Urban Planning Design Considerations for Better Water Quality, Bill Hunt NC S...
Planning a Chemical Flood EOR Asia 2012 MB Dupont
1. 2012 EOR Asia
Kuala Lumpur, Malaysia
Mike Dupont P.Eng, EOR Implementation Manager
December 6th, 2012
Planning and Development of a Chemical
Flood in a Heavy Oil Pool - Coleville
Saskatchewan, Canada
2. 2
Presentation Outline
• Introduction
• Industry Chemical Flooding Activity
• Discussion of Workflow & Screening
• Coleville Main Reservoir Parameters
• Geologic Setting
• Core Flood Results
• Simulation
• Pilot Review
• Results, Monitoring
• Commercial Project
3. 3
Introduction
• Penn West Exploration has significant Heavy Oil
assets with over 1 billion bbls OOIP in
Saskatchewan, Canada
• Penn West is currently piloting an ASP flood in
Coleville, Saskatchewan
• This is the most viscous oil to ever be ASP flooded
with in-situ viscosities in the 700 - 2000 cp range
4. 4
Coleville Main
Pushing Limits of ASP Application
Successful Field Applications of Chemcial Flood
0
5
10
15
20
25
30
35
40
0 200 400 600 800 1000 1200 1400 1600 1800 2000
Oil Viscosity, cp
OilGravity,o
API
Polymer Alkali-Polymer Alkali-Surfactant-Polymer Polymer (East Bodo)
POLYMER FLOOD
East Bodo
ASPFLOOD
AP flood
Thompson
Creek, WY
Coleville Main
Pelican
5. Chemical Flood Projects in Canada
Industry Active and Proposed
Penn West land position
Penn West has the most
leverage to large scale oil
development using
horizontal multi-stage
fracturing technology
in North America
Cardium Viking
Spearfish
Carbonates
Penn West
Operated Pilot
Coleville / Hoosier
6. 6
Workflow
Coleville Project
1. Screening – Reservoir characteristics and performance
2. Preliminary modeling /forecasts and economics
3. Laboratory determination of flood performance
4. Simulation – Core and up-scaled predictions
5. Facilities Design
6. Procurement
7. Installation
8. Pilot
9. Lab and Simulation – Ongoing
10. Decision – Commercial or not?
Complete cycle to Commercial can take up to 5 years
7. 7
Chemical Flooding
Penn West Primary Screening Criteria
Key Attribute
Penn West
Acceptable Range
Coleville
Main
Comment
In-situ Viscosity (cp) 5-2000 700-2000 There must be an improvement in mobility ratio
Water Quality (TDS) 0-20000 9700
Directly affects cost of chemical and water treatment.
Fe and H2S are also be considered
Target Formation Sandstone Sandstone Based on current worldwide experience
Permeability (md) >200 500
Specific to Heavy Oil –
Formation must tolerate high MW polymers
Waterflood Performance Good to Excellent Good
Flood must show good conformance and
recoveries near theoretical for a water flood
Clay Content < 5% 0-5 %
Low clay content and absence of
anhydrite prime considerations
Anhydrite Content 0 0
Underlying water/active
Aquifer
None None
Pool Size (bbls) >10MM 475MM Larger fields provide economies of scale
8. 8
Coleville Main
Reservoir Parameters and Performance
Pool Area 9815 acres (39.6 km2)
Lithology Sandstone
Average Net Pay 36' (12 m)
Original Oil in Place, OOIP 475MM bbls (75.5 MM m3)
Cumulative Oil Produced 65.5 MM bbls (10.4 MM m3)
Current Oil Production Rate 1800 bpd (286 m3opd)
Current Water Cut 96%
Recovery Factor to Date 13.80%
Initial Pressure 993 psi (6850 kPa)
Current Pressure 725 psi (5000 kPa)
Bubble Point pressure, Pb 993 psi (6850 kPa)
Oil Viscosity at Pb 700
Oil API Gravity 13
Formation Volume Factor, Bo 1.07
Initial Solution GOR, Rs 22
Reservoir Temperature 84 F (29 C)
Average Water Saturation, Sw 24%
Average Porosity 24%
Depth 2667' (813 m)
Well Spacing 20 acre (300 m)
Current # of Wells
Producing/Injecting
190/109
10. 10
Geology
Regional Bakken Deposition
• The intervening areas between
the sand accumulations are filled
with shale and silt
• An erosional low truncates the
Bakken and is filled with
Mannville sediments
• The Bakken sand was deposited
in the form of offshore bars in a
near-shore, shallow marine
environment
• The sands were deposited in a
NE-SW trend and can attain a
thickness greater than 15 metersColeville Main Field
11. 11
Depositional Setting
Deposition of offshore mudstone and lower, middle and upper shoreface quartz sandstone lithofacies
of the Middle Bakken Member in a coastal marine environment
(From Smith and Bustin. 1996)
18. 18
Coleville Main Pool
Core Analysis
OOIP Recoveries
Area Date
Coreflood
Type
Waterflood Polymer AP SP ASP Total
Coleville Main April 2010 Linear 50.3% 20.9% 6.8% 78.0%
Coleville Main April 2010 Radial 34.5% 31.9% 66.4%
Coleville Main April 2010 Radial 30.9% 26.8% 57.8%
Coleville Main April 2010 Radial 32.9% 22.8% 55.7%
Coleville Main April 2010 Radial 36.4% 23.4% 59.8%
Surtek Coreflood Results
19. 19
Coleville Main
Generic Simulations
Pattern Spacing (m)
Injection
Well Type
Production
Well Type
Producing
Layers
Incremental Recoveries (%)
Notes
Waterflood Polymer ASP
Line Drive 300 Vertical Vertical All 22.7 4.5 14
Line Drive 150 Horizontal Vertical Lower 6.4 11
Line Drive 150 Horizontal Vertical Upper/Lower 6.4 17
Inverted 5 Spot 150 Vertical Vertical All 5 12.5
Injectors converted
to producers
Inverted 5 Spot 150 Vertical Vertical All 7 17.6
Infill wells are
producers only
Simulations by Kade Technologies
Calgary, Alberta
20. 20
Coleville Main ASP Pilot
Summary
• Number of injection wells in pilot: 4 (Vertical Line Drive)
• Injection rates per well: 440 bpd (70 m3/d)
• Project start: March 28, 2011
• Pore volumes injected to date
• 11.0% (to Hz Wells ~150 m)
• 5.0% (to Vertical Wells ~300 m)
• Lab coreflood response: 15 to 22% range
• Average well-head injection pressure: 798 PSI (6200 kPa)
• Chemical Additives: 0.75% Na2CO3, 0.1% surfactant, 1500 ppm HPAM
25. 25
Coleville Main Pool
Pilot Results
• Pilot is still in early phases
• 6 to 12 months until pilot enters sufficient pore volume to see strong results
26. 26
Coleville Main ASP Pilot
Breakthrough Indicators - Water Analyses
Water Analyses
• Decreasing TDS
• Decreasing Cl
• Increasing pH
• Increasing CO3/HCO3 ratio
• Presence (concentration)
of polymer
27. 27
Coleville Main Pool
Pilot Results: Section 19-31-23W3M
ASP Discussion
• Injection initiated March 2011
• Good flood conformance to date
• Injected 11% PV with no fresh
source water breakthrough
• Offsetting wells have seen Oil
cut increases from 10-17.6%
Daily Oil (bbl)
Daily Water Injection (bbl)
WH Injection Press (psig)
Daily Water Cut (%)
ASP Injection Start
Oil Cut Increase
30. 30
Coleville Main ASP
Injector Performance
Indication of Injection
Pressure Sensitivity
to the Initiation of
Offsetting Horizontal
Well production
31. 31
Coleville Main
Commercial Chemical Flood Strategy
• ASP flood to target residual oil
Estimated 45% residual oil after waterflood
• Drill infill wells to increase recovery factor
Assumed 3% average but could be up to 10%
• Increase current injection rates by 4x per well
• Rebuild and expand infrastructure
New facility at Coleville Main, replace production lines,
cleanout and repair all existing injectors
• Access available source water
Bakken or Mannville most likely zones
32. 32
Proposed Coleville Main
Phase 1
Pilot Area
Project Area
Coleville
South
• Phase 1 Area – Selection Criteria
• Main battery located at 10 - 30
• Favorable Geology
• Relatively low recovery factor
• Good surface access
• Offset to pilot
• Plan Summary
• 10 acre spacing Inverted 5 spot
• 45 patterns
• Conversion of existing producers
to injection
• 98 MM bbls OOIP in Phase 1
• Current EUR - 15 % OOIP
R23W3
T31
33. 33
Coleville Main Pool Development Plan
Overview
Each phase will consist of the following
• An infill program creating a 10 acre inverted 5 spot pattern
• All new wells will be producers
• Existing producers will be converted to injectors
• Expecting response time 6 to 8 months
• Chemical injection period - 5 to 6 years
