the unknown and long
timelines associated with decommissioning, dismantling, and remediation at the BGP. The goal
therefore is to briefly identify measures that could be used to achieve “equivalent land capability”
that may be similar to surrounding land use conditions that may exist at the time of reclamation.
As this could very well be 10 years or more in the future, it is strictly conceptual in nature.
Preparation of the reclamation plan will eventually be guided by the engineering drawings and
site grading plan for the determined end land use. The engineering plans should guide the amount
of soil salvage or replacement required, the location for soil storage and/or replacement, re-
contouring, drainage restoration, and post closure conditions that result in specific reclamation
requirements being met on the site.
The final goal will be to achieve the following:
Erosion control and site stability;
Return of the proposed disturbances to land capability that is equivalent to or consistent
with the approved end land use or uses;
Re-vegetation of all disturbed areas to the targeted end land use or uses;
Control of noxious and restricted weeds;
Development of a self-sustaining landscape; and,
Reclamation certification.
As industry best management practices will likely evolve, Nexen will incorporate such
developments in the plan for successful realization of the end land use objectives.
12 HEALTH & SAFETY PROGRAM The management of Nexen is dedicated to the safety of personnel as well as those Nexen works
with. Nexen’s goal is to provide a safe work environment through a trained employee or
contractor who is safety oriented. Nexen’s mission is to not only provide a job that is done well
but is done safely.
To that end, the remediation plan will be implemented in accordance with a Site Specific Health
and Safety Plan that will account for all of the physical and chemical hazards that may be present.
The health and safety program will be consistent with the following primary goals: no accidents,
no harm to people and no damage to the environment.
At a minimum, the Site Specific Health and Safety Program will incorporate the following:
Air Monitoring;
Noise Monitoring;
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Decontamination Procedures;
Emergency Response Procedures;
Ground Disturbance;
Confined Space Entry;
Respirator Use Code of Practice; and
Management of Change.
The Health and Safety Program will also include the following:
adequate training of all owner, contractor and technical personnel;
initial safety orientation prior to commencing Site work;
daily tailgate meeting to reemphasize and identify potential hazards or health concerns;
testing and identification of underground hazards prior to excavating or intrusive
investigation;
selection of appropriate personal protective equipment for each activity;
recognition of emergency situations and appropriate response;
implementation of procedures for handling of contaminated soils and water;
noise and air quality monitoring; and
safety audits.
Both of the above noted Programs ensure that Nexen maintains compliance with Occupational
Health and Safety Requirements.
In 2002, the Nexen Balzac Gas Plant became the first Oil & Gas facility in the world verified
Responsible Care® In-Place.
Responsible Care® (RC) is a unique ethic developed within the chemicals industry that drives
continual improvement in health, safety, environmental and business performance, while openly
and transparently communicating with stakeholders about products and processes.
Critical to RC is an expectation for member companies to have a functioning, effective
management system in place and that it is structured to include all components of the
Plan/Do/Check/Act cycle of continual improvement.
Both the “ethic” and effectiveness of the management system is verified every three years by a
team of external industry experts and leaders within the community through a process of staff
interviews, document reviews and meetings with external stakeholders. The next verification for
the Balzac Gas Plant is scheduled for the fall of 2013.
13 COMPLAINT RESPONSE Nexen has a procedure for receiving, recording, investigating, resolving and reporting public
inquiry or non-compliance events which may occur. One of the key outcomes of the process is to
ensure there are steps taken so that Nexen can learn from our experiences and maintain diligence
in its ongoing operations.
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These include:
Record enquiries, comments and complaints;
Develop, manage and record responses to enquiries, comments and complaints;
Support data collection and reporting requirements;
Support communication, liaison and notification activities;
Record communication, consultation and liaison activities;
Assist the project team in managing issues;
Nexen will handle all comments and complaints concerning the Project in a timely and prudent
fashion.
14 REPORTING Further assessment activities and delineation activities are required to determine all sources of
contamination on the property and fully define the edges of each of the contaminant plumes.
Once these assessment activities are completed, assessment reports will be completed, and the
remedial plans will be updated with more specifics relating to excavation, remedial opportunities
and risk assessment choices. This updated plan will be provided to AENV as per the conditions
of the current approval, Section 5.2.4 of Approval 155-02-00.
Reporting to AENV will update progress on the decommissioning and land reclamation as the
project commences proceeds and more details are known on aspects of the remediation and
reclamation methods, expected outcomes, and end land uses are determined.
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Appendix I –Slater Demolition Plan
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Appendix II – Waste Management Plan
Nexen Canada Ltd Waste Management Plan
Balzac Gas Plant 1.0: INTRODUCTION Table of Contents
1.0 INTRODUCTION
2.0 MANAGEMENT
2.1 Identification
2.2 Characterization and Classification
2.3 Handling
2.4 Treatment
2.5 Disposal
2.6 Tracking
2.7 Record Keeping
3.0 WASTE MANIFESTING
3.1 Manifest completion
3.2 EUB Handling Codes
3.3 Other Manifests
3.4 Alberta Waste Management Table
4.0 MINIMIZATION
4.1 Eliminate
4.2 Reduce
4.3 Reuse
4.4 Recycle
4.5 Recover
5.0 STORAGE REQUIREMENTS
6.0 LIST OF ALL WASTE RECEIVERS IN ALBERTA
7.0 LIST OF ALL LANDFILLS IN ALBERTA
8.0 SPILLS REPROTABLE TO GOVERNMENT
9.0 COMPANY FACILITY CODES
10.0 WASTE AUDIT REPORTS
11.0 RECYCLING
Nexen Canada Ltd Waste Management Plan
Balzac Gas Plant 1.0: INTRODUCTION
Introduction
The Oilfield Waste Management Requirements for the Upstream Petroleum
Industry (EUB Guide G-58) publication was published in December 1996 by the
AEUB. It is the standard for proper management of upstream oilfield wastes.
The operations staffs are responsible for managing day-to-day waste issues. The
facility design engineer is responsible for ensuring that waste from a process is
minimized. The Environmental Analyst is responsible for working with field and
technical staff to ensure all related regulations are complied with.
Objective
Nexen Canada Ltd. (NEXEN) is committed to demonstrating continuous
improvement in reducing the generation of waste from its operations, beneficially
reusing or recycling materials that might otherwise end up in the waste stream. It
also strives to properly store, handle, and dispose of those wastes that remain.
Active waste minimization is forefront, when the proper waste handling
techniques are employed. NEXEN is committed to ensuring compliance with
regulations, as well as ensuring protection of the environment when dealing with
its waste products.
NEXEN is also committed to properly training all personnel who handle wastes
and those responsible for their supervision.
To actively pursue these commitments, NEXEN has developed this Waste
Management Plan to ensure compliance with all associated environmental
regulations. This plan will serve as a valuable tool for the collection of data,
providing guidance to employees, identification of future technology needs and
requirements, as well as reducing risk exposure, and identifying the company’s
operating procedures and standards. In creating this Corporate-wide Waste
Management Plan, NEXEN has endeavored to meet the requirements of the
strictest province’s regulations, and enforce them company wide.
Scope
This plan is applicable to all EUB regulated segments of the company. This plan
will be the corporate guide for all of its facilities. The corporate waste
management plan will be the basis for the waste management philosophy of the
company, and will ensure consistency throughout. In areas outside of Alberta, the
site-specific plans for each facility will have to reflect the regulatory requirements
of the province in which the facility is operating. It is the intention of NEXEN to
establish and utilize the best management practices where available.
Nexen Canada Ltd Waste Management Plan
Balzac Gas Plant 1.0: INTRODUCTION
Plan Description
The plan is based on discussions with operations and environmental personnel
from NEXEN. Site visits to a representative sample of facilities were conducted,
for the purpose of conduction waste audits. The plan will ensure regulatory
compliances and will meet or exceed the requirements of the EUB’s waste
management requirements as outlined in Guide G-58.
This waste management plan is comprised of the following components:
Identification
Characterization and classification
Handling
Storage
Treatment
Disposal
Manifesting
Tracking and record keeping
Reporting
Site specific plans for field offices
The principles of waste minimization are followed closely in this plan. This is
both an environmental consideration as well as an economical one. Recognizing
opportunities to reduce waste volumes as well as the elimination of certain wastes
will enable NEXEN to ensure that it is operating in an environmentally safe and
responsible manner. This will reduce the liabilities associated with the handling,
storage and disposal of dangerous oilfield wastes (DOWs).
Waste Minimization will be addressed in Section 4.0.
Nexen Canada Ltd Waste Management Plan
Balzac Gas Plant 2.1: IDENTIFICATION
A. INTRODUCTION
This section will describe the wastes specific to the individual facilities. These
specific wastes will be outlined in the site-specific individual facilities and are
found in the appendices. The wastes will include both Dangerous Oilfield Wastes
(DOWs) and non-Dangerous Oilfield Wastes (non-DOWs).
B. PURPOSE AND SCOPE
A waste is an unwanted substance or a mixture of unwanted substances that result
from the construction, operation or reclamation of an oilfield facility. The waste
streams need to be identified and documented in order to prepare a management
plan. From this list, specific techniques will be developed in order to ensure
compliance to corporate and regulatory requirements.
C. PROCEDURES
1. A waste audit is an evaluation of all steps of the operation to determine where
waste is created. A waste audit is performed to identify all waste sources and
streams. This audit is a physical inspection, reviewing operating procedures,
disposal records and documentation. The criteria on which the audits are
performed are base industry standards. Copies of facility audits should be
retained on-site.
2. Waste Audits may be performed by company employees or by third-party
auditors utilizing the same format for all facilities. An audit report should be
produced for each facility. Copies of these reports should be maintained at the
facilities as well as at the corporate office.
Nexen Canada Ltd Waste Management Plan
Balzac Gas Plant 2.2: CHARCTERIZATION AND CLASSIFICATION
A. INTRODUCTION
This section assesses the properties of the waste to determine its waste type. All
wastes will be classified as a Dangerous Oilfield Waste (DOW) or a non-
Dangerous Oilfield Waste (non-DOW).
B. PURPOSE AND SCOPE
Under the requirements of EUB G-58, all wastes require assessment as to its
physical, toxicological and chemical characteristics. These properties will
determine the waste’s classification. All wastes and waste streams must be
classified.
These classifications will be used for manifesting, tracking, record keeping,
storage, disposal and transportation requirements.
This will ensure compliance with the Alberta waste regulations.
C. PROCEDURES
1. Identify the waste or waste stream [See Section 2.1: Identification]
2. Determine physical, toxicological or chemical properties using analytical
techniques. These techniques are detailed in Section B of Guide G-58.
3. Alternatively, the waste name may be referenced in either the CAPP Waste
Management Handbook, or Guide G-58.
4. Classify the waste as a DOW or a non-DOW. Company personnel should
document theses waste names, characteristics and classification for reference.
There are a number of properties that will be used to classify a waste as DOW. These
properties are derived form the TDG regulations and are outlined as follows:
Flammability – flash point less than 61°C
Spontaneous combustion – auto ignition
Waste incompatibility
Toxic – oral, dermal, or inhalation
Corrosivity – pH less than 2.5 and over 12.5
Leachate toxicity – Alberta Tier 1 Metals / BTEX
PCB content – over 50mg/kg
Nexen Canada Ltd Waste Management Plan
Balzac Gas Plant 2.2: CHARCTERIZATION AND CLASSIFICATION
As can be seen, it is imperative to know the characterization of a waste before it can be
classified. All wastes have to be classified as a DOW or a non-DOW. Once a material
has been classifies, certain requirements must be met, such as:
A DOW must be manifested and a non-DOW does not
A DOW will require TDG placarding and a non-DOW does not
All DOWs and non-DOWs have to be tracked
Etc.
Nexen Canada Ltd Waste Management Plan
Balzac Gas Plant 2.3: HANDLING
A. INTRODUCTION
This section details the procedures necessary for proper waste handling.
B. PURPOSE AND SCOPE
Waste handling is an issue that field personnel require training for. Knowing how
to correctly handle DOWs involves safety issues.
It is important to know the properties of the wastes being handled. Waste
segregation should be employed to ensure that DOWs and non-DOWs are not
commingled. This is done for two reasons: the first safety. The safety
procedures should be consulted to ensure that the correct clothing and safety
equipment is used. The MSDS sheets should also be consulted. This is especially
true when dealing with chemicals or flammable material.
The second reason wastes should not be commingled is for economic
considerations. As DOWs are usually more expensive to dispose, it is important
not to increase their volume. Any wastes that are in contact with a DOW will
have to be classified as a DOW. This will increase the disposal volume as well as
the cost.
The proper storage of waste is another important handling consideration. This
issue is dealt with in Section 5.0: Storage.
C. PROCEDURES
1. Identify (Section 2.1 Identification).
2. Characterization and Classification (Section 2.2 Characterization and
Classification).
3. Consult Material Safety Data Sheets (MSDS) for proper handling and safety
procedures (where applicable).
4. Consult EUB – Guide G-58.
5. Consult Alberta Environmental Protection (AEP) – Waste Handlers Guide.
6. Consult CAPP – Waste Management Guidelines.
Transportation
Comply with the transportation requirements as detailed in the Transportation of
Dangerous Goods Regulations (TDGR).
Nexen Canada Ltd Waste Management Plan
Balzac Gas Plant 2.4 TREATMENT
A. INTRODUCTION
This section details the procedures followed in on-site and off-site waste
treatment prior to, or in place of disposal.
B. PURPOSE AND SCOPE
Treatment of wastes is undertaken for several reasons. The first reason is the
reduction of the waste volume. By reducing the volume of waste required for
disposal thereby reducing the cost. Secondly, some DOWs may be treated so as
to change its classification to a non-DOW, resulting in saving in disposal costs.
Lastly, treatment may be used as an alternative to, or in conjunction with disposal.
C. PROCEDURES
1. Identify (Section 2.1 Identification).
2. Characterization and Classification (Section 2.2 Characterization and
Classification).
3. Consult Material Safety Data Sheets (MSDS) for proper handling and safety
procedures (where applicable).
4. Consult EUB – Guide G-58.
5. Consult CAPP – Waste Management Guidelines.
6. Investigate industry recognized treatment alternatives, such as:
On – site treatment:
Treating spill sites instead of removing material
Land farming flare pit material
Draining fluids from filters before disposal
Neutralizing acids or caustics
Filtering oils and glycol for reuse
Off – site treatment:
Removing liquids from sludge to reduce volumes
Reclaiming oil from sludge prior to disposal at a waste plant
Cleaning and re-using crank case oil by a third party
Cleaning filter mediums such as charcoal and re-using
Recovering gold and silver from tower trays for reuse
On-site treatments, apart from land farming and bioremediation, are not required
to be included in the EUB Annual Report. Any treatment that can re-use a waste
or can reduce a volume is usually cost effective.
Facilities should carefully consider all alternatives before deciding on an option.
Some wastes that are small in volume may not be cost effective to treat.
Nexen Canada Ltd Waste Management Plan
Balzac Gas Plant 2.4 TREATMENT
All treatment programs should be well documented and initiated after discussion
with the appropriate governing agencies.
Nexen Canada Ltd Waste Management Plan
Balzac Gas Plant 2.5 DISPOSAL
A. INTRODUCTION
This Section defines waste disposal requirements as stipulated in Guide G-58.
B. PURPOSE AND SCOPE
To ensure compliance to regulations, proper disposal procedures need to be
defined for all wastes identified by Section 2.1.
There are rules in Guide G-58 that stipulate where a waste must be disposed of.
Theses are based on the type, and classification of waste. It is imperative that the
company personnel are familiar with the regulations. The incorrect disposal of
wastes could result in fines, both for the company and the individual. Jail terms
may also result if it can be shown that a willful act took place.
C. PROCEDURES
1. Identify (Section 2.1 Identification).
2. Characterization and Classification (Section 2.2 Characterization and
Classification).
3. Consult Material Safety Data Sheets (MSDS) for proper handling and safety
procedures (where applicable).
4. Consult EUB – Guide G-58.
5. Consult CAPP – Waste Management Guidelines.
6. Verify transporter compliance to TDG regulations.
7. Select proper disposal options from site-specific waste management plan or
Guide 58.
Waste disposal options include but are not limited to:
Landfills (municipal, industrial, and oilfield)
Thermal treatment
Swan Hill waste treatment facility
Deep well disposal
Waste management facilities
Biodegradation
On-site disposal (small volume incinerators, etc.)
Cavern disposal
Recyclers
Out of province or country facilities
Verify the conditions and approvals as listed on the waste receiver’s license to
ensure the correct disposal option has been chosen. It is the waste generators
responsibility to confirm the receiver’s license conditions. Conducting audits of
the transporters and waste receivers is one method of ensuring that compliance is
met.
Nexen Canada Ltd Waste Management Plan
Balzac Gas Plant 2.5 DISPOSAL
Audits may be performed by company personnel or by a third-party auditor.
Audit reports should be maintained at the field offices. An industry-standard
format should be utilized in conducting these audits.
Audit reports should be maintained for a minimum of two years or until the
contractor’s subsequent audit.
Nexen Canada Ltd Waste Management Plan
Balzac Gas Plant 2.6 TRACKING
A. INTRODUCTION
This policy defines the Tracking and Record Keeping requirements as they
pertain to proper waste management.
B. PURPOSE AND SCOPE
Guide G-58: Section C clearly defines the requirements for generators of oilfield
wastes in Alberta. An integral component of proper waste management is the use
of documentation. This documentation refers to a system by which the handling,
movement, treatment and disposal of wastes are monitored by the waste
generator.
Generators will be required to complete EUB Waste Manifests for all DOWs
transported and disposed within the province. Out of province disposal will
require separate TDG manifests as do wastes destined for the Sawn Hills Waste
Treatment Facility.
Generators are also required to implement an electronic tracking system that
ensures that the quantities, and characteristics of all those specified wastes, both
DOW and non-DOW as well as their final treatment methods are known and
documented.
An accurate record-keeping system is necessary to fulfill these requirements.
C PROCEDURES
Manifesting
1. Identify (Section 2.1: Identification)
2. Characterization and Classification (Section 2.2: Characterization and
Classification)
3. Consult EUB – Guide G-58
4. Refer to Section 3.0: Manifesting
5. Refer to Site specific Waste Management Plan
Once the manifests are returned from the receiver, ensure that Pages 1 and 2 are
filled out completely. Return page 1 to the EUB in Calgary and attach copy 2 to
copy 5 and place into a waste-tracking file.
Table 9.1 – Oilfield Waste Management Requirements for the Upstream Oil and Gas
Industry
Reportable Oilfield Wastes
All DOWs must be included in the annual oilfield waste disposition report. Additionally,
the following oilfield wastes that may or may not be dangerous, must be included in the
Nexen Canada Ltd Waste Management Plan
Balzac Gas Plant 2.6 TRACKING
report. Non-DOW that are not included in this list, but are specified in the Waste
Management Table, Section 7.4 of Appendix 7.0 are exempted from the waste disposition
report unless they are determined to be dangerous.
This list is only for the annual oilfield waste disposition report requirements. It is not
intended to be used for the classifying of oilfield wastes.
Absorbents
Activated Carbon
Asbestos
Boiler blowdown water
Catalyst (non sulphur)
Catalyst (sulphur)
All Contaminated Debris and Soils
Crude oil Condensate Emulsions (Residuals after treatment)
Desiccant
Filters (media) water treatment
Filters – air pollution control
Filters – lube oil
Frac Sand (radioactive and non-radioactive)
Glycol Solutions (no heavy metals)
Hydraulic and Transmission Oils
Incinerator Ash (if incinerator material is reportable)
Ion Exchange Resin
Ion Exchange Resin Regenerant Liquids
Lubricating Oil
Pigging Waste
Contaminated solids less than 50ppm Polychlorinated Biphenyls (PCBs)
Produced Sand
Sludges þ (flare pit, hydrocarbon, lime, process, and Sulphur)
Sweetening Agents þ (solids and liquids)
Treater Hay
Wash fluids (organic)
Water-Process (with organic chemicals)
Water-Process (neutralized solutions with heavy metals)
Water-Produced (if contaminants are present which make the solution a DOW)
Well Workover Fluids
Wood – chemically treated/cooling tower
Unlisted wastes (if they present a risk to the environment or the public)
Waste Tracking Sheet Requirements
The operator is required to track waste disposal information for all wastes
produced on the lease. This includes all wastes produced by drilling and servicing
contractors – such as: lube oil, glycol, filters, rags, absorbents, etc. The CAODC and
CAPP have agreed that the contractors will ensure proper disposal of all wastes that they
Nexen Canada Ltd Waste Management Plan
Balzac Gas Plant 2.6 TRACKING
create on the lease. However the AEUB requires that the waste disposal information be
recorded and tracked by the operator. The operator is defined as the “Waste Generator”
for all wastes created in the development of operation of their properties or facilities.
Therefore, the drilling and servicing companies must provide the Operator or Operator’s
representative (Consultant) with the waste disposal details when wastes are disposed.
Nexen Canada Ltd Waste Management Plan
Balzac Gas Plant 2.6 TRACKING
Facility Name:___________________________________________ Location: ___________________________
Reporting Dae: _______________________, 20____
Manifest
Number
Date
Shipped
Waste Name
[Waste Code]
Class
[D or N]
Volume
(units)
Transporter
Reciever
Nexen Canada Ltd Waste Management Plan
Balzac Gas Plant 2.7 RECORD KEEPING
A. INTRODUCTION
This policy defines the Record Keeping requirements as they pertain to proper
waste management.
B. PURPOSE AND SCOPE
Guide G-58: Section C clearly defines the requirements for generators of oilfield
wastes in Alberta. An integral component of proper waste management is the use
of documentation. This documentation refers to a system by which the handling,
movement, treatment and disposal of wastes are monitored by the waste
generator.
Generators will be required to complete EUB Waste Manifests for all DOWs
transported and disposes within the province. Out of province disposal will
require separate TDG manifests as do wastes destined for the Swan Hills Waste
Treatment Facility.
An accurate record-keeping system is necessary to fulfill these requirements.
C. PROCEDURES
Record Keeping
Waste generators are required to maintain an accurate electronic and physical
record of all DOWs and non-DOWs produced and disposed. These records are
maintained on a facility-by-facility basis, as well as at the corporate level.
The record keeping system must contain at least the following information:
1. Waste Tracking System
company operator code (EUB)
facility code (EUB)
point of waste generation / disposition
point of waste consolidation
waste (EUB Guide G-58: Appendix 7.0)
total quantity disposed (units: m³ or tones)
waste receiver information (company name, facility code, location, etc.)
disposal methods employed (such as: waste processing facility, disposal
wells, landfills, biodegradation facility, thermal treatment, used oil
recycler, recycling facility, Swan Hills Waste Treatment Facility, small
volume incineration, on-site biodegradation, road spreading, on-site burial
or other disposal methods)
Discrepancy reconciliation
Waste Reports (monthly, quarterly, annual, etc.)
2. Copies of the EUB manifests.
Nexen Canada Ltd Waste Management Plan
Balzac Gas Plant 2.7 RECORD KEEPING
3. Employee training records
4. Waste receiver licenses and approvals
5. Waste minimization initiatives
6. Documentation of on-site treatment
7. Copies of transporter TDG certification
8. Contractor (i.e. waste receivers, transporters, waste brokers, etc.) audit /
inspection reports if completed
9. Copies of third-party waste agreements (Hazco, RB Williams, etc.)
Facilities are required to maintain these records on an individual basis. These records
must be kept for a minimum of 2 year. This will be the responsibility of the Facility
foreman or supervisor. It will be the responsibility of the environmental analyst to
prepare the quarterly, semi-annual, and the annual report.
Nexen Canada Ltd Waste Management Plan
Balzac Gas Plant 2.7 RECORD KEEPING
Waste Inventory
When a waste bin, container or tank is being used an inventory should be kept for
each. This may be achieved by completing the attached Tank Inspection Sheet.
A separate line should be completed for each bin, container or tank.
Heading Description
Company Name Name of Operator/Waste Generator.
Date Date of Inspection – when worksheet is completed.
Location LSD of lease.
Contents Contents of the bin or compartment.
Fill Level Estimate the level of material in the bin.
Capacity Total capacity of the tank, bin or compartment – may be
obtained from bin supplier.
Cont. Condition Are there holes, cracks, etc. In the bin – walk around
physically inspect the bin, containers, etc.
Berm. Condition Are there holes, cracks, etc. in the berm – walk around to
physically inspect berm.
Comments Any additional comments regarding the storage containers.
Inspector Initials Initials of the person who completed the inspection.
Nexen Canada Ltd Waste Management Plan
Balzac Gas Plant 2.7 RECORD KEEPING
Facility Name & Location: ___________________________________________
Date Tank
No.
Contents Fill Level Capacity Container
Condition
Berm
Condition
Comments Inspec.
Initials
E ¼ ½ ¾ F Good
Leak
Good
Break
E ¼ ½ ¾ F Good
Leak
Good
Break
E ¼ ½ ¾ F Good
Leak
Good
Break
E ¼ ½ ¾ F Good
Leak
Good
Break
E ¼ ½ ¾ F Good
Leak
Good
Break
E ¼ ½ ¾ F Good
Leak
Good
Break
E ¼ ½ ¾ F Good
Leak
Good
Break
E ¼ ½ ¾ F Good
Leak
Good
Break
E ¼ ½ ¾ F Good
Leak
Good
Break
E ¼ ½ ¾ F Good
Leak
Good
Break
E ¼ ½ ¾ F Good
Leak
Good
Break
E ¼ ½ ¾ F Good
Leak
Good
Break
E ¼ ½ ¾ F Good
Leak
Good
Break
Nexen Canada Ltd Waste Management Plan
Balzac Gas Plant 3.0 MANIFESTING
A. INTRODUCTION
This Section defines the manifesting requirements as set by the EUB.
B. PURPOSE AND SCOPE
Contained Within the EUB Oilfield Waste Management Requirements for the
Upstream Petroleum Industry is the requirement for manifesting wastes
transported within Alberta. These manifests apply to waste generated, transported
and disposed within Alberta. This manifest will meet the TDG Requirement in
these instances.
All Dangerous Oilfield Waste transported from generator to receiver within
Alberta will be manifested using this new manifest. Non-DOWs do not have to
be manifested. These manifests are available from the EUB.
C. PROCEDURES
The waste manifest form you use is shown as an example on the next page. This
form conforms to Federal and Provincial regulations requiring manifesting.
MANIFEST Distribution
Step Action
1. GENERATOR completes part A.
2. TRANSPORTER completes part B.
3. GENERATOR detaches and retains page 5.
4. TRANSPORTER carries pagers 1,2,3 and 4 with shipment and
delivers them to receiver.
5. RECEIVER completes part C, noting any discrepancies, then gives
page 4 to Transporter, returns pages 1 & 2 to Generator within 30
days of the shipping date and retains page 3.
6. GENERATOR completes part D and submits completed page 1 to
EUB’s Environment Protection Department within 60 days of
shipment date. GENERATOR attaches page 2 to page 5 and files.
GENERATOR investigates any discrepancies noted by receiver and
takes corrective action.
Nexen Canada Ltd Waste Management Plan
Balzac Gas Plant 3.0 MANIFESTING
EUB Manifest Preparation
The following table describes the fields in the EUB Alberta Oilfield Waste
Manifest. Part A – Generator (Consignor)
Field .
Company Name
Operator Code
Business Address
Source Location
Intended Receiver
N or D
Shipping Name
Waste Code
TDG/PIN and Classification
Packing Group
Alberta Permit Number
Quantity Shipped
Units
Oil/Water/Solid %
Description .
Name of the waste generating company.
AEUB assigned code of facility from which
the waste is being shipped.
Address to which the manifest (and
invoicing) would be sent.
LSD, Battery/Facility Code, and Facility
Operator Code (may be different from
above operator code).
Name of Waste Receiver to which the
waste is sent. Included is the waste
receivers Business Address, Receiving Site
Location and Receiving Batter/Facility
Code (EUB or AEP assigned codes)
N = non-DOW and D = DOW
Waste Description (from Waste
Management Chart)
EUB assigned codes (Waste Management
Chart)
Obtained from TDG
I – Very Dangerous
II – Dangerous
III – Moderately Dangerous
Obtained from Transportation and Utilities
Report to the nearest 0.1m³ or 0.1 tonne
t = tonne m = m³
Specify value where applicable
Nexen Canada Ltd Waste Management Plan
Balzac Gas Plant 3.0 MANIFESTING
Field .
Special Handling/
Emergency Instructions
Date, Time Shipped,
Scheduled Arrival Date
Name, Telephone No., 24
Hour Emergency Telephone
No. and Sign
Part D – Generator
Consignor:
Field .
Discrepancy Reconciliation
Details
Corrective Action
Name, Date, Telephone No.
and Sign
Description .
Self Explanatory
Self Explanatory
Self Explanatory
Description .
Note any discrepancies (if any) between the
waste details that were shipped and those
that were received. If any serious
discrepancies are noted, immediately notify
the EUB
Describe any corrective action taken.
Self Explanatory
Notes:
If some portions of the manifest are not able to be completed when the waste is
shipped, leave those portions blank. When the manifest is returned form the
receiver, the remaining sections can be completed then. For example, if the
receiver codes are not known, leave them blank (in Section A) and fill them in
once the receiver has filled in Section C.
Complete enough of the manifest to ensure the TDG requirements are met. The
EUB required data only has to be complete on page 1 when it is sent in to the
EUB Office.
Nexen Canada Ltd Waste Management Plan
Balzac Gas Plant 3.0 MANIFESTING
3.2 EUB HANDLING CODES
Code Disposal Description
01 Storage Facility
02 Transfer Station (Specify intended treatment / disposal)
03 Oilfield Waste Processing Facility
04 Class Ia Disposal Well
05 Class Ib Disposal Well
06 Class II Disposal Well
07 Cavern
08 Class Ia Landfill
09 Class Ib Landfill
10 Class II Landfill
11 Class III Landfill
12 Thermal Treatment
13 Biodegradation Facility
14 Small oilfield Waste Incinerator
15 Used Oil Recycler
16 Recycling Facility (excluding Used Oil)
17 Swan Hills Facility
18 Road Spreading
19 Biodegradation (On-site)
20 Burial (On-site)
21 Other (specify)
3.3 OTHER MANIFESTS
Swan Hills Waste Treatment Facility Manifest
There is a specific manifest required to ship waste to this facility. This manifest
and the instructions for use may be obtained from Chem. Security or Alberta
Environmental Protection. This manifest is provided by the third party waste
management brokers such as: Hazco, WasteCo or RB Williams. This manifest is
referred to as the federal / provincial waste manifest. If this manifest is used, the
facility must have a waste generator number from Alberta Environmental
protection.
Nexen Canada Ltd Waste Management Plan
Balzac Gas Plant 3.0 MANIFESTING
Out of Province Wastes
The shipping manifest must meet the federal TDG Regulations. These manifests
may be obtained from the third party waste management brokers. The company
must receive a copy showing the final disposition of the waste within 30 days of
the shipping date. This manifest does not have to be submitted to the EUB,
however, the waste details must be retained and reported in the annual report.
Alberta Environmental Protection requires a copy of the completed manifest. The
company is responsible for ensuring that this is performed. The completed
manifest may be submitted by the waste broker or by the generator. This manifest
must by submitted to Alberta Environmental Protection within 2 days after
shipping. The waste broker usually does this for the generator.
Hazardous Recyclables
A Hazardous recycle docket may be used in place of a waste manifest, for all
products listed as hazardous recyclable. This waste must however, still be tracked
and included in the annual EUB report. Used lube oil is an example of a
hazardous recyclable.
Nexen Canada Ltd Waste Management Plan
Balzac Gas Plant 3.0 MANIFESTING
Alberta Waste Management Table
Nexen Canada Ltd Waste Management Plan
Balzac Gas Plant 3.0 MANIFESTING
Waste Name [WASTE
CODE]
EUB tracking
Waste
Class
(N or D
Required
Document
TDG PIN TDG
Class
Packing
Group
Criteria Treatment Storage Disposal Option
Absorbents
[OILABS]
Tracking
N-DOW Bill of Lading N/A N/A N/A Flashpoint,
Leachate
Drain and recover any free
liquids
Cover, labeled container Recycle or Landfill – Class II.
Aerosols
(Empty)
[EMTCON]
Not Tracked
N-DOW N/A UN 1950 2.1 N/A Flammable Invert can and remove all
contents prior to storage and
disposal.
Store in covered container.
Keep away from heat or
combustion sources
Ensure container is empty and
landfill.
Batteries
(Dry cell)
[BATT]
Not Tracked
N-DOW Bill of Lading N/A N/A N/A KOH or NI-Cd
content
Place in general refuse
containers
Recycle or Municipal Landfill.
Batteries
(Wet cell)
[BATT]
Tracking
DOW Manifest UN 2794 8 III Corrosivity,
leachae (heavy
metals)
Remove and neutraliz fluids,
handle container and fluids
separately.
Store in covered container.
Keep away from heat or
combustion sources
-Recycle via battery recycler.
-Dispose container at approved
Class Ia, Ib or II landfill.
Boiler Blowdown Water
[BLBDWT]
Tracking
N-DOW Bill of Lading N/A N/A N/A Heavy Metals
(Cr, V or other)
Neutralize pH. Release to
surface if material meets Surface
Water Discharge Criteria (EUB
G-55
Store in a corrosive resistant
container (fiberglass, etc.)
Reuse, Neutralize pH, surface
discharge, disposal well.
Contaminated Debris
(Crude/Condensate)
[SOILCO]
Tracking
N-DOW Bill of Lading N/A N/A N/A Flashpoint
(Residual
Hydrocarbons
Remove any free liquids prior to
disposal
Store on a covered, lined pad
until disposal
On-site bioremediation or Waste
Treatment Facility or landfill.
Contaminated Soil
(Produced Water)
[SOILPW]
Tracking
N-DOW Bill of Lading N/A N/A N/A Flashpoint
(Residual
Hydrocarbons)
Remove any fee liquids prior to
disposal
Store on a covered, lined pad
until disposal
Waste Treatment Facility, or
landfill at approved Class Ia, Ib
or II facility.
Contaminated Debris
(Refined Oil/Fuel)
[SOILRO]
Tracking
DOW Manifest 3175 4.1 II Flashpoint
Leachate
Remove an free liquids prior to
disposal.
Sore on a covered, lined pad
until disposal
On-site bioremediation or Waste
Treatment Facility or landfill.
Contaminated Soil
(Sulphur)
[SOILPW]
Tracking
N-DOW N/A N/A N/A N/A Not TDG
Regulated
On-site Treatment may include
lime addition to neutralize.
Store in covered container prior
to disposal.
Material may be taken to an
approved Class II or higher
landfill.
Descicant [DESICT]
Tracking
Testing
Required
Manifest or Bill
of Lading
Corrosivity,
flashpoint,
leachate
Drain and recover free liquids Store in covered container.
Keep away from heat or
combustion sources.
Material may be taken to an
approved Class II or higher
landfill.
Domestic Garbage
[DOMWST]
Not Tracked
N-DOW N/A N/A N/A N/A Municipal Landfill Municipal Landfill
Drums/Barrels
(Methanol, oil, etc.)
[EMTCON]
Not Tracked
N-DOW Bill of Lading TDG ma be
dependent on
previous contents
Return to vendor
Recycle
Landfill
Empty, Store covered to prevent
access to elements
-Return to vendor
-Recycle
-Approved Industrial Landfill
Nexen Canada Ltd Waste Management Plan
Balzac Gas Plant 3.0 MANIFESTING
Waste Name [WASTE
CODE]
EUB tracking
Waste
Class
(N or D
Required
Document
TDG PIN TDG
Class
Packing
Group
Criteria Treatment Storage Disposal Option
Filters
(Fuel Gas)
[FILOTH]
Tracking
DOW Manifest UN 1202 3
(4.2)
(9.3)
II Flashpoint,
Pyrophoric,
leachate
Drain and collect liquids.
Liquids should be Recycled
Deep well Disposed – Ia or Ib
Store filters in a covered sealed
container, away from sources of
heat or spark
Drain (24 hours) and crush –
Class Ia or Ib landfill
Filters
(Glycol)
DOW Manifest UN 1325 4.1 Flashpoint,
phyrophoric,
leachate
Drain and collect liquids.
Liquids should be Recycled
Deep well Dipsoed – Ia or Ib
Store filters in a covered sealed
container, away from sources of
heat or spark.
Recycle, Landfill at Class Ia, Ib
or II facility, thermal treatment
Filters
(Lube oil, UNDRAINED)
[FILLUB]
Tracking
N-DOW Recycle Docket NA 9500 9.3 III Leachable Toxic Drain and crush Store filters in a covered sealed
container, away from sources of
heat or spark
-Recycle
-Incinerate
-Approved Industrial Landfill
Filters
(Gas Sweetening, Amine, Sulphinol)
[FILSWT]
Tracking
DOW Manifest UN 1325 4.1 Flashpoint,
Phyrophoric,
leachate
Drain and contain free fluid.
Fluids are DOW. Recycle filters
(metal)
Store in an air tight container,
away from sources of heat or
spark
Thermal treatment,
containerized waste ma be
disposed at Class Ia, or Ib
landfill
Filters
(Produced water)
[FILPWT]
Tracking
DOW Manifest UN 1325 4.1 Flashpoint,
phyrophoric,
leachate
Drain to remove free liquids. Store filters in a covered sealed
container, away from sources of
heat or spark.
-Recycle
-Incinerate
-Approved Industrial Landfill
Grease Cartridges [EMTCON]
Not tracked
N-DOW N/A N/A N/A N/A Store with general refuse. Landfill Municipal
Glycol Solutions
(Heavy metals – Waste Type 202)
[GLYCHM]
Tracking
DOW Manifest NA 9500 3
(9.3)
III Flashpoint,
Toxicity
Do not mix waste with other
materials (i.e. lube oil)
Store in a covered sealed
container, way from sources of
heat or spark
-Return to supplier.
-Recycle through Waste Broker
-Dispose of at Swan Hills
Glycol Solutions
(No heavy metals)
[GLYC]
Tracking
N-DOW
(Testing)
Recycle Docket NA 9500 3
(9.3)
III Flashpoint
Toxicity
Do not mix waste with other
materials (i.e. lube oil)
Store in a covered sealed
container, away form sources of
heat or spark
-Return to supplier.
-Recycle through Waste Broker.
Lube Oils
(Waste type 201)
[LUBOIL]
Tracking
N-DOW Recycle Docket NA 9500 9.3 III Leachable Toxic Do not mix waste with other
materials (i.e. glycol, etc.)
Store in a covered sealed
container, away from sources of
heat or spark
-Return to supplier
-Recycle through a Waste
Broker
Oily Rags
[OILRAG]
Not Tracked
N-DOW Recycle Docket N/A N/A N/A Not TDG
regulated unless
contaminated
with a DOW
Remove all free liquids prior to
disposal
Store material in a covered,
sealed container.
-Recycle
-Remove free liquids and
landfill
Metal
(Scrap)
[SMETAL]
Not Tracked
N-DOW Bill of Lading N/A N/A N/A Store away from other wastes to
prevent contamination
Recycle
Methanol
[METHNL]
Tracking
DOW Manifest UN 1230 3.2
(6.1)
II Flashpoint,
Toxicity
Reuse material in other
processes
Store in a covered sealed
container, away from sources of
heat or spark
Reuse, Recycle, Disposal Well
Nexen Canada Ltd Waste Management Plan
Balzac Gas Plant 3.0 MANIFESTING
Waste Name [WASTE
CODE]
EUB tracking
Waste
Class
(N or D
Required
Document
TDG PIN TDG
Class
Packing
Group
Criteria Treatment Storage Disposal Option
Paint
(Wet Paint)
[WPAINT]
Tracking
DOW Manifest UN 1263
(flammable)
UN 3066
(corrosive)
3
8
II
II
Flashpoint,
Corrosivity
Remove lid and allow paint to
dry out. Once dry the waste is
considered an “empty container”
and may be treated as such.
Store material in a sealed
covered container to prevent
access by the elements.
Thermal Treatment, Recycle,
Toxic Round-up (sm. Volume
Paint
(Cans and brushes)
[WPAINT]
N-DOW Bill of Lading N/A N/A N/A Remove lid and allow contents
to dry out
Store material in a sealed
covered container to prevent
access by the elements
Dispose dry material in a landfill
Pipe Dope Containers
(Lead and non-Lead)
[EMTCON]
Not Tracked
N-DOW N/A N/A N/A N/A Not a DOW if
empty and dry
Open container and allow
contents to dry out.
Store material in a sealed
covered container to prevent
access by the elements.
Dispose material at an approved
Class Ia, Ib or II landfill.
Sludge (Flare Knock-out)
[SLGGLY]
Tracking
DOW Manifest NA 9500 3
(9.3)
II Flashpoint,
Leachate,
Pyrophoric
Remove and collect all free
fluids prior to disposal.
Store material in a covered
container to prevent access to
the elements. Store away from
sources of spark or flame.
Free fluids should be deep well
disposed. Solids should be
treated and then landfilled.
Sludge
(Flare Pit)
[SLGPIT]
Tracking
DOW Manifest UN 3175 4.1 II Flashpoint,
Leachate,
Toxicity
Remove and collect all free
fluids prior to disposal
Store material in a covered
container to prevent access to
the elements. Store away from
sources of spark or flame.
Free fluids should be deep well
disposed. Solids should be
treated and then landfilled.
Spill Material (Produced water)
[SOILPW]
Not Tracked
N-DOW Bill of Lading N/A N/A N/A Not a TDG
regulated waste
Remove and collect all free
fluids prior to disposal.
Store material in a covered
container to prevent access to
the elements. Store away form
sources of spark or flame.
Free fluids should be deep well
disposed. Solids should be
treated and then landfilled.
Contaminated Soil
(Produced Water)
[SOILPW]
Tracking
N-DOW Bill of Lading N/A N/A N/A Flashpoint
(Residual
Hydrocarbons)
Remove any fee liquids prior to
disposal
Store on a covered, lined pad
until disposal
Waste Treatment Facility, or
landfill at approved Class Ia, Ib
or II facility.
Contaminated Debris
(Refined Oil/Fuel)
[SOILRO]
Tracking
DOW Manifest 3175 4.1 II Flashpoint
Leachate
Remove an free liquids prior to
disposal.
Sore on a covered, lined pad
until disposal
On-site bioremediation or Waste
Treatment Facility or landfill.
Contaminated Soil
(Sulphur)
[SOILPW]
Tracking
N-DOW N/A N/A N/A N/A Not TDG
Regulated
On-site Treatment may include
lime addition to neutralize.
Store in covered container prior
to disposal.
Material may be taken to an
approved Class II or higher
landfill.
Descicant [DESICT]
Tracking
Testing
Required
Manifest or Bill
of Lading
Corrosivity,
flashpoint,
leachate
Drain and recover free liquids Store in covered container.
Keep away from heat or
combustion sources.
Material may be taken to an
approved Class II or higher
landfill.
Domestic Garbage
[DOMWST]
Not Tracked
N-DOW N/A N/A N/A N/A Municipal Landfill Municipal Landfill
Drums/Barrels
(Methanol, oil, etc.)
[EMTCON]
Not Tracked
N-DOW Bill of Lading TDG ma be
dependent on
previous contents
Return to vendor
Recycle
Landfill
Empty, Store covered to prevent
access to elements
-Return to vendor
-Recycle
-Approved Industrial Landfill
Nexen Canada Ltd Waste Management Plan
Balzac Gas Plant 3.0 MANIFESTING
*Note
- Treated Wood, such as fence post’s and lumber, as long as they are not
contaminated, are a non-trackable waste.
- Contaminated wood is manifested as “Contaminated Debris”. It could be
contaminated b any of the following, and should be manifested as such:
Crude / Condensate – [SOILCO]
Produced Water – [SOILPW]
Refined Oils – [SOILRO]
Nexen Canada Ltd Waste Management Plan
Balzac Gas Plant 4.0 MINIMIZATION
A. INTRODUCTION
This Section describes the policy for the minimization of waste.
B. PURPOSE AND SCOPE
The purpose for implementing a minimization policy is three-fold; reduction of
costs, reduction of liability and compliance to regulations. The first step in
managing waste is through realization and implementation of the 4-R’s are:
Reduce
Reuse
Recycle
Recover
C. PROCEDURES
Reduce Generate less waste through more effective practices
Cost savings – less waste to dispose of
Reduction in liability – less wastes means reduced liability in case
there is an adverse environmental impact involving your waste
Safety – less waste to handle (especially DOWs) means less worker
exposure
Environmental – less chance of impacting the environment
Some of the more effective practices are:
Substitute non-hazardous products for hazardous ones in order that the
waste streams by non-DOW
Segregate DOWs from non-DOWs as all waste contaminated with a
DOW will become a DOW and increase the volume of DOWs
Segregate wastes into recyclable and non-recyclable categories to
reduce the disposal costs and to facilitate recycling
Purchase products in larger quantities to reduce the amount of
containers whenever possible
Eliminate spill and leaks through proper equipment inspection and
handling procedures
Reuse: Generate less waste through reuse of materials
Some of the more effective practices are:
Return containers to the supplier
Return used lube oils to the supplier
Use of used oils for other purposes
Nexen Canada Ltd Waste Management Plan
Balzac Gas Plant 4.0 MINIMIZATION
Recycle: Minimize treatment and disposal of waste by utilizing recycling
Facilities
Some of the more effective practices include recycling the following
materials:
Rags
Sorbent material
Lube oils
Metals
Paper and cardboard
Plastic
Containers
Batteries
The plants also recycle their used filters, by sending them to RB Williams
which recycle almost all parts of the filter.
Recover: Recover useful components of a waste including energy content
This is the most difficult of the 4-R’s to implement. Some of the more
effective practices are:
Use of lube oils as boiler fuel
Recovery of hydrocarbons at a waste management facility
Recovery of metal cores from filters
Recovery of gold and silver from tower trays
Nexen Canada Ltd Waste Management Plan
Balzac Gas Plant 5.0 STORAGE REQUIREMENTS
A. INTRODUCTION
All storage tanks used in the Upstream Petroleum Industry are under the control
of the AEUB Guide G-55 Guidelines. These guidelines direct the use, testing and
monitoring of Above Ground Storage Tanks (ASTs), Underground Storage Tanks
(USTs) and Container Storage.
B. PURPOSE AND SCOPE
This practice applies to new and existing facilities. For more detailed information
refer to the G-55 Storage Guidelines.
All wastes must be properly stored, so as to prevent:
Leaking
Spilling
Contact with incompatible wastes
Contact with the environment
Creating a hazard to humans and livestock and wildlife
Mixing of DOW and non-DOWs
Creating a safety hazard
C. REQUIREMENTS
Aboveground Storage Tanks
Construction
Volume 1m³ to 5m³
The tank must have non-leaking hoses, fittings and nozzles. There is no
secondary requirement; however, it is a good idea to install a liner or tray
under the tank at the time of construction. This will contain any spills
should they occur.
As well, a drip tray should be installed around any filling areas to contain
any leaks, spills or over-fills.
Volume >5m
The tank must have cathodic protection (steel tanks in corrosive
environments) and all steel tanks must be externally coated (also internal
coating in a corrosive environment)
The tank(s) must be placed in a lined and bermed area. The liner must be
impervious to the materials being stored as well as to water. The
hydraulic conductivity must be at least 1 x 10-6
cm/s.
Nexen Canada Ltd Waste Management Plan
Balzac Gas Plant 5.0 STORAGE REQUIREMENTS
The diked area must be graded such that there is one low corner to
facilitate clean-up and water removal.
The dikes must be large enough to contain 100% of the volume of the tank
(where only one tank is present) or 110% of the largest +10% of each
remaining tanks contained within the same tank area. This extra 10% per
tank is to facilitate the displacement the tanks present to overall volume.
Inspections
All Aboveground Storage Tanks required a monthly visual inspection.
This inspection includes a physical walk around the tank(s) and tank area
to inspect for leaks, blowovers, etc. Any spills, leaks, overfills, etc must
be documented.
The berm must be inspected to ensure there are no breaks and that the dike
drain (if present) is closed.
Storage Areas / Barrel Docks
Construction
When the total stored volume of the storage area is greater than 1m³ (5 –
45 gallon drums), the following conditions must be met as per EUB Guide
55):
Secondary containment – a clay or synthetic liner, impervious to
the stored material, which prevents a direct connection to the
ground underneath or the surrounding area.
Weather protection – a cover or roof to prevent exposure to the
elements. Alternatively, use of weather resistant containers is also
appropriate.
Inspections
The storage area must be visually inspected monthly. This inspection
must include a physical inspection of the lined / bermed area, ensuring that
the liners is intact; the storage containers must not be leaking; and the
surrounding area must not show signs of a spill.
All monthly inspections must be documented. This may be done in an
operator’s log book or in a specific Inspection Form. The records of these
inspections must be retained for a minimum of two years. The EUB may
request these records when performing a facility or waste audit.
Nexen Canada Ltd Waste Management Plan
Balzac Gas Plant 5.0 STORAGE REQUIREMENTS
Underground Storage Tanks
Construction
All USTs constructed after January, 1996 must have secondary
containment. This is not a retroactive regulation where all tanks have to
meet this regulation, only those installed after January 1996.
The secondary containment requirements may be met by utilizing one of
the following methods:
Synthetic liner (External or internal tank liners)
Double-walled tanks
Concrete vault
Etc.
Whenever a UST is exposed for testing or repair, it must be brought up to
regulation.
Underground storage tank vents must be checked to ensure that they are
not over-flowing (e.g. flare-knockout tanks, etc.)
D. TANK INTEGRITY TESTING
Aboveground Storage Tanks (ASTs)
Testing
All storage tanks used in the Upstream Petroleum Industry must have their
integrity verified prior to October 31, 2001.
The following test types are approved methods for verifying the integrity
of the tanks:
Air Pressure Test
Air Vacuum Test
Hydrostatic Test
48 Hour Volumetric Test
Other tests if they are approved by the EUB
Once the tank has had its integrity verified, the records of the test must be
retained a minimum of five years. The tank must be checked every 3
years thereafter.
Nexen Canada Ltd Waste Management Plan
Balzac Gas Plant 5.0 STORAGE REQUIREMENTS
Monitoring
The integrity of the tank must be verified to demonstrate that the material
has not escaped. This verification may be demonstrated in the following
ways:
Monthly visual inspections of tanks and liners for evidence of
spills.
Incorporation of a weeping tile system, which is monitored
monthly.
Documentation
All records of tank integrity verification and monitoring should be retained
at the field or area offices. These records should be retained for a
minimum of five years.
Underground Storage Tanks (USTs)
Testing
All storage tanks used in the Upstream Petroleum Industry must have their
integrity verified prior to October 31, 2001, and every 3 years thereafter.
In order to comply with this requirement, the validity of every tank will be
verified using one of the following tests:
Integrity Testing (if tank can be blinded)
Air Pressure Testing
Air Vacuum Testing
Hydrostatic Testing
Other EUB approved testing procedure
Integrity Testing (if tank can not be blinded)
Volumetric test
Monitoring wells (dedicated to the tanks)
Other EUB approved testing procedure
If a UST is excavated and/or removed for repairs, it must meet the G-55
guidelines in order to be returned to service.
Monitoring
All USTs must be monitored regularly to ensure their integrity. This may
be achieved in one or more of the following methods:
A monitoring well located between the synthetic liner and the tank.
The well should be situated at the low end of the sloped liner. The
well should be sampled monthly.
Annual monitoring of the interstitial space of the double walled
tanks.
Nexen Canada Ltd Waste Management Plan
Balzac Gas Plant 5.0 STORAGE REQUIREMENTS
Monthly monitoring of a weeping tile system.
Integrity verification
All records of tank integrity verification and monitoring should be retained at the
field or area offices. These records should be retained for a minimum of three
years.
Containers
Separate storage bins or barrels should be set up for aerosol containers, paint cans,
pipe dope containers, and any other such containers that can be collected and
disposed of at a Class 1a, 1b or Class II landfill.
Nexen Canada Ltd Waste Management Plan
Balzac Gas Plant 6.0 WASTE MANAGEMENT FACILITIES
EUB APPROVED LANDFILLS
Anadime Processing and Disposal Inc
430, 1015 – 4 St. SW
Calgary AB
T2R 1J4
(403) – 777-4310
Anadime Elk Point
Location: 4-18-57-4 W5M
EUB Approval No: WM 045
Anadime Hays
Location: 5-19-13-14 W5M
EUB Approval No: WM 025
Anadime Niton Junction
Location: 6-33-3-12 W5M
EUB Approval No: WM 024
Upstream oilfield waste liquids and solids, DOW and non-DOW including sour fluids.
Processing of drilling wastes, completion fluids, production fluids and solids, workover
fluids and solids, spill materials, pit and pond fluids and solids and pipeline fluids.
Facility has a Class Ib disposal well for disposing of glycols, amines, inhibitors and wash
waters. Not permitted to receive lube oil or refined products such as gasoline or
industrial wastes. Have interim license for invert drill cuttings (expected June/99).
Anadime Provost
Location: 1-1-40-3 W4M
EUB Approval No: WM 031
Anadime Stettler
Location: 16-18-38-20 W4M
EUB Approval No: WM 018
Nexen Canada Ltd Waste Management Plan
Balzac Gas Plant 6.0 WASTE MANAGEMENT FACILITIES
Area 1 Reclaiming Ltd
21369 Highway 38
Box 646
Redwater AB
T0A 2W0
(403)-875-7752
Area 1 Redwater
Location: 7-4-57-21 W4M
EUB Approval No: WM 064
Canadian Crude Separators
2400, 530 – 8Ave SW
Calgary, AB
T2P 3S8
(403)-233-7565
Canadian Crude Separators Big Valley
CCS
Box 221
Big Valley, AB
T0J 0G0
Phone: (403)-876-2636
Fax: (403)-846-2248
Plant Manager: Kelly Shanks
Facility Code: 653
Location: 10-36-35-20 W4M
EUB Approval No: WM 005
Big Valley Waste Management Facility Acceptable Waste Streams:
All waste streams compatible with Class 1b disposal well as per Alberta Energy and
Utilites Board Guide G-51 (Injection and Disposal Wells). Select upstream oilfield waste
as per Alberta Energy and Utilities Board Guide G-58 (Oilfield Waste Management
Requirements for the Upstream Petroleum Industry).
Canadian Crude Separators Coronation
CCS c/o Coronation Tire
4901 Victoria Avenue
Coronation, AB
T0C 1C0
Phone: (403)-575-3911
Nexen Canada Ltd Waste Management Plan
Balzac Gas Plant 6.0 WASTE MANAGEMENT FACILITIES
Fax: (403)-575-3927
Plant Manager: Mark Zimmer
Location: 12-30-34-11 W5M
EUB Approval No: WM 004
Facility Code: 654
Canadian Crude Separators Brazeau
Phone: (780)-894-2291
Fax: (780)-894-2296
Location: 11-3-47-11- W5M
EUB Approval No: WM 048
Facility Code: 694
The Brazeau Waste Management Facility Acceptable Waste Streams:
All waste streams compatible with Class 1b disposal well as per Alberta Energy and
Utilities Board Guide G-51 (Injection and Disposal Wells). Select upstream oilfield
waste as per Alberta Energy and Utilities Board Guide G-58 (Oilfield Waste
Management Requirements for the Upstream Petroleum Industry). Acid Solution, Boiler
Blowdown Water, Caustic Solution, Contaminated Debris and soil (Crude
Oil/Condensate), Contaminated Debris and Soil (Produced Water), Contaminated Debris
and Soil (Sulphur), Corrosion Inhibitor/Oxygen Scavenger Solutions, Crude
Oil/Condensate Emulsions, Drilling Sump Materials (Gel Chem), Drilling Sump
Materials (KCl), Drilling Sump Materials (Hydrocarbons), Frac Sand - Non Radioactive,
Glycol Solutions (no Heavy Metals), Hydrotest Fluids - Water, Wash Fluids - Organic,
Water - Process (with Heavy Metals), Water - Process (with Organic Chemicals), Water -
Produced, Well Workover Fluids.
Canadian Crude Separators Edson
Location: 5-24-51-15 W5M
EUB Approval No: WM 019
Canadian Crude Separators Fox Creek
CCS
Box 120
Fox Creek, AB
T0H 1P0
Phone: (780)-622-3355
Fax: (780)-622-3664
Plant Manger: Ralph Juuti
Facility Code: 686
Location: 3-29-62-20 W5M
EUB Approval No: WM 040
Nexen Canada Ltd Waste Management Plan
Balzac Gas Plant 6.0 WASTE MANAGEMENT FACILITIES
Waste handled/processed at this facility:
All waste streams compatible with Class 1b disposal well as per Alberta Energy and
Utilities Board Guide G-51 (Injection and Disposal Wells). Select upstream oilfield
waste as per Alberta Energy and Utilities Board Guide G-58 (Oilfield Waste
Management Requirements for the Upstream Petroleum Industry).
Canadian Crude Separators Fox Creek Landfill
CCS
Box 120
Fox Creek, AB
T0H 1P0
Phone: (780)-622-2981
Fax: (780)-622-2361
Plant Operator: Matt Harrington
Location: SE1/4-6-62-18 W5M
EUB Approval No: WM 050
Waste handled/processed at this facility:
Non-dangerous solid oilfield waste as per Alberta Energy and Utilities Board Guide G-58
(Oilfield Waste Management Requirements for the Upstream Petroleum Industry).
Canadian Crude Separators Judy Creek
CCS c/o Whitecourt Answering Service
Box 2071
Whitecourt, AB
T7S 1P7
Location: 4-5-63-11 W5M
EUB Approval No: WM 009
Judy Creek Waste Management Facility Acceptable Waste Streams:
All waste streams compatible with Class 1b disposal well as per Alberta Energy and
Utilities Board Guide G-51 (Injection and Disposal Wells). Select upstream oilfield
waste as per Alberta Energy and Utilities Board Guide G-58 (Oilfield Waste
Management Requirements for the Upstream Petroleum Industry).
Canadian Crude Separators LaGlace
CCS c/o Phoenix Oilfield Supply
10933 - 96 Avenue
Grande Prairie, AB
T9V 3J4
Plant Manager: Tim Dalgleish
EUB Approval No: WM 027
Nexen Canada Ltd Waste Management Plan
Balzac Gas Plant 6.0 WASTE MANAGEMENT FACILITIES
1. Treating Facility
Location: 12-8-73-8 W6M
Phone: (780)-766-3111
Fax: (780)-766-2959
2. Disposal Facility #1
Location: 08-09-72-08 W6M
Phone: (780)-766-2401
Fax (780)-766-2620
3. Disposal Facility #2
Location: 16-36-72-09 W6M
Phone: (780)-766-3550
Fax: (780)-3777
La Glace Waste Management Facility Acceptable Waste Streams:
All waste streams compatible with Class 1b disposal well as per Alberta Energy and
Utilities Board Guide G-51 (Injection and Disposal Wells). Select upstream oilfield
waste as per Alberta Energy and Utilities Board Guide G-58 (Oilfield Waste
Management Requirements for the Upstream Petroleum Industry).
Canadian Crude Separators Lindbergh
Location: 5-26-59-5 W4M
EUB Approval No: WM 061
Canadian Crude Separators Mitsue
Location: 4-29-72-4 W5M
EUB Approval No: WM 007
Canadian Crude Separators Mitsue Landfill
Location: 4-29-72-4 W5M
EUB Approval No: WM 041
Mitsue Class II Oilfield Landfill Acceptable Waste Streams:
Non-Dangerous solid oilfield waste as per Alberta Energy and Utilities Board G-58
(Oilfield Waste Management Requirements for the Upstream Petroleum Industry).
Canadian Crude Separators Valleyview
Box 1779
Valleyview, AB
Nexen Canada Ltd Waste Management Plan
Balzac Gas Plant 6.0 WASTE MANAGEMENT FACILITIES
T0H 3N0
Phone: (780)-524-3336
Fax: (780)-524-3957
Plant Manager: Randy Woolston
Facility Code: 669
Location: 9-16-69-22 W5M
EUB Approval No: WM 006
All waste streams compatible with Class 1b disposal well as per Alberta Energy and
Utilities Board Guide G-51 (Injection and Disposal Wells). Select upstream oilfield
waste as per Alberta Energy and Utilities Board Guide F-58 (Oilfield Waste Management
Requirements for the Upstream Petroleum Industry).
Canadian Crude Separators Wolf Lake
Location: 9-1-48-14 W5M
EUB Approval No: WM 056
Medicine River Oil Recyclers Ltd.
Medicine River Eckville Medicine River Oil Recyclers Ltd
P.O Box 76 Box 58
Eckville AB Eckville, AB
T2R 1L9 T0M 0X0
Phone: (403)-746-3130
Fax: (403)-746-2666
Upstream petroleum wastes including produced oilwater and water spill debris; oilfield
pits and ponds; tank and treater bottoms; frac sands, emulsion; KCl water sands; frac
fluids; caustic water; cement water; frac oils; boiler blowdown water; oilfield fresh water;
neutralized acid water; Hydro-Test fluids; inhibited annular fluids; uncrosslinked diesel
gel; oilfield spill fluids; and wash water from upstream oil and gas operations. This
facility also approved to handle waste streams and emulsions containing hydrogen
sulphide and has a Class Ib disposal well.
Newalta Corporation
1200, 333 – 11 Ave SW
Calgary, AB
T2R 1L9
(403)-266-6556
Newalta Brooks
Location: 1-25-18-14 W4M
Nexen Canada Ltd Waste Management Plan
Balzac Gas Plant 6.0 WASTE MANAGEMENT FACILITIES
EUB Approval No: WM 013
Newalta Brooks
Location: 1-25-18-14 W4M
EUB Approval No: WM 065
Newalta Clairmont
Location: 16-35-72-6 W6M
EUB Approval No: WM 065
Newalta Drayton Valley
Location: 12-28-48-7 W5M
EUB Approval No: WM 010
Newalta Drayton Valley Disposal Well
Location: 8-23-48-8 W5M
EUB Approval No: WM 043
Newalta Eckville
Location: 11-21-39-3 W5M
EUB Approval No: WM 003
Upstream oilfield waste management (DOW and non-DOW) including crude oil
emulsions, drilling mud, hydrocarbon sludge for treatment and disposal. Sour water
solutions for class 1b well disposal. Lubricating oil, glycol solutions and waste
flammable liquids accepted for storage and transfer.
Newalta Elk Point
Location: 3-15-55-6 W4M
EUB Approval No: WM 042
Dangerous and Non-Dangerous oilfield waste.
Newalta Gordondale
Location: 9-10-73-10 W6M
EUB Approval No: WM 021
Nexen Canada Ltd Waste Management Plan
Balzac Gas Plant 6.0 WASTE MANAGEMENT FACILITIES
Newalta Grande Prairie
Location: 6-2-71-6 W6M
EUB Approval No: WM 017
Newalta Hughenden
Location: 16-33-40-7 W4M
EUB Approval No: WM 001
Newalta Red Earth
Location: 12-13-87-9 W5M
EUB Approval No: WM 002
Newalta Stauffer
Location: 16-11-37-5 W5M
EUB Approval No: WM 012
Newalta Taber
Location: 3-4-9-16 W4M
EUB Approval No: WM 022
Newalta Valleyview
Location: 4-21-69-22 W5M
EUB Approval No: WM 047
Newalta Zama Disposal Well
Location: 8-21-116-6 W6M
EUB Approval No: WM 063
Newalta Zama
Location: 12-18-116-5 W6M
EUB Approval No: WM 011
Normcan Control Inc.
1430, 717 – 7 Ave SW
Calgary, AB
T2P 0Z3
(403)-294-3031
Nexen Canada Ltd Waste Management Plan
Balzac Gas Plant 6.0 WASTE MANAGEMENT FACILITIES
Normcan Standard
Location: NW1/4-3-25-22 W4M
EUB Approval No: WM 052
PetroVera Resources Limited
P.O Box 1070
Llyodminister SK
S9V 1E9
(780)-875-9186
PetroVera Frog Lake
Location: SE1/4-32-55-03 W4M
EUB Approval No: WM 058
Producers Disposal Services Ltd
P.O Box 7318
Edson AB
T7E 1V5
(780)-693-2226
PDS Paddle River
Location: 16-31-56-8 W5M
EUB Approval No: WM 060
Rag Industries Inc. 4804 – 44 Ave
Stettler AB
T0C 2L0
(403)-742-6900
Rag Industries Stettler
Location: 4804 – 44 Ave.
EUB Approval No: WM 053
Canadian Natural Resources Limited
P.O. Box 6926
Station D
2500, 855 – 2 St. SW
Calgary, AB
T2P 2G1
(403)-221-2100
Nexen Canada Ltd Waste Management Plan
Balzac Gas Plant 6.0 WASTE MANAGEMENT FACILITIES
CNRL Lindberg
Location: 14-28-55-6 W4M
EUB Approval No: WM 034
RemedX Remediation Services Inc. 308, 1305 – 11 Ave SW
Calgary, AB
T2P 2G1
(403)-209-0004
RemedX Breton
Location: NW1/4-12-48-4 W5M
EUB Approval No: WM 051
Western Canadian Environmental Services Ltd.
P.O Box 1009
105, 150 Crowfoot Crescent NW
Calgary AB
T3G 3T2
(403)-239-3797
WCES Rainbow Lake
Location: 16-32-110-05 W6M
EUB Approval No: WM 057
Western Oil Processors Ltd. 1104, 10080 Jasper Ave.
Edmonton, AB
T5J 1V9
(780)-941-2380
(780)-421-1698
Western New Sarepta
Location: 6-11-50-22 W4M
EUB Approval No: WM 023
Nexen Canada Ltd Waste Management Plan
Balzac Gas Plant 6.0 WASTE MANAGEMENT FACILITIES
Alberta Environment Approved Landfills
Brooks Newell Waste Recovery Facility
Location: 4-15-19-34
Approval No: 00070359 00 00
Facility Owner: Newell Regional Solid Waste Management Authority
Expiry: Sept. 1, 2006
Document Type: AENV Approved
Classification: Class II
Sanitary Landfill
Accepted Waste Types: Non-hazardous solid industrial and oilfield wastes.
Calgary BFI Landfill
Location: 5-1-22-13 NW
Approval No: 00018690 00 00
Facility Owner: BFI Canada Inc.
Expiry: Sept. 1, 2006
Document Type: Health Approved
W 0358
Classification: Class II
Waste handled/processed at this facility:
Municipal Solid Waste
Sulphur
Asbestos
Construction and Demolition
Autoclaved Biomedical Waste
White Goods (w/removal of freon certification)
Non-hazardous industrial including contaminated soils and sludges (must have a
flashpoint greater than 61ºC, no free liquids, pH must be between 2.0 and 12.4
Wastes not handles/processed at this facility:
Propane tanks, batteries, non-treated biomedical, air conditioning units, hazardous
waste, radio active waste (>2400cpm), putresibles, and free liquids.
City of Calgary: East Calgary Landfill
Location: 4-29-24-11 E
Approval No: 00019090 01 00
Facility Owner: City of Calgary
Expiry: Sept. 1, 2001
Document Type: Health Approved
Classification: Class II
Nexen Canada Ltd Waste Management Plan
Balzac Gas Plant 6.0 WASTE MANAGEMENT FACILITIES
City of Calgary: Shepard Landfill
Location: 4-29-23-2 N & 4-29-23-11
Approval No: 00111216 00 04
Facility Owner: City of Calgary
Expiry: Sept. 1, 2001
Document Type: AENV Approved
Classification: Class II
City of Calgary: Spyhill Landfill
Location: 5-2-25-26
Approval No: 00019101 01 00
Facility Owner: City of Calgary
Expiry: Sept. 1, 2001
Document Type: Health Approved
Classification:
Drumheller Regional Landfill
Location: 4-20-28-36 NE
Approval No: 00047449 00 00
Facility Owner: Drumheller and District Solid Waste Management Association.
Expiry: Sept. 1, 2001
Document Type: Health Approved
Classification:
Okotoks/Foothills Regional Landfill
Location: 4-29-19-32 SE
Approval No: 000417447 00 00
Facility Owner: Foothills Regional Services Commission
Expiry: Sept. 1, 2001
Document Type: Health Approved
Classification:
Three Hills Municipal Landfill
Location: 4-24-31-25 W4M
Approval No: 00018653 00 00
Facility Owner: Town of Three Hills
Expiry: Sept. 1, 2006
Document Type: Health Approved
Classification:
Nexen Canada Ltd Waste Management Plan
Balzac Gas Plant 6.0 WASTE MANAGEMENT FACILITIES
Cold Lake/WMF/Municipal Landfill
Location: 4-2-63-27 NE
Approval No: 00047716 00 00
Facility Owner: Town of Cold Lake
Expiry: Sept. 1, 2001
Document Type: Health Approved
Classification:
Edmonton/WMF/Municipal Landfill, Clover Bar
Location: 4-23-53-28 SE
Approval No: 00047140 00 00
Facility Owner: City of Edmonton, Asset Management and Public Works.
Expiry: Sept. 1, 2006
Document Type: Health Approved
Classification:
Edmonton/WMF/Municipal Landfill, West
Location: 4-25-53-15 S
Approval No: 00048819 00 00
Facility Owner: Canadian Waste Services Inc.
Expiry: Sept. 1, 2006
Document Type: Health Approved
Classification:
Fort McMurray/WMF/Municipal Landfill
Location: 4-9-88-22
Approval No: 00020670 00 00
Facility Owner: Regional Municipality of Wood Buffalo
Expiry: Sept. 1, 2001
Document Type: Health Approved
Classification:
Sturgeon/WMF/Municipal Landfill/Compost, Sturgeon Regional
Location: 4-25-55-36 SW
Approval No: 00047061 00 00
Facility Owner: Sturgeon Regional Landfill Authority
Expiry:
Document Type: Health Approved
Classification:
Cholla Sand and Dry Waste Inc.
Nexen Canada Ltd Waste Management Plan
Balzac Gas Plant 6.0 WASTE MANAGEMENT FACILITIES
Location: 4-26-52-35
Approval No: 00020686 00 00
Facility Owner: Cholla Sand and Dry Waste Inc.
Expiry: Sept. 1, 2006
Document Type: AENV Approved
Classification:
Northlands Sand and Gravel
Location: 4-26-52-02 NE
Approval No: 00049589 00 00
Facility Owner: Northlands Sand and Gravel.
Expiry: Sept. 1, 2006
Document Type: AENV Approved
Classification:
Alberta Special Waste Treatment Centre
Location: 8-08-67-06 W
Approval No: 00001744 00 00
Facility Owner: Chem-Security (Alta) Ltd
Expiry: Dec. 1, 2005
Document Type: AENV Approved
Classification:
Pembina Hazardous Waste Landfill
Location: 5-11-50-17 SW & 5-11-50-18 SE
Approval No: 00048516 00 00
Facility Owner: Byram Industrial Services Ltd.
Expiry: March 31, 2009
Document Type: AENV Approved
Classification:
Fairview/WMF/Municipal landfill
Location: 6-3-82-27 SW
Approval No: 00020940 00 00
Facility Owner: Town of Fairview
Expiry: Sept. 1, 2001
Document Type: Health Approved (AENV Approval under consideration)
Classification:
High Prairie/WMF/Municipal landfill
Nexen Canada Ltd Waste Management Plan
Balzac Gas Plant 6.0 WASTE MANAGEMENT FACILITIES
Location: 5-18-74-24 NW
Approval No: 00020969 00 00
Facility Owner: Town of High Prairie
Expiry: Sept. 1, 2006
Document Type: AENV (Registered) (Approval process in progress)
Classification:
Peace River/WMF/Municipal Landfill, East Peace Regional
Location: 5-20-84-2 SW
Approval No: 00020252 00 00
Facility Owner: Municipal District of East Peace No.131
Expiry: Nov. 30, 2000
Document Type: Health Approved (AENV Approval process in progress)
Classification: Sanitary Landfill Class II
Red Earth Creek/WMF/Municipal Landfill/Transfer Station
Location: 5-8-87-19
Approval No: 00071127 00 00
Facility Owner: Municipal District of Opportunity No. 17
Expiry: Sept. 1, 2006
Document Type: AENV (Registered) (AENV Approval process in progress)
Classification:
Grande Prairie/WMF/Municipal Landfill
Location: 6-6-71-2 NE
Approval No: 00020954 00 00
Facility Owner: City of Grande Prairie
Expiry: Sept. 1, 2006
Document Type: AENV Approved
Classification:
High Level – Mackenzie/WMF/Regional landfill
Location: 5-20-110-1 SE
Approval No: 00073493 00 00
Facility Owner: Town of High Level
Expiry: Sept. 1, 2006
Document Type: AENV Approved
Classification:
MD of Spirit River
Nexen Canada Ltd Waste Management Plan
Balzac Gas Plant 6.0 WASTE MANAGEMENT FACILITIES
Location: 6-5-77-31 SW
Approval No:
Facility Owner:
Expiry:
Document Type: AENV Approval process in progress
Classification:
Slave Lake/WMF/Lesser Slave Lake Regional Landfill
Location: 5-7-73-13 NE
Approval No: 00072856 00 00
Facility Owner: Lesser Slave Regional Waste Management Services Commission
Expiry: Nov. 30, 2009
Document Type: AENV Approved (Under construction)
Classification:
Leduc/WMF/Municipal Landfill, Regional
Location: 4-24-49-29 NE
Approval No: 00047073 00 00
Facility Owner: Leduc & District Regional Waste Management Authority
Expiry: Sept. 1, 2006
Document Type: Health Approved
Classification: Class II
Ridgeview/WMF/Municipal Landfill, Regional
Location: 4-25-37-10 NW
Approval No: 00046896 00 00
Facility Owner: Central Alberta Waste Management Authority
Expiry: Sept. 1, 2006
Document Type: Health Approved
Classification:
West Dried Meat Lake/WMF/Municipal Landfill, Regional
Location: 4-21-44-14 SW
Approval No: 00078945 00 00
Facility Owner: West Dried Meat Lake Regional Waste Management Authority
Expiry: Sept. 1, 2006
Document Type: Health Approved
Classification:
Camrose/WMF/Municipal Landfill, Regional
Location: 4-20-46-16 N
Nexen Canada Ltd Waste Management Plan
Balzac Gas Plant 6.0 WASTE MANAGEMENT FACILITIES
Approval No: 00047636 00 00
Facility Owner: Camrose Regional Solid Waste Authority
Expiry: Sept. 1, 2006
Document Type: Health Approved
Classification:
Drayton Valley/WMF/Industrial, Municipal Landfill, Regional
Location: 5-7-49-20 SE
Approval No: 00047415 00 00
Facility Owner: Drayton Valley Regional Sanitary Landfill Authority
Expiry: Sept. 1, 2001
Document Type: AENV Approved
Classification: Regional Sanitary
Red Deer/WMF/Municipal Landfill
Location: 4-27-37-33 NE
Approval No: 00074348 00 00
Facility Owner: City of Red Deer
Expiry: Sept. 1, 2001
Document Type: Health Approved (New Landfill under construction)
Classification:
Rocky Mountain House/WMF/Industrial, Municipal Landfill, Regional
Location: 5-9-40-12 E
Approval No: 00047645 00 00
Facility Owner: Rocky Mountain Regional Solid Waste Authority
Expiry: Sept. 12, 2006
Document Type: AENV Approved
Classification:
Ryley/WMF/Municipal Landfill, Beaver, Regional
Location: 4-17-50-10 NE
Approval No: 00020754 00 00
Facility Owner: Beaver Regional Waste Management Commission
Expiry: Sept. 1, 2006
Document Type: AENV Approved
Classification: Class II
Big Valley
Location: 4-20-35-30 SW
Nexen Canada Ltd Waste Management Plan
Balzac Gas Plant 6.0 WASTE MANAGEMENT FACILITIES
Approval No:
Facility Owner: Canadian Waste Service
Expiry: Sept. 1, 2006
Document Type: Health Approved
Classification:
Bow Island/WMF/Municipal Landfill, North Forty Mile Regional
Location: 4-11-11-23 SE
Approval No: 00074841 00 00
Facility Owner: County of Forty Mile No. 8
Expiry: Sept. 1, 2006
Document Type: Health Approved
Classification:
Boychuk/WMF/Municipal Dry Waste Landfill
Location: 4-22-9-11 SW
Approval No: 00020983 01 00
Facility Owner: William Boychuk
Expiry: March 1, 2008
Document Type: AENV Approved
Classification:
Cardston/WMF/Chief Mountain Regional Landfill
Location: 4-24-4-15 SE
Approval No: 000801109 01 00
Facility Owner: Chief Mountain Regional Solid Waste Authority
Expiry:
Document Type: AENV Approved
Classification:
Claresholm/WMF/Municipal Landfill
Location: 4-27-12-21 SE
Approval No: 00050110 01 00
Facility Owner: Town of Claresholm
Expiry:
Document Type: AENV Approved
Classification:
Claresholm/WMF/Willow Creek Regional Landfill, Dry Waste
Location: 4-26-11-22 NW
Approval No: 00077849 00 00
Nexen Canada Ltd Waste Management Plan
Balzac Gas Plant 6.0 WASTE MANAGEMENT FACILITIES
Facility Owner: Willow Creek Regional Waste Management Commission
Expiry:
Document Type: AENV Approved
Classification:
Crowsnest – Pincher Creek/WMF/Municipal Landfill, Regional
Location: 4-1-7-8 SW
Approval No: 00018701 00 00
Facility Owner: Crowsnest – Pincher Creek Regional Waste Management
Authority
Expiry: Sept. 1, 2006
Document Type: AENV Approved
Classification:
Enchant/WNF/Municipal
Location: 4-18-14-16 NW
Approval No: 00137502 00 00
Facility Owner: Municipal District of Taber.
Expiry: Sept. 1, 2006
Document Type: Health Approved
Classification:
Grassy Lake/WMF/Municipal Landfill
Location: 4-13-10-15 NW
Approval No: 00018787 00 00
Facility Owner: Municipal District of Taber
Expiry: Sept. 1, 2006
Document Type: Health Approved
Classification:
Hays/WMF/Municipal Landfill
Location: 4-14-13-36 SE
Approval No: 00137508 00 00
Facility Owner: Municipal District of Taber
Expiry: Sept. 1, 2006
Document Type: Health Approved
Classification:
Iron Springs/WMF/Dry Waste Landfill
Location: 4-14-13-36 SE
Approval No: 00018746 00 00
Nexen Canada Ltd Waste Management Plan
Balzac Gas Plant 6.0 WASTE MANAGEMENT FACILITIES
Facility Owner: Lethbridge Waste Services Commission
Expiry: Sept. 1, 2006
Document Type: Health Approved
Classification:
Lethbridge County/WMF/Dry Waste Landfill
Location: 4-20-10-22 NE
Approval No: 00018753 00 00
Facility Owner: County of Lethbridge No 26
Expiry: Sept. 1, 2006
Document Type: Health Approved
Classification:
Lethbridge/WMF/Municipal Landfill, Regional
Location: 4-21-10-33 NW
Approval No: 00019028 00 00
Facility Owner: City of Lethbridge
Expiry: Sept. 1, 2006
Document Type: AENV Approved
Classification:
Medicine Hat/WMF/Dry Landfill, Westar
Location: 4-4-12-31
Approval No: 00072729 00 00
Facility Owner: Westar Landfill Ltd.
Expiry: Sept. 1, 2006
Document Type: AENV Approved
Classification:
Medicine Hat/WMF/Municipal Landfill,
Location: 4-5-12-34 NW
Approval No: 00078246 00 00
Facility Owner: City of Medicine Hat
Expiry: Sept. 1, 2001
Document Type: Health Approved
Classification:
Redcliff-Cypress/WMF/Municipal Landfill
Location: 4-7-13-23 E
Approval No: 00074850 00 00
Facility Owner: Town of Redcliff
Nexen Canada Ltd Waste Management Plan
Balzac Gas Plant 6.0 WASTE MANAGEMENT FACILITIES
Expiry: Sept. 1, 2006
Document Type: Health Approved
Classification:
Taber/WMF/Municipal Landfill
Location: 4-17-10-12 SW
Approval No: 00018985 00 00
Facility Owner: Town of Taber
Expiry: Sept. 1, 2001
Document Type: Health Approved
Classification:
Vauxhall/WMF/Municipal Landfill
Location: 4-16-13-12 SW
Approval No: 00137512 00 00
Facility Owner: Town of Vauxhall
Expiry: Sept. 1, 2006
Document Type: Health Approved
Classification:
Nexen Canada Ltd Waste Management Plan
Balzac Gas Plant 6.0 WASTE MANAGEMENT FACILITIES
Others
Safety-Kleen (Ryley) Ltd
P.O. Box 390
Ryley, AB
T0B 4A0
Class I Landfill/Transfer Station
Facility is a hazardous waste transfer station and secure Class 1b landfill. All classes of
waste acceptable except explosives, biological/pathological and radioactives.
Hazco Environmental Services Ltd.
200, 5720 - 4 Street S.E.
Calgary, AB
T2H 1K5
Phone (403)-297-0415
East Peace Industrial Waste Treatment and Disposal Site.
Location: SW 1/4-2-84-20 W5M
Facility Owner: M.D of East Peace No. 131
Class 2 Sanitary Landfill - acceptable wastes are non-hazardous (non-DOW) petroleum
wastes and other non-hazardous industrial wastes (no free liquids). Bioremediation
option available.
Beaverlodge Transfer Station
This facility is licensed by AEP to store, process and transfer hazardous wastes and
recyclables. The facility can accept Class 3-6, 8 and 9 hazardous wastes. Dangerous
Oilfield Wastes (DOW's), Hazardous recyclables and non-hazardous materials. The
facility cannot accept PCB's, explosives, compressed gases, radioactive wastes and
biological/pathological wastes. Although the facility is licensed to volume reduce shred,
segregate, separate and recover liquids, the facility serves only as a collection point and
all further processing occurs at the Calgary Transfer Station.
Calgary Waste Storage and Transfer Facility
Hazardous and industrial waste storage, recyclables processing and transfer facility.
Wastes from the following TDG classes are acceptable: 2,3,4,5,6,8 and 9. Combined
capacity of 230 tonnes including 20 tonnes of PCB waste.
rbw Waste Management Ltd. 4625 - 101 Street
Nexen Canada Ltd Waste Management Plan
Balzac Gas Plant 6.0 WASTE MANAGEMENT FACILITIES
Edmonton, AB
T6E 5C6
Fax: (780)-437-0281
Permit No. 00068686 00 00
For Recycle
1. rags and sorbents contaminated with hydrocarbons or glycol
2. filters contaminated with hydrocarbons, sulfinol, produced water, filter backwash
water, amines, natural gas liquids, raw and fuel, glycol and air
3. engine lube oil filters
Brokerage of:
1. Liquid hydrocarbons and glycols
2. Spent dry alkali and Ni-cd batteries
3. Spent aerosol containers
Newalta Corporation 6110 27 Street
Edmonton, AB
T6P 1J9
Phone: (780)-440-6780
Fax: (780)-468-0964
Newalta Corporation Edmonton Process Facility
Hazardous Recyclables - Hydrocarbons, Glycols, Amines
BFI
Big Valley Landfill
Class II Industrial
Waste handled / Processed at this facility:
Sulphur
Asbestos
Construction and Demolition
Non-hazardous industrial including contaminated soils and sludges (must have a
flashpoint greater than 61ºC, no free liquids, pH must be between 2.0 and 12.4)
Waste not handled/processed at this facility
Nexen Canada Ltd Waste Management Plan
Balzac Gas Plant 6.0 WASTE MANAGEMENT FACILITIES
Propane tanks, batteries, non-treated biomedical, air conditioning units, hazardous
waste, radioactive waste (>2400 cpm), putresibles, municipal solid waste, white
goods and free liquids.
Environmental Waste Management
7100 44 Street SE
Calgary, AB
T2C 2V7
Phone: (403)-720-1046
Fax: (403)-720-1050
All waste types: biohazardous, radioactive or explosive.
E.I.L. Environmental Services
16041 - 132 Avenue
Edmonton, AB
T5V 1H8
Phone: (780)-448-0866
Fax: (780)-482-5750
E.I.L. Environmental Services Onoway Facility/Transfer Station and Transportation
Network
All types of hazardous waste with the exception of explosives, radioactives,
biohazardous. All liquids, solids and sludges. Bulk waste oil, fuels, solvents and
contaminated water.
Byram Industrial Services Ltd. P.O Box 6478
5610 - 50th
Avenue
Drayton Valley, AB
T7A 1R9
Pembina Area Landfill
PAL is fully licensed to dispose of hazardous and dangerous oilfield wastes; and non-
hazardous and non-dangerous oilfield wastes that are solid wastes (as defined by the
Paint Filter Test). Examples of the material accepted into the facility are: Hydrocarbon
and/or salt contaminated soil, process sludges, drilling mud and cuttings, flare pit
reclamation material, sulphur block contaminated soils, filters incinerator ashes, service
station reclamation material, railway sidings material, process material from mining,
manufacturing or refining industries, decommissioning refuse, catalysts and desiccants,
and other solid wastes.
Nexen Canada Ltd Waste Management Plan
Balzac Gas Plant 6.0 WASTE MANAGEMENT FACILITIES
Cleanit Greenit Composting Systems Inc. 15619 - 112 Avenue
Edmonton, AB
T5M 2V8
Phone: (780)-488-7926
Fax: (780)-452-8284
Site: (780)-451-0921
Site 1, Edmonton
Waste handled/processed at this facility:
All waste accepted for processing at this site must be compostable. All waste must meet
the waste acceptance criteria. Waste can/may be tested in the mini-lab at the site. Some
hazardous recyclables can be accepted; however, they must meet the criteria for waste
acceptance and be justified as hazardous recyclable. Composted is done using the static
pile process.
WasteCo Environmental Services Ltd. P.O Box 3009
Sherwood Park
Edmonton, AB
T8A 2A6
Phone: (780)-944-0057
Fax: (780)-475-3465
CEDA Reactor Ltd.
Waste handled/processes at this facility:
Handle both regulated and non-regulated waste. All classes of regulated waste except
explosives, radioactive and biohazardous.
Sumas Environmental Services Inc.
Nisku Hazardous Waste Transfer Station
#7 - 1301 4th
Street
Nisku, AB
Phone: (780)-955-2390
Fax: (780)-955-2070
Permit #: 167-02-000
Receiver #: ABR 01097
Carrier #: ABC 02265
Generator #: ABG 05716
Waste handled/processed at this facility:
All classes of toxic, hazardous and non-hazardous wastes for treatment and transfer.
CWR Waste Management Corporation Inc
Nexen Canada Ltd Waste Management Plan
Balzac Gas Plant 6.0 WASTE MANAGEMENT FACILITIES
Box 848
Coronation, AB
T0C 1C0
Location: NE 1/4-34-36-11 W4M
EUB
Proeco Environservices Ltd 7722 9
th Street
Edmonton AB
T6P 1L6
Phone: (780)-440-1825
Fax: (780)-440-2428
Custom Environmental Services Ltd.
7722 9th
Street
Edmonton AB
T6P 1L6
Waste handled/processed at this facility:
Approval No. 95-IND-085
The operation of a hazardous waste storage and hazardous recyclable reclamation and
processing facility.
Plant storage of hazardous waste, hazardous recyclables, and dangerous oilfield waste.
The treatment of hazardous waste by commingling phase separation, solids dispersion
physical segregation and crushing for volume reduction and liquid recovery.
Processing of hazardous recyclable by commingling, phase separation, crushing for
volume reduction and liquid recovery, removal of hazardous residuals and any other
authorized process.
Recycling and processing of PCB electrical equipment.
Interstate Batteries of Northern Alberta 11404 - 156 Street
Edmonton, AB
Phone: (780)-454-4343
Waste handled/processed at this facility:
Collecting wet acid batteries for recycling.
Nexen Canada Ltd Waste Management Plan
Balzac Gas Plan 7.0 ALBERTA APPROVED LANDFILLS
ALBERTA LANDFILLS
There are a number of landfills in Alberta that may be used by waste producers
for disposition of waste streams. It is important to note that the onus is on the
waste producer to ensure proper waste classification prior to land filling a waste.
Landfills in Alberta are regulation by the EUB for Oilfield Landfills and by
Alberta Environmental Protection for regional and Industrial landfills.
Landfills have different classifications based on construction. And siting. All
landfills have classification, based on these two criteria, and the classification of a
landfill determines the waste products that may be disposed of at these sites.
AEP LANDFILL CLASSIFICATION
Class I landfills
Class I landfills may accept hazardous wastes up to a certain limit. This limit is
above the Alberta Tier I levels for heavy metals and for BTEX.
There are only two landfills with a class I designation in Alberta.
1. Safety-Kleen (Ryley) Ltd. at Ryley, Alberta
2. Chem. Security Landfill at the Swan Hills Treatment Center
Class II landfills (Industrial)
Class II landfills may only accept non-hazardous or non-DOW materials
There are a number of Class II landfills in Alberta and are all private landfills that
accept third party waste. The following landfills are Class II landfills:
1. Hazco Landfill at Peace River
2. BFI Landfill at Calgary
3. BFI Landfill at Big Valley
4. EWM Landfill at West Edmonton
5. Clover Bar Landfill at Edmonton
6. Rocky Mountain House Regional Landfill at Rocky Mountain House
The remaining landfills that are regulated by AEP are either regional, county, or
local landfills. These have a Class III designation. These types of landfills are
only able to accept inert wastes form the Upstream Oilfield Industry, such as
construction material and normal refuse. These landfills are not recommended for
use for other types of waste disposal.
Nexen Canada Ltd Waste Management Plan
Balzac Gas Plan 7.0 ALBERTA APPROVED LANDFILLS
EUB REGULATED LANDFILLS
The EUB also has different classifications of Oilfield Landfills under its
jurisdiction. The criteria for classifying its landfills are identical to AEP.
Class Ia Oilfield landfill
There are no Class Ia oilfield landfills in Alberta at this time
Class Ib Oilfield landfill
There are no class Ib oilfield landfills in Alberta at this time, however there are a
number which are in the application stage.
Class II Oilfield landfill
There are a number of Class II oilfield landfills in Alberta that accept third party
waste for disposal. They are as follows:
1. NOS Landfill at Zama
2. CCS Landfill at Slave Lake
3. Newalta Landfill at Taber
NEXEN may use landfills for proper disposal, whether a landfill is regulated by
AEP or EUB.
Nexen Canada Ltd Waste Management Plan
Balzac Gas Plan 8.0 SPILL REPORTING
ALBERTA Spill Response and Reporting
All spills, leaks, and releases of potentially harmful substances are to be reported
to a company field superintendent or member of management and a written report
will be sent to the Environmental Coordinator and filed with regulatory
authorities if required.
EUB Reportable spills
If a spill occurs with an unrefined product (crude oil or produced water) the
following guidelines should be followed:
Complete an incident report and forward to the Field Supervisor if the volume is
less than 2m³ and is contained on lease.
Contact the local AEUB Field Office if:
The volume of spilled material is >2m³ on lease; or
Any spill material escapes off-lease
The rig manager or driller is responsible for reporting spills or leaks of hazardous
or dangerous goods where the spill:
Is of a volume greater than 2m³ on lease;
Enters into any natural waterway; and/or
Escapes from the lease site
Reports must be made to the local AEUB field office immediately upon discovery
of the spill. If required, a written report will be submitted to the AEUB with the
information requested. The AEUB may require a written report with the
following information:
The name, address, etc. of the drilling company and operator;
The location of the spill;
The source and cause of the spill
The type and volume of product spills
The final distribution of recovered and unrecovered product; and
Other details as required
If a spill occurs with a refined product (diesel, varsol, chemical, lube oil, glycol,
etc.) the following guidelines should be followed:
Spills of controlled substances greater than the thresholds specified in the
Transportation of Dangerous Goods Regulations should be reported to:
the Director of Pollution Control, Alberta Department of Environment
through Industrial Incident Reporting
Nexen Canada Ltd Waste Management Plan
Balzac Gas Plan 8.0 SPILL REPORTING
Anyone directly affected by the spill (for example, other yard sites,
municipality, private landowners, etc.)
The report to the Director should include:
The location and time of the release;
A description of circumstances leading up to the spill;
Details of any action taken or planned at the release site;
The final distribution of recovered and unrecovered product; and
Reclamation plans if required
A written report must also be sent to the Director’s office within seven days of the
initial report being made. It should contain the following information;
Date and time of the spill;
Location of the spill;
Duration of the release and its release rate;
Composition of the release showing, for each substance;
Its concentration;
The total weight, quantity or amount;
A detailed description of the circumstances leading up to the release;
Steps or procedures which were taken to minimize, control or stop the
release; and
Any other information as required by the Director.
The report should be sent to:
ALBERTA ENVIRONMENT
Pollution Control Division
11th
Floor, 9820 – 106 Street
Edmonton, Alberta
T5K 2J6
Spills or leaks may not be detected until days or even weeks after the incident
occurs, however, if such a release occurs, it should be reported and active clean-
up measure implemented as soon as possible.
Nexen Canada Ltd Waste Management Plan
Balzac Gas Plan 9.0 COMPANY FACILITY CODES
Company Code 0JT3
Prov. ID Number ABG05629
Facility Name Location Facility Code
Balzac Gas Plant 10-02-26-29 W4M 2670030
Nexen Canada Ltd Waste Management Plan
Balzac Gas Plan 10.0 WASTE / ENVIRONMENTAL AUDIT REPORTS
Waste and
Environmental Audits
Nexen Canada Ltd Waste Management Plan
Balzac Gas Plan 11.0 RECYCLING
A. INTRODUCTION
This section will describe the policy for the recycling of wastes.
B. PURPOSE AND SCOPE
The implementation of a waste recycling program is designed to reduce the
volume of waste that is sent to landfills and reduce the costs of disposal.
Recyclable wastes are collected throughout the operating facility and sent off site
to recycling facilities.
Those wastes included in the recycling program are batteries, used oil, metal,
paper and cardboard and miscellaneous materials. Each type of waste is collected
and stored in a designated site and prepared for transport.
C. PROCEDURES
Each type of recyclable waste is collected by plant employees and stored in their
designated site.
1. Batteries - All Dry cell and Vehicle batteries are collected and placed on
the Environmental Waste Storage Pad located in the plant. When enough
batteries are collected they are transported by Hazco to a battery recycling
facility.
2. Used Oil - Used oil removed from the process machinery is collected in
blue double walled storage tanks that are placed throughout the plant site
(Treater, Boiler House, KVSR buildings, SVG building and Site G).
When the tanks are full the used oil is transferred to the waste oil settling
tank in flare area. Newalta is called and a manifest is completed for
transport.
3. Metal - All metal that no longer has a use is placed in an orange bin,
located at the west end of the plant, that has been designated for metal.
When this bin becomes full Calgary Metal transports the bin to their metal
recycling facility. Payment for recyclable metal is made to the generator.
4. Paper and Cardboard - Recyclable Paper and Cardboard is placed in bins
located throughout the office facilities. All paper should be collected in
plastic bags. When the individual bins are full the waste is collected in
green paper/cardboard recycling bins. The paper and cardboard is
transported by BFI to their recycling facility.
5. Miscellaneous Recyclables – Depending on quantity some materials may
be recycled i.e. glycol, solvents, varsol, diesel, etc.
BALZAC GAS PLANT
DECOMMISSIONING, REMEDIATION & LAND RECLAMATION PLAN 2012
104
Appendix III – List of Environmental Reporting Completed
for the BGP
Balzac Gas Plant
Summary of Environmental Reporting
Year Report Title
1992 Komex Report: Terrain Conductivity and Magnetometer Survey at the Petrogas Processing Plant, Balzac Alberta A92-2553-2
1993 Petrogas Report Entitled: Activity Change – Upgrade of Runoff Water Control around Sulphur Block Area – Central File 001-20
1995 Komex Report: Stable Isotope Study at the Petrogas Processing Facility KI94-2553-5
1995 Komex Report: 1995 Geophysical Program and Limited Soil Sampling Investigation – Petrogas Processing Ltd. KI95-2553-6
1996 Komex Report: 1996 Soil Monitoring Program – Balzac Gas Plant – Canadian Occidental Petroleum Ltd. KI96-2553-7-3-6
1997 Komex Report: Effects of Acid Conditions on Element Distribution Beneath a Sulphur Basepad KI96-4374
1997 Komex Report: Study of Soil, Sludge and Groundwater Conditions Around the Blowdown Ponds at the Balzac Gas Plant 2553-7-2
1997 Komex Report: Soil Quality Adjacent to the Sulphur Contaminated Soil Pile at the Balzac Gas Plant – 2553-8-2
1997 Komex Report: Hydrocarbon Burn Pit, Filter Cake Pond and Chemical Pond Remediation at the Balzac Gas Plant - KI - 2553-10-2
1997 Komex Report: Screening Level Human Health and Ecological Risk Assessment (Ponds) Wascana Energy - Balzac Gas Plant - KI 98-4683
1998 Komex Report: 1998 Integrated Soil and Groundwater Investigation Program - Wascana Energy Inc. KI-2553-9 T01/T02
1998 Komex Report: Delineation of Free Product Contamination in the LPG Recovery Area – Balzac Gas Plant KI-2553-10-5
1999Delineation of Free Product Contamination in LPG Recovery Area – 1999 , Komex Report KI-2553-10-5 dated May 9, 1999.
Conductivity probes were used in delineation of plume.
1999 Remediation Options Analysis - LPG Recovery Area , Komex Report KI-2553-11-02 (Draft) dated May 1999.
1999 Komex Report: Soil and Sludge Remediation Program of Flare Pits at Well site 2-2 C25531204
1999 Komex Report: Remediation Options Analysis LPG Recovery Area – Balzac Gas Plant KI2553-11-02 (Draft)
1999 Komex Report: Installation and 1999 Performance Review LPG Recovery Area Free Phase Recovery System C25531106
1999 Komex Report: 1998/1999 Cremona Pipeline Remediation at the Balzac Gas Plant - Komex Report C47480100
2000 Installation and 1999 Performance Review - LPG Recovery Area , Komex Report C2553‑1106 dated March 2000.
2000 Proposed Expansion of Free Product Recovery System - LPG Recovery Area , Komex Report C25531205 dated June 2000.
2000 Komex Report: Balzac Parking Lot – Underground Petroleum Storage Tank Investigation – File No. 25531208
2000
Komex Report: Balzac Gas Plant – Delineation of the Flare Area and Condensate Loading Area – File No. C25531104 Draft
Komex Report: Balzac Gas Plant – Condensate Loading Area Remediation – File No. 25531211 Draft
2000 Komex Report: Balzac Gas Plant – Underground Tank Removals – File No. C-2553-1206
2000 Komex Report: Balzac Gas Plant – Landtreatment Activities – File No. C-2553-1211
2000 Komex Report: 2000 Performance Review Phase I and Phase II Installation - LPG Recovery Area Free Phase Recovery System C25531212
2000 Komex Report: Proposed Expansion of the Free Product Recovery System LPG Recovery Area – Balzac Gas Plant C25531205
2001 2000 Performance Review Phase I and Phase II Installation - LPG Recovery Area , Komex Report C2553-1212 dated October 2001.
2001 2001 Performance Report Free Phase Recovery - LPG Recovery Area , Komex Report C2553-1303 dated July 2002.
2001 Komex Report: Balzac Gas Plant – North and South Landfill Characterization Program – File No. 25531309
Balzac Gas Plant
Summary of Environmental Reporting
Year Report Title
2001Komex Report: Balzac Gas Plant – 1998 Integrated Soil and Groundwater Investigation Program Volume 1 of 2 - File No. KI-2553-9
T01/T02 (Page 50 and Photos Section)
2001 Process Research Associates Ltd. Report: Project No. 00-05207
2001 Komex Report: Balzac Gas Plant – Land Treatment Activities – File No. C-2553-1211
2001 Komex Report: Balzac Gas Plant – Methanol Storage Tank Investigation - File No. 25531306
2001 Komex Report: Balzac Gas Plant – Inhibitor Tank Remediation – File No. 25531408
2001 Komex Report: 2001 Performance Report - Free Phase Recovery - LPG Recovery Area C25531303
2001 Komex Report: Hydrocarbon Monitoring Results Waterline Installation C25531307
2001 Komex Report: Hydrocarbon Monitoring Results Fuel Gas Line Installation C25531307
2001 Komex Report: Arsenic Detection’s in S.W. Dugout – Review and Recommendations C25531302
2001 Komex Report: 5 Year Remediation Management Plan Summary - Balzac Gas Plant - C25531300
2002 2002 Performance Report - LPG Recovery Area , Komex Report C2553-1407 dated March 19, 2003.
2002 Komex Report: Installation and 1999 Performance Review LPG Recovery Area Free Phase Recovery System C2553-1106
2002 Komex Report: 2000 Performance Review Phase I and Phase II Installation - LPG Recovery Area Free Phase Recovery System C25531212
2002Worley Parsons Komex Report: Remediation Status Report 01-08-027-27 W4M and 06-23-027-27 W4M. File No. C25532006. (In
Draft).
2002 Komex Report: Balzac Gas Plant – PCB Soil Sampling and Delineation – File No. C25531403
2003 2003 Groundwater Monitoring Report. Balzac Gas Plant. Komex International Ltd. Report No. C25531502.
2003 Balzac Gas Plant. Stormwater Management Report. Westhoff Engineering Resources Inc. July 2003
2003 Komex Report: Balzac Gas Plant – North and South Landfill Characterization Program – File No. 25531309
2003Komex Report: Balzac Gas Plant – 1998 Integrated Soil and Groundwater Investigation Program Volume 1 of 2 - File No. KI-2553-9
T01/T02 (Page 50 and Photos Section)
2003 Komex Report: Balzac Gas Plant – North Landfill Closure Report - File No. 25531505
2003Komex Report: Balzac Gas Plant – 2002 Performance Report – Free Phase Recovery System LPG Recovery Area Balzac Gas Plant – File
No. C25531407 – Draft Report
2003 Komex Report: Balzac Gas Plant – Delineation of the Flare Area and Condensate Loading Areas – File No. C25531104 – Draft Report
2003 Komex Report: 5 Year Remediation Management Plan Summary - Balzac Gas Plant - C25531501
2003/2004 2003/2004 Performance Report LPG Recovery Area , Komex Report C25531605 dated July 27, 2005
2004 2004 Groundwater Monitoring Report. Balzac Gas Plant. Komex International Ltd. Report No. C25531603.
2004 Komex Report: Balzac Gas Plant – Updated Risk Assessment – C25531301 June 2004
2004Komex Report: Balzac Gas Plant – 2003/2004 Performance Report – Lean Oil Remediation System – LPG Recovery Area – File No.
C25531605
2004 Komex Report: Updated Risk Assessment (Ponds) - Balzac Gas Plant - C25531301
2005 2005 Groundwater Monitoring Report. Balzac Gas Plant. Komex International Ltd. Report No. C25531701
2005 Komex Report: Balzac Gas Plant – 2003/2004 Soil and Groundwater Investigation in the Flare Area - File No. C25531504
2005 Komex Report: Balzac Gas Plant – 2005 Environmental Summary Update- File No. C25531700
Balzac Gas Plant
Summary of Environmental Reporting
Year Report Title
2006 2006 Groundwater Monitoring Report. Balzac Sour Gas Plant. Worley Parsons Komex Report No. C25531804. ;
2006 Decommissioning and Reclamation Plan – Sulphur Handling Facility. Worley Parsons Komex. Report No. C25531604.
2006 2006 Soils Management Plan. Worley Parsons - Report No. C25531901
20062006 Environmental Assessment for Management of Contaminated Sulphur And Materials Contaminated with Sulphur. WorleyParsons
Komex. Report No. C25531803.
2006 Worley Parsons Komex Report: Balzac Gas Plant – 2006 Industrial Runoff Assessment - File No. C25531806
2006 2006 Soil Monitoring Program. Balzac Sour Gas Plant. Worley Parsons. Report C25531803. 30 November 2006.
2006 Worley Parsons Komex Report: Balzac Gas Plant – 2006 Soil Monitoring Program - File No. C25531803
2006Worley Parsons Komex Report: Balzac Gas Plant – 2006 Environmental Assessment for the Management of Contaminated Sulphur and
Materials Contaminated with Sulphur - File No. C25531803
2006Worley Parsons Komex Report: Balzac Gas Plant – Decommissioning and Reclamation Plan Sulphur Handling Facility - File No.
C25531604
2006Worley Parsons Komex Report: Balzac Gas Plant – 2005-2008 Performance Report Lean Oil Remediation System - File No. C25532004
(Draft)
2007 2007 Groundwater Monitoring Report. Balzac Gas Plant. Worley Parsons Komex. Report No. C25531903.
2007 2007 Soil Management Activities Program at Balzac Sour Gas Plant. Worley Parsons. Report C25532002.
2007 Worley Parsons Komex Report: Balzac Gas Plant – Soil Management Plan - File No. C25531901
2007 Worley Parsons Report: Balzac Gas Plant – Sulphur Soil Pile Closure Sampling - File No. C25532001
2007 Worley Parsons Komex Report: Balzac Gas Plant – Directive 001 Site Specific Liability Assessment - File No. C25531801
2007Worley Parsons Komex Report: Balzac Gas Plant – 2005-2008 Performance Report Lean Oil Remediation System - File No. C25532004
(In Draft)
2007 Worley Parsons Report: Balzac Gas Plant – Sulphur Pit Construction - File No. 25531902 (In Draft)
2008 2008 Groundwater Monitoring Report. Balzac Gas Plant. Worley Parsons. Report No. C25532003.
2008 2008 Soil Management Activities Program at Balzac Sour Gas Plant. Worley Parsons. Report C25532105. March 27, 2009
2008 Worley Parsons Report: Balzac Gas Plant – Sulphur Soil Pile Closure Sampling - File No. C25532001
2008Worley Parsons: Sulphur Impacted Soil Stockpile Removal in Sulphur Handling Facility at Balzac Sour Gas Plant. File No. C25532007.
(In Draft)
2008Worley Parsons Komex Report: Balzac Gas Field – Pipeline Release Remediation Program at 7-15-25-28 W4M Wellsite - File No.
C50920500
2009 2009 Groundwater Monitoring Report. Balzac Gas Plant. Worley Parsons. Report No. C25532103.
2009 2009 Soil Management Activities Program at Balzac Sour Gas Plant. Worley Parsons. Report C25522109. March 30, 2010.
2009Sediment Sampling in McDonald Lake to Assess the Potential for Natural Hydrogen Sulphide Generation. Matrix Solutions Inc. January
29, 2009.
2009 Unknown Sump Excavation. 02-26-29W4M, Alberta. Worley Parsons. Report C25531802. January 30, 2009.
2009 Worley Parsons. Confirmatory Soil Sampling Summary Report C25532005. December 23, 2009.
2009 Worley Parsons Komex Report: Balzac Gas Plant – Topsoil Stockpile Removal - File No. C25532007 DRAFT
2009 Worley Parsons Komex Report: Balzac Gas Plant – Sulphur Ditch Assessment - File No. C25532106
2009 Komex Report: Balzac Gas Plant – North and South Landfill Characterization Program – File No. 25531309
Balzac Gas Plant
Summary of Environmental Reporting
Year Report Title
2009Komex Report: Balzac Gas Plant – 1998 Integrated Soil and Groundwater Investigation Program Volume 1 of 2 - File No. KI-2553-9
T01/T02
2009Worley Parsons Komex Report: Balzac Gas Plant – 2009-2010 Performance Report Lean Oil Remediation System - File No. C25532104
(Draft)
2009 Worley Parsons Report: Balzac Gas Plant – Unknown Sump Excavation Update - File No. C25531802
2009 Worley Parsons Report: Confirmatory Soil Sampling Summary, Balzac Plant Ditch Excavation – File No.C25532106, 23-March-2011.
2009Worley Parsons: Interim As-Built Drawings of Surface Water Collection Ditches Constructed During 2009 at the Balzac Gas Plant -.
Report C25532005. December 23, 2009.
2009 Worley Parsons-2009 DEA UST Removal and Replacement - Letter Report. Report C25532107. May 10, 2011. DRAFT
2009-2010 2009-2010 Performance Report Lean Oil Remediation System , Worley Parsons Report C25532104 (Draft)
2010 2010 Groundwater Monitoring Program. Balzac Sour Gas Plant. Worley Parsons. Report No. C25532202.
2010 2010 Soil Management Activities Program at Balzac Sour Gas Plant. Worley Parsons. Report C25532301. March 11, 2011
2011 Confirmatory Soil Sampling Summary Balzac Plant Ditch Excavation. WorleyParsons Report No. C25532106 – March 23, 2011.
2011 Sulphur Pit Construction. Balzac Sour Gas Plant. WorleyParsons. Report No. C25531902. Report still in Draft. May 9th, 2011
2011 Sulphur Pile Closure Sampling. Balzac Sour Gas Plant. Worley Parsons. Report No. C25532001. April 11, 2011.
2011 Topsoil Stockpile Removal Sulphur Handling Facility. Balzac Sour Gas Plant. Worley Parsons. Report C25532007. May 9th, 2011.
2011 Condensate Loading Area (CLA) Excavation, Balzac Sour Gas Plant. Worley Parsons. Report C25531211. Draft May 4th, 2011.
2011 Remediation Status Report. 01-08-027-27W4M/06-23-027W4M. Worley Parsons. Report C25532006. May 9th, 2011 (In Draft).
2011 2009 DEA UST Removal and Replacement - Letter Report. Worley Parsons. Report C25532107. May 10, 2011.
2005-2008 2005-2008 Performance Report Lean Oil Remediation System , Worley Parsons Report C25532004 (Draft)
Komex Report: Terrain Conductivity Survey at the Petrogas Processing Plant, Balzac Alberta A94-2553-6
Worley Parsons Komex Report: Balzac Gas Plant – Topsoil Stockpile Removal - File No. C25532007 DRAFT
35
APPENDIX IV – BALZAC POWER STATION MAPS
109
NE-2026-29 W4
Image Date = 14/09/2008
High Pressure Pipelines and Wells current to November 30, 2009 *** Low Pressure Pipelines current to November 1, 2005ROCKY VIEW
FIgure 3. Aerial Photo of existing Thermal Electric Power Plant & Balzac Gas Plant
N
36
APPENDIX V – PROPOSED 2012 GROUNDWATER MONITORING PROGRAM
WorleyParsons Canada4500 16th Avenue NW Calgary, AB T3B 0M6 CANADA Phone: +1 403 247 0200 Toll-Free: 1 800 668 6772 Facsimile: +1 403 247 4811 www.worleyparsons.com
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14 December 2011 Proj. No.: C25532306 File Loc.: Calgary
Nexen Inc. P.O. Box 239 Balzac, AB T0M 0E0
Attention: Todd Jorgensen-Nelson
Dear Mr. Jorgensen-Nelson:
RE: PROPOSED 2012 GROUNDWATER MONITORING PROGRAM AT BALZAC SOUR GAS PLANT
Groundwater conditions at the Balzac Sour Gas Processing Plant (Plant) have been documented in great detail through monitoring from 1992 to 2011. The main findings of the groundwater monitoring include:
generally, natural groundwater quality in the Plant area is of poor quality as indicated by high sulphate and total dissolved solids (TDS) concentrations;
groundwater flow velocities outside of the process area are low, in all three monitored groundwater zones, primarily due to low hydraulic gradients;
groundwater quality, including in zones of contamination, is relatively stable with small seasonal and annual variability; and
inorganic and organic groundwater impacts related to Plant operation identified within the process area, ponds and adjacent areas are aerially stable and have not expanded greatly over the monitoring period.
Considering the significant hydrogeological information available and the anticipated Plant decommissioning, a major revision in the forthcoming groundwater monitoring program is recommended. Proposed changes to the 2012 program include:
reduction in groundwater monitoring frequency;
reduction in the number of monitoring wells to be monitored;
reduction in analytical schedule; and
concentrating monitoring activities around the process area and perimeter “C” wells.
C25532306-CA-LTR GW 2012 Changes-Rev0.doc Page 2 of 2 14 December 2011
The proposed groundwater monitoring program would include sampling once a year in the spring, instead of spring and fall sampling, with the number of monitored wells reduced. To address operational issues during the 19 year history of groundwater monitoring, several monitoring wells were installed in relatively close proximity to each other, often duplicating and/or confirming information obtained from existing wells. These expansions to the monitoring network were required at the time of installation. However, in view of the Plant decommissioning, some monitoring wells are of lesser importance. It should be noted that during Plant decommissioning and remediation of the area, several wells installed near facilities will be removed. These monitoring wells should be properly abandoned.
Monitoring wells selected for continued monitoring should be sampled according to WorleyParsons’ preferred operating procedures. Reduction in laboratory analysis is also recommended. Testing at select monitoring locations should include:
laboratory analysis for benzene, toluene, ethylbenzene, xylenes (BTEX) and petroleum hydrocarbon (PHC) fractions F1 and F2 and amines; and
field measured parameters including depth to groundwater surface, temperature, electrical conductivity (EC) and pH. If significant changes in EC and/or pH are measured as compared to historical field measurements, a sample should be submitted for routine potability analysis for the well in question. Otherwise, laboratory testing for main ions and dissolved metals should be discontinued.
Based on the information noted above, a recommended analytical schedule is provided on Table 1.
It is WorleyParsons recommendation that Nexen submits proposed changes to the groundwater program to Alberta Environment (AENV) for approval. We trust that the proposed changes meet AENV requirements as well as Nexen’s long-term commitment to environmental protection.
Regards,
Steve Hardy, B.A.Sc., P. Eng. Dr. Tad Dabrowski, P.Eng. Staff Environmental Engineer Technical Director, Hydrogeology
Prairie Business Unit Infrastructure & Environment WorleyParsons Canada Services Ltd.
Table 1 2012 Schedule of Analyses
PROJECT NO.: C25532306
Monitoring Station
Fiel
d Pa
ram
eter
s
BTE
X/F1
ATF
1F2
Am
ine
GPW
WR
2
92-3A X92-3B X92-4A X92-8A X X X92-8B X X X98-8C X X X92-11A X92-11B X92-12A X92-12B X92-13A X92-14A X93-15A X93-15C X X94-17C X X94-18C X X94-19C X X96-22A X98-24A X X98-24B X X98-24C X X98-26A X98-26C X X98-28C X01-33A X01-34A X X03-37A X03-38A X X04-42A X06-44A X06-45A XMW-1A XMW-4A XMW-8A XMW-9A XMW-9B XMW-10A X
SW Dugout X XMcDonald Lake X X X X
Dup I = Trip Blank XDup II = X
TOTALS 42 15 3 5 5
NOTES: - GPWWR2 (non rush)- consists of Ammonia-N, COD, Cl, pH, Sheen, TSS, SO4
- ATF1F2 includes BTEX, F1 and F2- Field Parameters include depth to groundwater surface, temperature, pH and electrical conductance
- Amines can be submitted from routine bottle
Open Drain Collection Pond (Water from Tile Drain)
X
X
Duplicates
X
Open Drain Collection Pond (Water between Liners)
X
XX
Spring 2012
Groundwater-Bearing Zone
XOpen Drain Collection Pond (Surface Water) X
Surface WaterX
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