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1 Murphy Oil Company LTD. Seal Polymer Pilot Scheme Approval No B Annual ERCB Progress Presentation June 3,
2 Agenda Subsurface Surface Conclusions 2
3 Subsurface Background Geology Drilling & Completions Flood Performance Injection Pressures Future Plans 3
4 Subsurface Background Geology Drilling & Completions Flood Performance Injection Pressures Future Plans 4
5 Background Map of Seal Central Polymer injection Located in Central Seal Sections 3, 4, 9, 10 & W5 Utilizing Pads 14-10, 13-10, 13-03, 4-10, 15-4 & 2-9 5
6 Background Map of Seal Central Pilot + 3 Areas of expansion Pilot operational Oct, 2010 Area 1 operational Sept, 2012 Area 2 operational Dec, 2012 Area 3 planned for Dec,
7 Subsurface Background Geology Drilling & Completions Flood Performance Injection Pressures Future Plans 7
8 Geology - Reservoir Properties Bluesky Sand Unconsolidated, quartz-rich sandstone fine-medium grained moderate sorting Depth of ~625m TVD Net Pay Range ~4-8m in Polymer area Porosity 22-34% Permeability mD in Polymer area Reservoir temperature 19 C Water Saturation < 25%, typically 15-20% in reservoir Oil Viscosity (dead oil) 5,000 50, C Initial Reservoir Pressure kPa 8
9 Geology - Murphy Seal Type Log Murphy Seal W5 BLSK GTNG DBLT 9
10 Geology - Net Bitumen Pay Cutoffs Gamma: <65API Porosity > 22% S o > 60% (oil zone), from Resistivity Permeability > 500mD 10
11 Geology - Bluesky Net Pay Map Polymer Pilot 11
12 Geology - Bluesky Structure Map Polymer Pilot 12
13 Subsurface Background Geology Drilling & Completions Flood Performance Injection Pressures Future Plans 13
14 Drilling & Completions Pilot + Expansion Locations: Lowest viscosity compared to other locations <10 m net pay Murphy 100% working interest Flowline production Well Placement Criteria: Well placement within the top 5 meters of the Bluesky due to low viscosity and high permeability 14
15 D&C - Typical Drilling Configuration Build Section Intermediate Casing Point (ICP) Lined Horizontal Section 15
16 D&C - Typical Drilling Details Surface Casing 80m of 339.7mm, 81.1 kg/m, J-55, ST&C Intermediate Casing (311mm Hole) 219.1mm, kg/m, J-55 KOP: Approximate 367m with Builds of 9⁰/30m Slotted Production Liner (200mm Hole) 1600 m of 139.7mm,20.83 kg/m, J-55, ST&C 16
17 D&C - Typical Completion Details 17
18 Subsurface Background Geology Drilling & Completions Flood Performance Injection Pressures Future Plans 18
19 Performance Polymer Flood First Polymer Injection in October 2010 Hydrating polymer concentrations: ppm Polymer trace in produced water: >900 ppm within pilot 19
20 SEAL Polymer Pilot Pilot consists of 3 injectors and 4 producers. Approval No B to downspace on the East side of the pilot. 70 meter spacing Production response has been observed since Q
21 Performance Production/Injection Profile Increased production >70 m3/day Production spike in 2010 due to 2 infill wells Maintained plateau for 1.5 years Observed that: Reduced injection rates = Reduced production rates 21
22 Performance Polymer Flood Response noticed in Q3, 2011 Increased Water cuts on all producers (<50%) Maintaining reservoir voidage at approximately 100% Volume of injected polymer to date 142,679 E3m3 Expected incremental recovery factor after polymer flood 8.8% Produced solution gas from the pilot & expansion is captured and tied in to 4-33 battery. No response has been observed in the expansion areas. 22
23 Performance Key Learning s 70m spacing more effective compared to 140m Observed reduced GOR s within the pilot area Wells need to be lined throughout the horizontal section Injectivity is a non-issue with wells on vacuum at the start of injection Higher injection pressures yield better production Water production increases before oil response Source water quality and quantity is crucial for the success of the project Higher TDS (specifically Fe & Mg) results in higher polymer concentrations to achieve required viscosity 23
24 Subsurface Background Geology Drilling & Completions Flood Performance Injection Pressures Future Plans 24
25 Injection Pressures Polymer Injection Approval Pressure (Approval # 11320) MAWHIP 3,780 kpa MABHIP 9,800 kpa Monitoring Injection Pressure At least 1 well on each pad within the polymer expansion is equipped with down hole pressure and temperature monitoring. Surface pressure recorded daily and monitored to ensure MAWHIP is not exceeded. 25
26 Injection Pressure W1330 W1050 W910 W770 Decline in pressure *April, 2012 was due to reducing injection rates to a 1:1 ratio with production volumes Injection pressures are monitored by means of pressure transducers throughout the horizontal sections of the above mentioned wells 26
27 Subsurface Background Geology Drilling & Completions Flood Performance Injection Pressures Future Plans 27
28 Future - Expansion Plans Murphy has commissioned 2 of the 3 area s of the commercial expansion. Area 3 injection is planned for December 2013 Murphy is in the process of drafting up an application for further polymer injection within Central Seal. 28
29 Future Plans- Expansion Located in Central Seal just North of existing pilot and expansion. Similar reservoir characteristics and viscosities 29
30 Surface Facilities Non-Saline Water Use and Conservation Regulatory Future Plans 30
31 Surface Facilities Non-Saline Water Use and Conservation Regulatory Future Plans 31
32 Facilities - Battery Locations Located in Central Seal All producing well from the polymer pilot are flowlined to the 4-33 CPF Polymer Scheme T CPF R15 32
33 Facilities 4-33 Plot Plan 33
34 Pilot Plot Plan 34
35 Facilities Polymer PFD 35
36 Area Plot Plan 36
37 Area PFD 37
38 Area P&ID 38
39 Area Plot Plan 39
40 Area Plot Plan 40
41 Area 2 - PFD 41
42 Area 2 - PFD 42
43 Area 2 - PFD 43
44 Area Plot Plan 44
45 Area Plot Plan 45
46 Area 3 - PFD 46
47 Area 3 - PFD 47
48 Surface Facilities Non-Saline Water Use and Conservation Regulatory Future Plans 48
49 Water Usage - Paddy Well Location Paddy 4-10 Notikewan 2-10 Notikewan 15-3 Paddy 49
50 UWI: 1F1/ W5/0 Water Usage - Paddy Formation Murphy currently has term license with Alberta Environment for the diversion of up to 164,260 m 3 of Paddy water for injection with an expiry date of UWI: 1F1/ W5/0 *not on production No TDL necessary with TDS testing >4000 ppm 50
51 Water Usage - Notikewan Formation UWI: 1F1/ W5 *not on production UWI: 1F1/ W5 *not on production TDL s are not needed for Notikewan wells with TDS >4000 ppm 51
52 Water Usage Planning and Operation Murphy is currently developing a water management program for the entire Seal field Produced water recycling is challenging with the presence of hydrated polymer. An economic solution is needed to handle produced emulsion at lower treating temperatures In compliance with Alberta Environment regarding weekly reporting and all other terms of the License 52
53 Water Usage Injected Volumes Pilot & Area 1 Area 2 53
54 Water Usage Produced Volumes Produced volumes are reported from test tanks located at the well site (tested weekly) From the start of the polymer flood there has been a recorded 7,623 m 3 of produced water Water volumes are calculated through BS&W tests conducted simultaneously with the well test Proration factors for production volumes are calculated using standard accounting procedures which are outlined section 3 of Directive 17 and section of Directive 7. Proration factors are also included as part of Directive 76 (Theme 14) for which Murphy reviews and signs off on as part of our controls environment. Produced water is currently being injected into disposal wells 102/ W5/0, 100/ W5/0 and 100/ W5/0 Proration Factors for
55 Water Usage Disposal Approval No A Approval No
56 Water Usage Disposal Approval No
57 Surface Facilities Non-Saline Water Use and Conservation Regulatory Future Plans 57
58 Regulatory - Scheme Approval Murphy is not aware of any outstanding compliance issues regarding the current approvals Murphy is in compliance with other regulatory bodies (SRD, AENV, DFO) 58
59 Surface Facilities Non-Saline Water Use and Conservation Regulatory Future Plans 59
60 Future Expansion 2 Murphy is currently looking into the required infrastructure needed to expand the polymer flood within Central Seal. 60
61 Conclusion Murphy is committed to maximizing the value of the resource for both itself and the province of Alberta through it s royalty interest Results over the last year have continued to show polymer flooding in heavy oil as successful, which supports the future expansion of the polymer flood Compliance with all ERCB regulations continues to be a top priority 61
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