Delineation History
description
Transcript of Delineation History
-
Hangingstone Project Update for AER October 2012 to September 2013
Presented 2013-11-05
-
Hangingstone Project - Introduction
Project Background
Subsurface
Facilities
Compliance
Future Plans
2
-
Project Background
-
AOC Hangingstone Lands outlined ( ) acquired and delineated between July 2006 and February 2010
Lands outlined ( ) acquired in October 2010 and delineated by March 2011 as Hangingstone Project 1 application submitted March 2011
Initial development area selected for its proximity to Infrastructure and to act as a central development node for the overall Hangingstone Asset.
Lands outlined ( ) acquired in October 2011 and delineated over the following two winters formulating the initial development for Hangingstone Expansion submitted in March of 2013
Asset Statistics & Development Overview 117 MMbbl reserves; 912 MMbbl contingent resource
Asset planned to be developed in three phases:
Hangingstone Project - Acquisition and Delineation History
Hangingstone Regional Development Map
Sales pipeline
Fuel Gas
Fort McMurray
Enbridge Cheecham
(1) Contingent resource best estimate
CPF
Project 1 - 12,000 bbl/d (approved & in construction)
Project 2 - 40,000 bbl/d (current EIA application)
Project 3 - 30,000 bbl/d (current EIA application)
4
-
5
Objective
Construct, operate and reclaim a bitumen recovery scheme using SAGD technology to produce bitumen up to a rate of 12,000 bpd.
Scope
20 km from Fort McMurray.
5 production pads.
25 horizontal well pairs.
CPF and associated facilities.
Offsite services and utilities.
Infrastructure:
Fuel Gas from TCPL.
Dilbit export to Enbridge Cheecham Terminal.
Diluent commercial negotiations ongoing.
Hangingstone Project - Background
-
Hangingstone Project Surface and Subsurface Layout
6
-
Hangingstone Project Scheme Map
7
-
Subsurface
-
Subsurface Data Overview
Stratigraphy and Reference Well from HS1
Depositional Environment of the McMurray Formation
McMurray Net Pay Map
McMurray Pay Structure and Fluid Isopach Maps
Caprock Geomechanics
Drilling and Completion
Scheme Performance
Hangingstone Project - Subsurface Section Outline
-
10
Hangingstone Project - Subsurface Data - Overview Vertical Wells Hangingstone Lease
Area (Km2)
MCMR Cored Wells
Image Logs
Caprock Core
Development Area 5.1 26 30 1
Project Area 5.6 26 30 1
-
11
Hangingstone Project - Subsurface Data - Overview Seismic
3D acquired in 2011 and 2012, merged in 2012.
Total Proprietary 2D ~ 450 km.
Total 3D Area ~98 km2 (Merged).
Covers Development Area.
3D Parameters:
Source Line/Source Spacing: 60 m/ 20m.
Receiver Line/Receiver Spacing: 60(40) m/20m.
2011 Hangingstone River 3D 2011 Hangingstone River North 3D 2012 Halfway Creek 3D 2012 Highway 3D Proprietary 2D
-
Hangingstone Project - Stratigraphy and Reference Well 1AA/03-31-086-09W4/00
12
Middle McMurray Target Reservoir
-
Depositional Model
Breccia
Sand
SIHS, MIHS
Mud
Middle McMurray Deposits Formed dominantly in a mixed tide and wave dominated estuary system.
Reservoir is composed of amalgamated point bar deposits dominated by fine-medium grained, channel sand. Mud clast breccia is commonly found near the base of the reservoir. The reservoir fines upwards into interbedded sand and mud (sandy and muddy IHS). Thin mud layers are typical towards the top of the reservoir.
Mudstone
Modern Analog Estuarine Environment (Digul River Estuary, Papua New Guinea)
Outer
MIHS SIHS (IHS) Breccia Channel Sand (CS)
Fining Upward
Digul River
Fly River
Hangingstone Project - Subsurface Depositional Environment of Middle McMurray
Reference Well
CS
IHS
CS
Breccia
Mud
CS
Wabiskaw
McMurray
Top Pay
Base Pay
Paleozoic
13
-
14
Hangingstone Project - Subsurface Definition of Net Pay and Map
Wabiskaw
McMurray
Top Pay
Base Pay
Paleozoic
Middle McMurray Gross Pay definition:
GR < 70 API Density > 27% Resistivity >18 ohm Water Saturation < 50% Includes less than 1 m thick mud. Net Pay thickness typically excludes mud.
So
-
15
A
Hangingstone Project - Subsurface Structural Cross Section NW-SE Across HS1 Area
A
A
Gross 36m Net 26m
Gross 36m Net 31m
Gross 38m Net 22m
Gross 43m Net 38m Gross 44m
Net 39m
Gross 36m Net 21m
A
A A
Wabiskaw
McMurray
Top Pay
Base Pay Paleozoic
-
16
B
Hangingstone Project - Subsurface Structural Cross Section W-E Across HS1 Area
B
B B
Gross 42m Net 32m
Gross 36m Net 31m
Gross 38m Net 30m
Gross 43m Net 38m
Gross 36m Net 27m
B B
Wabiskaw
McMurray
Top Pay
Base Pay Paleozoic
-
17
Range of elevation from 260 to 295 masl, highest over drainage pads.
Hangingstone Project - Subsurface Structure Map of Top of Bitumen Pay
Wabiskaw
McMurray
Top Pay
Base Pay
Paleozoic
So
-
18
Hangingstone Project - Subsurface Structure Map of Base of Bitumen Pay
Range of elevation from 245 to 260 masl, low over drainage pads.
Wabiskaw
McMurray
Top Pay
Base Pay
Paleozoic
So
-
19
Hangingstone Project - Subsurface Isopach Middle McMurray Gas Map
Middle McMurray gas has minimal thickness and limited distribution within the Development Area.
Wabiskaw
McMurray
Top Pay
Base Pay Paleozoic
M. MCR Gas M. McMurray
So
-
20
Hangingstone Project - Subsurface Isopach Middle McMurray Bottom Water
Interbedded mud and water saturated sand
Wabiskaw
McMurray
Top Pay
Base Pay
Paleozoic
Basal Mud
M. McMurray
The permeability measured from core within the muddy interval between the bottom water and the bitumen reservoir through interval 193.80 to 193.85 m MD is 4.30 millidarcy (kV) and 71.0 millidarcy (kMax). Denoted on photo by
Basal Water Zone
-
21
Hangingstone Project - Subsurface OBIP and Reservoir Properties
Avg Porosity Avg So OBIP
(Vol Frac) (Vol Frac) (mln m)
Drainage Areas 0.35 0.75 13.0
Development Area 0.35 0.75 14.2
Project Area 0.35 0.75 14.3
Depth Typical Producer
Pres Initial @ 190mTVD
Tres Initial Reservoir Kh, avg
Reservoir Kv, avg
Bitumen Viscosity @ Tres Initial
(m TVD/masl) (kPaa) (C) (mD) (mD) (cP)
190/255 600 10 4,000 3,200 >1 mln
-
22
Hangingstone Project - Subsurface Caprock Description Core and Image Data
Caprock Core 1AA\10-30-86-9W4\00
Caprock is defined as the unit between the top of the Clearwater Formation and Wabiskaw.
Two main units within the caprock; lower argillaceous and upper silty mud.
Primary caprock is the lower argillaceous unit which ranges from the top of the Clearwater Argillaceous to the top of Wabiskaw.
Composed primarily of shales and siltstones
Prim
ary
Cap
rock
-
23
Hangingstone Project - Subsurface Caprock Description Seismic Analysis
Devonian Wabiskaw Clearwater
Variance attribute time slices through formations.
Seismic and image log analysis indicates laterally continuous competent caprock unit across the area.
1AA\
10-3
0
100\
04-3
1
102\
04-3
1
A A A
A A A
A A
Devonian
Wabiskaw
Clearwater Arg
Clearwater
-
Mini-Frac test performed February 2011 on 1AA/10-30-086-09 W4/00. Approval for 2,200 kPaa during circulation. Approval for 2,000 kPaa during SAGD mode.
Safety factor of 33% with respect to base of the Clearwater shale. Safety factor of 13% with respect to top of pay interval of the middle McMurray bitumen sands.
Mini-Hydraulic Fracture Test Summary, Gauge Pressures (1AA/10-30-086-09 W4/00)
24
Hangingstone Project - Subsurface Caprock Geomechanics Mini-Frac
Mini-Frac test depths
Interval Depth Fracture Gradient Fracture Pressure Operating Pressure Safety FactorMinimum Mini-Frac Test, Smin Minimum (MFP) Maximum (MOP) Minimum
Shale (m TVD) (kPag/m) (kPaa) (kPaa) (1 - MOP/MFP)CLWT Shale Base 136 21.20 2,983 2,000 33%
Top Middle MCM Pay 155 14.17 2,296 2,000 13%
-
11 tri-axial tests performed. 7 at room temperature (RT). 4 at high temperature (75 to 175 oC). XRD done on all samples.
Tri-axial tests showed thermally induced mechanical hardening.
Beneficial to SAGD operations. Geomechanical model created using only RT tri-axial data. Model supported safe operating pressure with respect to caprock integrity.
25
Hangingstone Project - Subsurface Caprock Geomechanics Tri-Axial Testing & Model
Tri-axial lab samples
Caprock Core 1AA\10-30-86-9W4\00
Prim
ary
Cap
rock
-
26
100 m interwell spacing
650 to 850 m slotted lateral section
~350 m (~450 mMD) displacement
to ICP
AA P1 to AA I5
Example, Pad AA
ICP 75 m
Tangent
Build
Slotted Liner
Lateral
Well pairs are numbered 1 to 5 from left-to-right, when facing down the well pairs trajectory.
Hangingstone Project - Subsurface HS1 Planned Well Layout
Injectors target
5 mTVD above
producers along
horizontal lateral
Delineation Wells Observation Wells
-
27
Hangingstone Project - Subsurface Typical SAGD Wellbore Schematic
Mechanical lift required to bring fluids to surface.
WHP of ~2000 kPaa (downhole MOP 2,000 kPaa). Gas lift cannot bring fluids to surface.
All-metal PCPs will be run in the 25 producers, with the option to trial ESPs at a future date.
Injector long string is a continuous pipe size (application showed a swedge in lateral heel).
-
28
Downhole Instrumentation
SS SS SS SS
Producer Only: Fiber (40 to 60pt temp FBG or DTS)
with 1 or 2 pressure sensors
SS: 4 injectors with Steam Splitters
Hangingstone Project - Subsurface Planned Instrumentation in SAGD Wells
Producer and Injector: Fiber (40 to 60pt temp FBG or DTS)
with 1 or 2 pressure sensors
Injectors will have continuous real-time monitoring at surface of casing (blanket) gas pressure to determine downhole heel pressure during SAGD phases.
Select injectors will also have downhole instrumentation and/or adjacent observation wells to monitor injection temperature and pressure.
Producers will have downhole temperature and pressure instrumentation.
Producers will also have casing gas pressure monitored during all SAGD phases.
-
29
15 observation (obs) wells in total.
15 observation wells will have thermocouples (TCs).
10 observation wells will have piezometers (piezo).
5 obs wells will have TCs in the upper McMurray, Wabiskaw, and Clearwater for proactive caprock monitoring.
102/03-31-086-09W4 also has piezos in these zones.
100/07-31-086-09W4 will have TCs in isolated bottom water.
100/11-30-086-09W4 has a piezo in isolated bottom water.
Typical Observation Well Completion
Hangingstone Project - Subsurface Planned Instrumentation in Observation Wells
-
30
AA AB
AC
AD
AE
5 Obs wells with 10 to 20 TCs
10 Obs well with 10 to 20 TCs and 3-6 piezometers (installed)
10 Vertical delineation well
Obs well also monitoring above pay (U MCM, Wab, and CLW caprock) Obs well also monitoring below pay (basal zone)
14 observation wells within drainage areas and 1 observation well adjacent to drainage area AC
Planned TC Sensor Interval
Piezometer
Planned Producer Placement
Hangingstone Project - Subsurface Planned Instrumentation in Observation Wells
AOC Hangingstone 100/03-31-086-09W4/0
-
Hangingstone Project - Subsurface Hangingstone Project Drilling Status
Hangingstone Project Drilling Program
Consists of 2 SAGD slant drilling rigs.
Drilling commenced August 4th, 2013.
Pad Drilling Order:
Rig 1 AA, AC, AE.
Rig 2 AD and AB.
As of September 30th, 2013:
Pad AA: Drilled 10 surface holes, 5 producer intermediates and 3 producer laterals with set liner.
Pad AD: Drilled 10 surface holes and 3 producer intermediates.
AA
AE
AD
AC
AB
Red Line indicates Laterals Drilled with liner set
31
-
A
A
A A
Actual Well Path
32
Total lateral length 846 mMD.
ICP Depth: 479 mMD and Total Depth 1,325 mMD.
Flat across the lateral section.
Well is placed low in reservoir in clean bitumen rich sand with 100% reservoir along wellbore.
Hangingstone Project Pad AA Pair 1 - Results
-
B
B
B B
Actual Well Path
33
Total lateral length 850 mMD.
ICP Depth: 454 mMD and Total Depth 1,304 mMD.
Flat across the lateral section.
Well is placed low in reservoir in clean bitumen rich sand with 85% reservoir along wellbore.
Hangingstone Project Pad AA Pair 2 - Results
-
D
D
Total lateral length 851.5 mMD.
ICP Depth: 454.5 mMD and Total Depth 1,306 mMD.
Gradual rise across lateral section.
Well is placed low in reservoir in clean bitumen rich sand with 95% reservoir along wellbore.
Actual Well Path
34
Hangingstone Project Pad AA Pair 4 - Results
-
35
Production History:
No production history.
First steam anticipated end Q4 2014.
Hangingstone Project - Subsurface Scheme Performance History
-
36
Pad Well Pairs Well Pair Length
OBIP Predicted RF
RBIP
(m) (mln m3) (%) (mln m3)
AA 5 850 2.79 50 1.39
AB 5 650 1.87 50 0.94
AC 5 750 2.70 50 1.35
AD 5 750 2.78 50 1.39
AE 5 850 2.90 50 1.45
TOTAL 25 13.0 50 6.52
Hangingstone Project - Subsurface Scheme Performance Pad Recoveries
-
37
Hangingstone Project - Subsurface Surface Heave Monitoring
AOC plans on monitoring surface heave.
Method and frequency are still being determined.
-
38
AOC plans on monitoring steam growth and conformance using 4D seismic.
Geophones will be buried over the five drainage areas to accommodate year round shooting.
4D baseline survey planned to be acquired in 2014.
3.72 km2 total area.
Hangingstone Project - Subsurface Planned 4D Seismic
-
Surface Operations
-
40
Hangingstone Project - Approved Plot Plan From D078 Amendment Application 1757038
Modifications from D078 Amendment Application: Location and footprint of admin and control buildings, communications tower finalized
-
41
Hangingstone Project - Facility Schematic
SEPARATOR TREATER
BFW
BFW GLYCOL
GLYCOL
EMULSION
FROM PRODUCTION PADS
DILUENT TANK
DILUENT
TRUCK IN
DILBIT TANKS (x2)
SALES OIL
TRUCK OUT
VAPOUR RECOVERYUNIT
TANK VAPOURS
VRU
VRU
EDUCTED VAPOURS
FROM PRODUCTION PADS
PG SEPARATOR
TO STEAM GENERATORS
GLYCOL
FUEL GAS
FROM SUPPLY PIPELINE
MIXED GASSEPARATOR
FUEL GAS
TO PRODUCTION PADS
UTILITYUSERS
PRODUCED GAS
DILUENTRECOV. SEP.
GLYCOL
TO DIRTY WATER
HEADER
TO SLOP OIL TANK
TO DIRTY WATER
HEADER
SKIM TANK
INDUCEDSTATIC
FLOTATIONPACKAGE
INTERMITTENT SOLIDSCONTAINING STREAMS
DESAND / DIRTY WATER SYSTEM
VRU
VRU
VRU
SOLIDS TRUCKED OUT
SERVICE WATER TANK
NON-SALINE WATER
FROM NON-SALINEWATER WELLS
DIRTY WATER HEADER
TO NON-SALINEWATER USERS
VRU
VRU LIQUIDS
SLOP OIL
PW TANK
VRU
SLOP OIL TANK
VRU
EVAPORATOR / CONCENTRATOR PACKAGES (x2)
EDUCTORS
WASTE WATER TANKS (x2)
TRUCK OUT
EDUCTORS
BFW TANK
HEAT EXCHANGE
HP STEAM
TO PRODUCTION PADS
HP STEAM GENERATORPACKAGES (x2)
INT. BLOWDOWN
VENT
E-18
BLOWDOWNTO DIRTY WATER
HEADER
MIXED GAS
GLYCOL
SLOP OILTREATING
PKG
TO DILBITTANKS
TO DESAND/DIRTY WATER SYSTEM
TO SEPARATOR
-
Hangingstone Project - Facility Performance
The facility is not yet in operation. As designed:
Material Rates:
Bitumen: 1,908 m3/d.
Steam: 6,677 m3/d.
Produced Water: 6,243 m3/d.
Diluent: 616 m3/d.
Greenhouse Gas Emissions:
CO2E: 0.565 Mt/y (site-generated).
Values are annual averages.
Solution gas is recovered and used as fuel in the steam generators.
42
Gas Usage:
Purchased: 475 103 m3/d.
Produced Gas: 7.12 103 m3/d.
Flared: 0.39 103 m3/d (purge gas).
Vented: 0.12 103 m3/d (truck loading).
Expected Power Consumption:
8.6 MW operating load.
6,278 MWh monthly import.
-
43
Measurement, Accounting and Reporting Plan (MARP) approval received on October 5, 2012.
MARP updated on February 11, 2013 to capture Directive 078 amendment application design changes and to align the MARP with the requirements of Directive 081.
Next MARP update to the AER on or before February 28, 2014 as per Approval.
Hangingstone Project - Measurement and Reporting
-
44
PRODUCTION BATTERYAB BT # # # # # # # # (344)19/ 30-86-09 W4M
TCPLAB MS # # # # # # #
DILUENT SOURCE
PIPELINE TERMINALAB TM # # # # # # #XXXXXXXX W4M
INJECTION FACILITYAB IF # # # # # # # # (506)19/ 30-86-09 W4M
INJECTION FACILITYAB IF # # # # # # # # (506)19/ 30-86-09 W4M
HANGINGSTONE PROJECTMARP METERING SCHEMATIC
Pr oduct ion Bat t er y(Pg 1 of 3)
REV.2
EMULSION
FROM WELL PADS
RECOVERABLE UTILITY FSHWTR
RECOVERABLE STEAM/ WATER
01-T1300SKIM TANK[WATER]
DIRT
Y W
ATER
HEAD
ER
BITUMEN BUILDING SUMP
SAND SLURRY HEADER
WATERTRUCK OUT
SKIM
TAN
KHE
ADER01-T1520
DECANT TANK[WATER]
LI15200A
01-T1700SLOP OIL TANK
[OIL]
LI17000K
01-VZ1330ISF VESSEL
01-T1400PRODUCED
WATER TANK[WATER]
LI14000A
SECONDARY
DESAND FLUSH WATERTO SEPARATOR/TREATER
01-V1050SEPARATOR
01-V1100TREATER 04-T1300
DILBIT TANK[OIL]
LI13000K
04-T1310DILBIT TANK
[OIL]
LI13100K
TRUCK IN
04-T1000DILUENT TANK
[COND]
LI10000A
01-V1220DILUENT RECOVERY
SEPARATOR
01-V1700MIXEDGAS
SEPAR-ATOR
PRODUCED GAS
FROM WELL PADS
00-V1520PRODUCED GAS
SEPARATOR
TO DIRTY WATERHEADER
TO DIRTY WATERHEADER
PURCHASED GAS
FROM TCPL
BLANKET/ BUBBLE GAS
TO WELL PADS
01-Z5040/ 5050VRU
COMPRESSORPACKAGES
BLANKET GASRETURNS
BLANKET GAS TO TANKSAND ISF VESSEL
UTILITY FUEL GAS HEADER
CRITICAL FUEL GAS HEADER
00-Z3300GLYCOL HEATER
PACKAGE
GLYCOL EXPANSION DRUM BLANKET
01-V5500HP FKOD
HP FLARE HEADER
HP FKODPURGE
TO SLOP OIL HEADER
FLARE PILOT
05-SF1000HP FLARE
STACKNC
NO
SECONDARY
MP FUEL GAS HEADER
SEPARATOR, TREATER, PG SEPARATOR, DILUENT RECOVERY SEPARATOR BLANKET GAS
MAK
EUP
FUEL
GAS
SAND TOSAND SLURRY HEADER
OFFSPEC
PW TRANSFERPUMPS
WATERTRUCK OUT
NC
SLOP
OIL
HE
ADER
RAG LAYERS TOSLOP OIL HEADER
NC
SP
SP
PRODUCTION BATTERYSERVICE WATER
TO PUMP SEAL FLUSHESTO BITUMEN BUILDING SUMP
TRUCKTICKETS
UNIT 00 FLARE HEADER PURGE
UNIT 01 FLARE HEADER PURGE
GLYCOL EXPANSIONDRUM BLANKET RETURN
VRU
VRU
VRU
VRU
VRUVRU
VRU
RELIEVE TO HP FLARE
RELIEVE TO HP FLARE
VRU
RELIEVE TO HP FLARE
RELIEVE TO HP FLARE
REV. DESCRIPTION DATE BY0 IFA SW1 RE-IFA2
28/ 03/ 1205/ 06/ 12 SW
2 RE-IFA 01/ 02/ 13 SW
FLOW & DENSITY
OILTRUCKOUT
EST.
UNIT 01 FLARE SUBHEADER PURGE
FROM PSVs (NNF)
FE16106
FE00010
FE00030
FE16101
FE55005
FE55002
FE14001
M
FE1410214152
M
FE10005
FRESH WATER
INJECTION FACILITYUTILITY FSHWATER
FE00020
M
FE30102B
M
PRIMARY
PRIMARY
FE63007
PRODUCED WATER
TO EVAPORATOR PACKAGE
TO EXCESS TRUCK OUT
VENT CONDENSEREDUCTOR
EDUCTOR MOTIVE GAS
PRODUCED GASESFROM EVAPORATORS AND WW TRUCKOUT
TANKSMIXED FUEL GAS
TO STEAM GENERATORS
TO STEAM GENERATORS
FEA0201
TCPLMETER
INJECTION FACILITYAB IF # # # # # # # # (506)19/ 30-86-09 W4M
FEA0370
V
FEB0370
V
ESTIMATE
ESTIMATE FROM
FE-21033
TRUCK OUT
TRUCKTICKETS
TRUCKTICKETS
TRUCKTICKETS
NC
DILUENT
SALES OIL
DILUENT
STREAMS
GASSTEAMBITUMENWATER
VORTEX METER
V
M
ULTRASONIC METER
CORIOLIS METER
MAGNETIC METER
V-CONE METER
METER TYPES
TAGS
EQUIPMENT TAGS PRECEDED BY HCP-INSTRUMENT TAGS PRECEDED BY HCP-XX- WHERE XX IS THE UNIT IDENTIFIER
ABBREVIATIONSAE ANALYZER CBD CONTINUOUS BLOWDOWNFE FLOW ELEMENT (ACCOUNTING METER)H20 WATER CUTIBD INTERMITTENT BLOWDOWNLI LEVEL METER (RADAR TYPE)NC NORMALLY CLOSEDNNF NORMALLY NO FLOWNO NORMALLY OPENSP SAMPLE POINT
LEGEND
WELL TYPES
WATER SOURCE WELL
STEAM INJECTION WELL
OIL WELL
FEXXXXX
FEXXXXX
PETRINEX ACCOUNTINGMETER
METER NOT REPORTINGTO PETRINEX
DILUENTPUMPS
OFFSPECPUMPS
DESANDPUMP
ISF SKIM OILPUMPS
ISF DISCHARGEPUMPS
DECANT RECYCLE
PUMPS
SAND QUENCH
MAKEUP
SLOP OILPUMPS
RECOVERED DILUENT TRANSFER PUMPS
HP FKODPUMP
01-Z1800SLOP OIL TREATING PACKAGERECYCLE
NC
Hangingstone Project - Measurement Schematics Battery
-
45
HANGINGSTONE PROJECTMARP METERING SCHEMATIC
Inj ect ion Facil it y(Pg 2 of 3)
REV.2
04-T3000WATER TANK
[FSHWTR]
LI30000A
RECOVERABLE SERVICE WATERif pump seal f l ushes
FSHWTRPLTUSE
MIXED FUEL GAS
PRODUCED WATER02-Z1100/ 1300EVAPORATOR
PACKAGES03-T1000
BFWTANK
[WATER]
LI10000A
02-T6300WW TRUCKOUT
TANK[WATER]
02-T6310WW TRUCKOUT
TANK[WATER]
HP STEAM
HP STEAMLETDOWN
03-V1500INTER-
MITTENTBD
VESSEL
IBD VENT
SECONDARY
PRIMARY
SECONDARY
PRIMARY
BLOW
DOW
N
EXCESS PW
FRESH WATER
PRIMARY
CBD
CBD
INJECTION FACILITYAB IF # # # # # # # # (506)19/ 30-86-09 W4M
NNFPRIMARY
TRUCKTICKETS
LI63000
LI63100
RECOVERABLE STEAM/ WATERt o dir t y wat er header via sumps
IBD
03-Z2100HP STEAM
GENERATORPACKAGE
03-Z2200HP STEAM
GENERATORPACKAGE
FROM PW TRANSFER PUMPS
EDUCTOR
EDUCTOR
REV. DESCRIPTION DATE BY0 IFA SW1 RE-IFA2
28/ 03/ 1205/ 06/ 12 SW
2 RE-IFA 01/ 02/ 13 SW
VRU
WATER UTILevapor at ive l osses
NITROGEN
BLANKET GAS
NC
NC
IBD
NO
NO
PRIMARY
PRIMARY
FE21033
FEA0201
FE63007
FEB3040
FEA3040
FEA3530
FEB3530
FE00020
M
WAFE1010
M
WBFE1010
M
WCFE1010
M
FE30001
M
FE30102B
M
FEA0370
V
FEA4310
V
FEB4310
V
ESRD-LICENSED WATER SOURCEAB WS # # # # # # # # (901)ESRD LICENCE 00316166-00-00
PRODUCTION BATTERYAB BT # # # # # # # # (344)19/ 30-86-09 W4M
FEB0370
V
AB WI # # # # # # # # # # # #15-33-085-W4SOURCE WATER WELLFSHWTR
AB WI # # # # # # # # # # # #06-12-086-09-W4SOURCE WATER WELLFSHWTR
AB WI # # # # # # # # # # # #04-08-086-08-W4SOURCE WATER WELLFSHWTR
EDUCTOR
TO WELL PADS
ESTIMATE
PRODUCTION BATTERYAB BT # # # # # # # # (344)19/ 30-86-09 W4M
WASTE FACILITYAB WP # # # # # # # # (# # # )19/ 30-86-09 W4M
ESTIMATE
ESTIMATE
FSHWTR UTILevapor at ive l osses
ESTIMATE
ESTIMATE
RECOVERABLE UTILITY FSHWTRt o dir t y wat er header via sumps
ESTIMATE
ESTIMATE
ESTIMATE
LP STEAM LOSS
IBD
NC
TRUCK OUT
WASTE WATER
DILUENT
STREAMS
GASSTEAMBITUMENWATER
VORTEX METER
V
M
ULTRASONIC METER
CORIOLIS METER
MAGNETIC METER
V-CONE METER
METER TYPES
TAGS
EQUIPMENT TAGS PRECEDED BY HCP-INSTRUMENT TAGS PRECEDED BY HCP-XX- WHERE XX IS THE UNIT IDENTIFIER
ABBREVIATIONSAE ANALYZER CBD CONTINUOUS BLOWDOWNFE FLOW ELEMENT (ACCOUNTING METER)H20 WATER CUTIBD INTERMITTENT BLOWDOWNLI LEVEL METER (RADAR TYPE)NC NORMALLY CLOSEDNNF NORMALLY NO FLOWNO NORMALLY OPENSP SAMPLE POINT
LEGEND
WELL TYPES
WATER SOURCE WELL
STEAM INJECTION WELL
OIL WELL
FEXXXXX
FEXXXXX
PETRINEX ACCOUNTINGMETER
METER NOT REPORTINGTO PETRINEX
BFW PUMPS
WATER PUMPS
NITROGEN SOURCE
Hangingstone Project - Measurement Schematics Injection Facility
-
46
HP STEAM
FEAA111
FEAA121
FEAA211
FEAA221
FEAA311
FEAA321
FEAA411
FEAA421
FEAA511
FEAA521
AA01IINJECTION WELLSTEAM
AA02IINJECTION WELLSTEAM
AA03IINJECTION WELLSTEAM
AA04IINJECTION WELLSTEAM
AA05IINJECTION WELLSTEAM
AA01PPRODUCTION WELLEMULSIONPUMP JACK (ELECTRIC)
AA05PPRODUCTION WELLEMULSIONPUMP JACK (ELECTRIC)
AA02PPRODUCTION WELLEMULSIONPUMP JACK (ELECTRIC)
AA03PPRODUCTION WELLEMULSIONPUMP JACK (ELECTRIC)
AA04PPRODUCTION WELLEMULSIONPUMP JACK (ELECTRIC)
TESTSEPAR-ATOR
AA-V3000
AE30002
SP30002
NNF
AA-T3010POP TANK
VENT(ESTIMATE)
HANGINGSTONE PROJECTMARP METERING SCHEMATIC
Wel l Pads(Pg 3 of 3)
REV.2
REV. DESCRIPTION DATE BY0 IFA SW1 RE-IFA2
28/ 03/ 1205/ 06/ 12 SW
2 RE-IFA 01/ 02/ 13 SW
GROUP
TEST
PRODUCED GAS
EMULSION
TYPICAL WELL PAD AA
AA01I 105/04-31-086-09W4/0 AB01I 106/03-31-086-09W4/0 AC01I 103/16-30-086-09W4/0 AD01I 100/02-30-086-09W4/0 AE01I 116/03-31-086-09W4/0
AA02I
AA03I
AA04I
AA05I
AA01P
AA02P
AA03P
AA04P
AA05P
106/04-31-086-09W4/0 AB02I 107/03-31-086-09W4/0 AC02I 100/16-30-086-09W4/0 AD02I 108/02-31-086-09W4/0 AE02I 114/04-31-086-09W4/0
107/04-31-086-09W4/0 AB03I 108/03-31-086-09W4/0 AC03I 102/16-30-086-09W4/0 AD03I 118/03-31-086-09W4/0 AE03I 113/04-31-086-09W4/0
108/04-31-086-09W4/0 AB04I 103/02-31-086-09W4/0 AC04I 102/15-30-086-09W4/0 AD04I 117/03-31-086-09W4/0 AE04I 112/04-31-086-09W4/0
103/03-31-086-09W4/0 AB05I 104/02-31-086-09W4/0 AC05I 100/15-30-086-09W4/0 AD05I 105/03-31-086-09W4/0 AE05I 104/04-31-086-09W4/0
103/04-31-086-09W4/0 AB01P 109/03-31-086-09W4/0 AC01P 106/16-30-086-09W4/0 AD01P 102/02-31-086-09W4/0 AE01P 104/03-31-086-09W4/0
109/04-31-086-09W4/0 AB02P 110/03-31-086-09W4/0 AC02P 105/16-30-086-09W4/0 AD02P 107/02-31-086-09W4/0 AE02P 117/04-31-086-09W4/0
110/04-31-086-09W4/0 AB03P 111/03-31-086-09W4/0 AC03P 104/16-30-086-09W4/0 AD03P 115/03-31-086-09W4/0 AE03P 118/04-31-086-09W4/0
111/04-31-086-09W4/0 AB04P 105/02-31-086-09W4/0 AC04P 104/15-30-086-09W4/0 AD04P 114/03-31-086-09W4/0 AE04P 116/04-31-086-09W4/0
112/03-31-086-09W4/0 AB05P 106/02-31-086-09W4/0 AC05P 103/15-30-086-09W4/0 AD05P 113/03-31-086-09W4/0 AE05P 115/04-31-086-09W4/0
AOC WELL NAMES AND UNIQUE IDs
BUBBLE GAS
BUBBLE GAS
BUBBLE GAS
BUBBLE GAS
BUBBLE GAS
TO CPF
INJECTION FACILITYAB IF # # # # # # # # (506)19/ 30-86-09 W4M
PRODUCTION BATTERYAB BT # # # # # # # # (344)19/ 30-86-09 W4M
BLANKET/ BUBBLE GAS
FROM CPF
FROM CPF
FE30002
FE00010
H20
FE30006
DILUENT
STREAMS
GASSTEAMBITUMENWATER
VORTEX METER
V
M
ULTRASONIC METER
CORIOLIS METER
MAGNETIC METER
V-CONE METER
METER TYPES
TAGS
EQUIPMENT TAGS PRECEDED BY HAF-INSTRUMENT TAGS PRECEDED BY HAF-AA- WHERE AA IS THE WELL PAD IDENTIFIER (TYPICAL)
ABBREVIATIONSAE ANALYZER CBD CONTINUOUS BLOWDOWNFE FLOW ELEMENT (ACCOUNTING METER)H20 WATER CUTIBD INTERMITTENT BLOWDOWNLI LEVEL METER (RADAR TYPE)NC NORMALLY CLOSEDNNF NORMALLY NO FLOWNO NORMALLY OPENSP SAMPLE POINT
LEGEND
WELL TYPES
WATER SOURCE WELL
STEAM INJECTION WELL
OIL WELL
FEXXXXX
FEXXXXX
PETRINEX ACCOUNTINGMETER
METER NOT REPORTINGTO PETRINEX
Hangingstone Project - Measurement Schematics Well Pads
-
Well Production and Injection Volumes
Each well pad has a dedicated test separator with liquid flow meter and water cut analyzer to determine well bitumen and water production.
Wells will be individually put on test for one valid testing hour for every 20 hours of operation. Valid well test criteria per approved MARP.
Well gas production prorated from Battery Level GOR using a proration factor of 1. Battery Level GOR will be updated monthly.
Steam injection is metered at each individual wellhead. Primary and secondary steam production metering available at the central steam plant.
Battery Sales Oil
Sales oil will be trucked from the Hangingstone Battery. Custody transfer metering will be done at the receiving facility.
Measurement Technology
Well testing uses standard method of test separators with microwave water cut analyzers. New technologies such as multiphase flow meters may be evaluated later.
47
Hangingstone Project - Measurement Methodology
-
48
Fresh Water Wells
Water Diversion Licence 00316166-00-00 received on March 8, 2013 for 479,975 m3 annually.
ESRD-licenced fresh water source wells:
Wells are less than 150 m in depth and not licenced with the AER. Well IDs are AOC internal identifiers, not UWIs.
Well ID Location Formation TDS (mg/L) Maximum Rate of Diversion (m3/d)
WSW153308508W400 15-33-085-08-W4 Quaternary 286 3,000
WSW061208609W400 06-12-086-09-W4 Quaternary 303 3,000
WSW040808608W400 04-08-086-08-W4 Quaternary 287 3,000
Hangingstone Project Water Production, Injection and Uses
-
49
Water volumes
Values are annual averages; Makeup includes recoverable utility water.
Evaporator blowdown (Disposal) is not recycled.
Disposal water will be 90oC at atmospheric pressure, trucked out.
Split sump concentrating evaporator design minimizes disposal volumes.
Waste will be sent to approved off-site disposal facilities.
Due to access restrictions AOC is currently obtaining water under TDLs to address water requirements for drilling and construction.
Fresh Source Water
Time Bitumen Steam Produced
Water Returned to Environment
Unrecoverable Utility Makeup TOTAL Disposal PW
(Years) (m3/cd) (m3/cd) (m3/cd) (m3/cd) (m3/cd) (m3/cd) (m3/cd) (m3/cd) Recycle 1 1,369 4,790 3,718 100 60 1,155 1,315 83 98% 2 1,908 6,677 6,024 100 60 778 938 125 98% 3 1,908 6,677 6,231 100 60 575 735 129 98% 4 1,908 6,677 6,231 100 60 575 735 129 98% 5 1,908 6,677 6,231 100 60 575 735 129 98% 6 1,908 6,677 6,231 100 60 575 735 129 98% 7 1,908 6,677 6,231 100 60 575 735 129 98% 8 1,908 6,677 6,231 100 60 575 735 129 98% 9 1,868 6,539 6,102 100 60 557 717 120 98% 10 1,348 4,716 4,400 100 60 406 566 90 98% 11 0 0 0 0 0 0 0 0 0%
Hangingstone Project Water Production, Injection and Uses
-
50
Sulphur production under one tonne/day, no recovery.
Sulphur balance (from SIR 2):
RESERVOIR BITUMEN TREATING
WATER TREATINGSTEAM GENERATION
Bitumen 107 t/cd S 114 t/sd S
Produced Gas 0.077 t/cd S0.082 t/sd S
Produced Water 1.0 t/cd S 1.1 t/sd S
Diluent 1.1 t/cd S for Gas Condensate1.2 t/sd S for Gas Condensate
Sales Oil 108.1 t/cd S for Gas Condensate115.2 t/sd S for Gas Condensate
Produced Water 1.0 t/cd S 1.1 t/sd S
Disposal Water 1.0 t/cd S 1.1 t/sd S
Boiler Feed Water 0 t/cd S 0 t/sd S
HP Steam 0 t/cd S 0 t/sd S
Natural Gas0 t/cd S0 t/sd S
Produced Gas 0.077 t/cd S0.082 t/sd S
Emissions 0.077 t/cd S0.082 t/sd S
Saline Water 0 t/cd S0 t/sd S
Non-Saline Water 0 t/cd S0 t/sd S
Hangingstone Project Sulphur Production
-
Hangingstone Project - Timeline
March 31, 2011 Filed Application.
September 30, 2011 Project Update and SIR 1 submitted.
March 6, 2012 Project Update and SIR 2 submitted.
October 3, 2012 Order in Council 307/2012 and AER Commercial Approval 11888.
October 5, 2012 MARP Approval (AER) 1949359.
October 29, 2012 EPEA Approval 289664-00-00.
November 6, 2012 Historical Resources Act Clearance 003119951.
February 7, 2013 D78 Pad Shift Approval (AER) 11888A.
March 20, 2013 Water Act Licence Approval 00316166-00-00.
April 29, 2013 D78 Pad Shift Approval (AESRD) 289664-00-00.
51
-
Hangingstone Project - Timeline
May 24, 2013 CPF Amendment Approval (AER) 11888B.
May 31, 2013 Groundwater Management Proposal Approval 289664-00-00.
June 7, 2013 D56 Fuel Gas Pipeline (AER) Licence 55219.
June 20, 2013 D56 CPF Amendment ( AER) Licence F45426.
July 11, 2013 Caribou Monitoring and Mitigation Plan Approved.
July 2, 2013 Substation Application submitted 1609725.
July 30, 2013 Water Act Amendment received 00316166-00-01.
September 9, 2013 D56 Pad AA (AER) Licence F46483.
September 12, 2013 CPF Amendment approved (AESRD) 289664-00-01.
September 20, 2013 D56 Residue Fuel Gas Pipeline (AER) Licence 55432.
52
-
Compliance
-
54
Zero non-compliance instances related to EPEA Approval 289664-00-01.
3 trespass incidents were self disclosed to the AESRD Forestry Officer.
1 AER High Risk non-compliance for the filing of Fuel Gas Pipeline (AER) Licence 55219 prior to signed PLAs being issued.
Corrective action was taken on December 14, 2012 by filing an amendment to change the status to non-construct.
A new application was filed on May 27, 2013 with the signed PLAs.
1 AER reportable spill.
5.5 m3 water based polymer drilling mud released while drilling 109/04-31-086-09 W4M on Pad AA.
In compliance with DFO guidelines and regulations.
AOC has not started reclamation for the approved footprint as it is currently under construction.
54
Hangingstone Project - Compliance
-
Hangingstone Project - Regional Initiatives
55
AOC is a funding member of:
Wood Buffalo Environmental Association,
Oil Sands Developers Group,
Alberta Biodiversity Monitoring Institute, and
Joint Oil Sands Monitoring Program.
55
-
Future Plans
-
Hangingstone Project - Future Plans
57
AOC filed an application for the Hangingstone Expansion Project in May 2013.
The Expansion includes:
increase the bitumen recovery capacity from the existing approved 1,908 m3/d (12,000 bpd) to 13,037 m3/d (82,000 bpd) to be developed in two phases:
HS2 will add an incremental 6,360 m3/d (40,000 bpd) and
HS3 will add an incremental 4,770 m3/d (30,000 bpd).
Extension of the production life from 10 to 40 years,
CPF expansion from 35 ha to 76 ha,
Field facilities and,
Offsite and utility services.
57
-
Corporate Office 2000, 250 6 Ave SW
Calgary, Alberta, T2P 3H7 Telephone: 403-237-8227
Fax: 403-264-4640 www.atha.com
Hangingstone Project Update for AER October 2012 to September 2013Hangingstone Project - IntroductionSlide Number 3Slide Number 4Slide Number 5Hangingstone Project Surface and Subsurface Layout Slide Number 7Slide Number 8Slide Number 9Slide Number 10Slide Number 11Slide Number 12Slide Number 13Slide Number 14Slide Number 15Slide Number 16Slide Number 17Slide Number 18Slide Number 19Slide Number 20Slide Number 21Slide Number 22Slide Number 23Slide Number 24Slide Number 25Slide Number 26Slide Number 27Slide Number 28Slide Number 29Slide Number 30Slide Number 31Slide Number 32Slide Number 33Slide Number 34Slide Number 35Slide Number 36Slide Number 37Slide Number 38Slide Number 39Slide Number 40Slide Number 41Slide Number 42Slide Number 43Slide Number 44Slide Number 45Slide Number 46Slide Number 47Slide Number 48Slide Number 49Slide Number 50Hangingstone Project - TimelineHangingstone Project - TimelineSlide Number 53Slide Number 54Slide Number 55Slide Number 56Slide Number 57Slide Number 58