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212-035
Image Project Well History File Cover Page XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. Qci a- OT3 Well History File Identifier Organizing (done) ❑ Two-sided ❑ Rescan Needed RE AN: OVERSIZED: NOTES: Co r Items: ❑ Maps:V R ET,Items: ❑ Logs: WELL E LIQ ❑ Poor Quality Originals: ❑ Other: �J ❑ Other: BY: MX. Date: 1111 a,6—' /s/ u ' Project Proofing BY: 441111W Date: 7iia s ` 9 /s/ M---P Scanning Preparation x 30 = + = TOTAL PAGES jv (Count does not include cover sheet) 0P BY: Date: /s/ - Production Scanning Stage 1 Page Count from Scanned File: ac. (Count does include cover sheet) Page Count Matches Number in Scanning Pre aration: IA.ES NO BY: Date: F'Y 1 as / Is! Vylp Stage 1 If NO in stage 1, page(s) discrepancies were found: YES NO BY: Maria Date: /s/ Stage 2 Additional Well Reports: YES NO TOTAL PAGES: Digital version appended by: Meredith Michal Date: /s/ Final Page Count: Stage 1 + Stage 2: TOTAL PAGES: Scanning is complete at this point unless rescanning is required. ReScanned BY: Maria Date: /s/ Comments about this file: Quality Checked 7/8/2014 Well History File Cover Page_20140708.doc SEAN PARNELL, GOVERNOR iiin6i O Dill ARM V> 333 W.7th AVENUE,SUITE 100 CIDDIBEEIRMITIDY COPEDIMaoneEr ANCHORAGE,ALASKA 99501-3539 PHONE (907)279-1433 FAX (907)276-7542 L. Gantt CTD Engineering Supervisor ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510-0360 Re: Kuparuk River Field, Kuparuk River Oil Pool, 1E-05AL1-01 ConocoPhillips Alaska, Inc. Permit No: 212-035 Surface Location: 653' FSL, 633' FEL, SEC. 16, T11N, R10E, UM Bottomhole Location: 2376' FSL, 475' FEL, SEC. 16, T11N, R1OE, UM Dear Mr. Gantt: Enclosed is the approved application for permit to re-drill the above referenced development well. The permit is for a new wellbore segment of existing well KRU 1E-05A, Permit No 211- 156, API 50-029-20479-01. Production should continue to be reported as a function of the original API number stated above. This permit to drill does not exempt you from obtaining additional permits or an approval required by law from other governmental agencies and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. Sincerely, Cathy P. Foerster Chair DATED this 'f day of March, 2012. cc: Department of Fish 86 Game, Habitat Section w/o encl. (via e-mail) Department of Environmental Conservation w/o encl. (via e-mail) STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL ;' C.' 1 20 AAC 25.005 .f-,c i r`rr-nils Oi ' r ConocoPhillips Alaska P.O.BOX 100360 r,_ E n ANCHORAGE,ALASKA 99510-0360 MAS' 2 2u92 March 19, 2012 Alaska Oil& Gas Cons. Cemmissior Commissioner-State of Alaska Anchor age Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Dear Commissioner: ConocoPhillips Alaska, Inc. hereby submits Permit to Drill (PTD) applications to drill and complete six laterals from Kuparuk well 1E-05A (PTD# 211-156). Coiled tubing drilling (CTD) operations are scheduled to begin as early as April 10, 2012, using the rig, Nabors CDR2-AC. The objective of the CTD project is to improve A-Sand sweep efficiency and oil recovery within the target pattern by drilling lateral sidetracks. Three laterals each are planned to be drilled from two window exits from the 5.5" liner in parent wellbore, 1E-05A. The parent wellbore will have no producing sections; it will be considered "Suspended" until the CTD laterals are drilled and completed. At that point a 10-404 form will be submitted changing the 1E-05A status from "Suspended" to "Oil-Development". For that reason, the laterals will be named: 1 E-05AL1, 1 E-05AL1-01, 1 E-05AL1-02, 1 E-05AL2, 1 E-05AL2-01, and 1 E-05AL2-02. Attached to this application are the following documents that explain the proposed job operations: — Permit to Drill Application Forms: 1E-05AL1, 1E-05AL1-01, 1E-05AL1-02, 1E-05AL2, 1E-05AL2-01, and 1 E-05AL2-02 — Directional Plans: 1 E-05AL1, 1 E-05AL1-01, 1 E-05AL1-02, 1E-05AL2, 1 E-05AL2-01, and 1 E-05AL2-02. — Current Wellbore Schematic — Proposed Post-CTD Wellbore Schematic If you have any questions or require additional information please contact me at my office 907-263-4093. Sincerely, LtiC, Jill . Long ConocoPhillips Alaska Coiled Tubing Drilling Engineer Ku paru k CTD Laterals MNABORSALASKA 1 E-05AL1, 1 E-05AL1-01, 1 E-05AL1-02, 1 E-05AL2, 1 E-05AL2-01, 1 E-05AL2-02 CD ConocoPhilIips r Application for Permit to Drill Document " (iC 1. Well Name and Classification 2 (Requirements of 20 AAC 25.005(1)and 20 AAC 25.005(b)) 2 2. Location Summary 2 (Requirements of 20 AAC 25.005(c)(2)) 2 3. Blowout Prevention Equipment Information 3 (Requirements of 20 AAC 25.005(c)(3)) 3 4. Drilling Hazards Information and Reservoir Pressure 3 (Requirements of 20 AAC 25.005(c)(4)) 3 5. Procedure for Conducting Formation Integrity tests 4 (Requirements of 20 AAC 25.005(c)(5)) 4 6. Casing and Cementing Program 4 (Requirements of 20 AAC 25.005(c)(6)) 4 7. Diverter System Information 4 (Requirements of 20 AAC 25.005(c)(7)) 4 8. Drilling Fluids Program 5 (Requirements of 20 AAC 25.005(c)(8)) 5 9. Abnormally Pressured Formation Information 5 (Requirements of 20 AAC 25.005(c)(9)) 5 10. Seismic Analysis 5 (Requirements of 20 AAC 25.005(c)(10)) 5 11. Seabed Condition Analysis 5 (Requirements of 20 AAC 25.005(c)(11)) 5 12. Evidence of Bonding 5 (Requirements of 20 AAC 25.005(c)(12)) 5 13. Proposed Drilling Program 6 (Requirements of 20 AAC 25.005(c)(13)) 6 Summary of Operations 6 Pressure Deployment of BHA 7 Liner Running 7 14. Disposal of Drilling Mud and Cuttings 8 (Requirements of 20 AAC 25.005(c)(14)) 8 15. Directional Plans for Intentionally Deviated Wells 8 (Requirements of 20 AAC 25.050(b)) 8 16. Quarter Mile Injection Review (for injection wells only) 8 (Requirements of 20 AAC 25.402) 8 17. Attachments 8 Attachment 1: Directional Plans for 1 E-05AL1, 1 E-05AL1-01, 1 E-05AL1-02, 1 E-05AL2, 1 E-05AL2-01, 1 E-05AL2-028 Attachment 2: Current Well Schematic for 1E-05A 8 Attachment 3: Proposed Well Schematic for 1 E-05AL1, 1 E-05AL1-01, 1 E-05AL1-02, 1 E-05AL2, 1E-05AL2-01, 1 E- 05AL2-02 8 Page 1 of 8 3/19/2012 PTD Application: 1 E-05AL1, 1 E-05AL1-01, 1 E-05AL1-02, 1 E-05AL2, 1 E-05AL2-01, 1E-05AL2-02 1. Well Name and Classification (Requirements of 20 AAC 25.005(f)and 20 AAC 25.005(b)) The proposed laterals described in this document are 1 E-05AL1, 1 E-05AL1-01, 1 E-05AL1-02, 1E-05AL2, 1 E- 05AL2-01, 1 E-05AL2-02. All six of these laterals will be classified as"Development- Oil'wells. 2. Location Summary (Requirements of 20 AAC 25.005(c)(2)) This wellbore is planned to be a lateral targeting the A sand package in the Kuparuk reservoir. Location at Surface 653' FSL, 633' FEL, Sec 16, T11N, R10E, UM NAD 1927 RKB Elevation 101 AMSL Northings: 5960237 Eastings: 549890 Pad Elevation 69.5 AMSL 1 E-05AL1 Location at Top of Productive Horizon 2333' FSL, 1436' FWL, Sec 15, T11N, R10E, UM (Kuparuk) NAD 1927 Measured Depth, RKB: 7575' Northings: 551943.5 Eastings: 5961933.8 Total Vertical Depth, SS: 6259' Location at Total Depth 2340' FSL, 406' FWL, Sec 15, T11N, R10E, UM NAD 1927 Measured Depth, RKB: 8650' Northings: 5961933.8 Eastings: 550913.5 Total Vertical Depth, SS: 6160' 1 E-05AL1-01 Location at Top of Productive Horizon 2269' FSL, 337' FWL, Sec 15, T11N, R10E, UM (Kuparuk) NAD 1927 Measured Depth, RKB: 8700' Northings: 5961862 Eastings: 550845 Total Vertical Depth, SS: 6197' Location at Total Depth 2376' FSL, 475' FEL, Sec 16, T11N, R10E, UM NAD 1927 Measured Depth, RKB: 9535' Northings: 5961964 Eastings: 550032 Total Vertical Depth, SS: 6219' 1 E-05AL1-02 Location at Top of Productive Horizon 2124' FSL, 1743' FWL, Sec 15, T11N, R10E, UM (Kuparuk) NAD 1927 Measured Depth, RKB: 7030' Northings: 5961727 Eastings: 552252 Total Vertical Depth, SS: 6148' Location at Total Depth 2331' FSL, 539' FEL, Sec 16, T11N, R10E, UM NAD 1927 Measured Depth, RKB: 9590' Northings: 5961964 Eastings: 550032 Total Vertical Depth, SS: 6192' 1 E-05AL2 Location at Top of Productive Horizon 2162' FSL, 2095' FWL, Sec 15, T11N, R10E, UM (Kuparuk) NAD 1927 Measured Depth, RKB: 7435' Northings: 5961768 Eastings: 552604 Total Vertical Depth, SS: 6217' Location at Total Depth 2155' FSL, 2365' FEL, Sec 15, T11N, R10E, UM NAD 1927 Measured Depth, RKB: 8265' Northings: 5961766 Eastings: 553423 Total Vertical Depth, SS: 6283' G1NAL Page 2 of 8 3/19/2012 PTD Application: 1 E-05AL1, 1 E-05AL1-01, 1 E-05AL1-02, 1 E-05AL2, 1 E-05AL2-01, 1 E-05AL2-02 1 E-05AL2-01 Location at Top of Productive Horizon 2204' FSL, 1892' FWL, Sec 15, T11N, R10E, UM (Kuparuk) NAD 1927 Measured Depth, RKB: 7225' Northings: 5961808 Eastings: 552401 Total Vertical Depth, SS: 6230' Location at Total Depth 2149' FSL, 2366' FEL, Sec 15, T11N, R10E, UM NAD 1927 Measured Depth, RKB: 8275' Northings: 5961760 Eastings: 553423 Total Vertical Depth, SS: 6222' 1 E-05AL2-02 Location at Top of Productive Horizon 3181' FNL, 1730' FWL, Sec 15, T11N, R10E, UM (Kuparuk) NAD 1927 Measured Depth, RKB: 6980' Northings: 5961701 Eastings: 552240 Total Vertical Depth, SS: 6106' Location at Total Depth 1949' FSL, 2213' FWL, Sec 15, T11N, R10E, UM NAD 1927 Measured Depth, RKB: 7700' Northings: 5961555 Eastings: 552723 Total Vertical Depth, SS: 6229' 3. Blowout Prevention Equipment Information (Requirements of 20 AAC 25.005(c)(3)) Please reference blowout prevention (BOP) schematics on file with the Commission for Nabors CDR2-AC. BOP equipment is as required per 20 AAC 25.036, for thru-tubing drilling operations. — Pipe rams, blind rams and the CT pack off will be pressure tested to 250 psi and to 3500 psi. (Using the maximum pressure at which the reservoir was static after drilling the 1E-05A Rotary Sidetrack of 3516 psi, the maximum possible surface pressure, assuming a gas gradient of 0.1 psi/ft, would be 2900 psi. See the"Drilling Hazards Information and Reservoir Pressure" section for more details.) — The annular preventer will be tested to 250 psi and 2500 psi. 4. Drilling Hazards Information and Reservoir Pressure (Requirements of 20 AAC 25.005(c)(4)) Reservoir Pressure and Maximum Downhole Pressure (Requirements of 20 AAC 25.005(c)(4)(a)) An updated static bottomhole pressure (BHP) reading was obtained in the parent wellbore, 1 E-05, in December 2011, prior to the rotary sidetrack. The pressure at that time was 2610 psi at 6800' MD/6014' TVDSS. This would be the equivalent of 8.3•ppg fluid. Nordic 3 rig sidetracked 1E-05A out of 1E-05 in February 2012. The parent wellbore was isolated and the new bottomhole location was positioned in a new fault block. The _final fluid weight at the time of TD (7273'MD/6350'TVDSS), with both the A and C sands open, was 11.0 ppg. Based upon this final fluid weight, the maximum anticipated bottomhole pressure at the kickoff points (KOPs) for the CTD laterals is 3516 psi, an 11.0 ppg equivalent mud weight(EMW). Considering all surrounding wellbores, the most recent pressure surveys indicate pressures no greater than 8.3 ppg to be expected. Because of this surrounding well data, the maximum downhole pressure in the area is expected to be the 11.0 ppg equivalent, mentioned above. Potential Gas Zones (Requirements of 20 AAC 25.005(c)(4)(b)) No specific gas zones will be drilled; however, 1E pad does have some wells on miscible gas injection (MI) so encountering MI gas is a possibility. ORI (‘0W Page 3 of 8 3/19/2012 PTD Application: 1 E-05AL1, 1 E-05AL1-01, 1 E-05AL1-02, 1 E-05AL2, 1 E-05AL2-01, 1 E-05AL2-02 Potential Causes of Hole Problems (Requirements of 20 AAC 25.005(c)(4)(c)) The largest, expected risk of hole problems in the 1 E-05A laterals will be at fault crossings and shale interfaces. There are several large fault crossings (with throws of 30' or more) in both the Western and Eastern laterals. This risk has been taken into account by developing plans that call for drilling shorter laterals which will place less drilled footage at risk in the event of a hole collapse. Also, based on lessons learned while drilling 1E-24, if a large fault is crossed in an unfavorable location, consideration will be given to plugback and redrill sooner. 5. Procedure for Conducting Formation Integrity tests (Requirements of 20 AAC 25.005(c)(5)) N/A for this thru-tubing drilling operation. According to 20 AAC 25.030(/), thru-tubing drilling operations need not perform additional formation integrity tests. 6. Casing and Cementing Program (Requirements of 20 AAC 25.005(c)(6)) New Completion Details Lateral Name Liner Liner Btm Liner Top Liner Btm Liner Details Top MD MD TVDSS TVDSS 1E-05AL1 7575' 8650' 6259' 6160' 2%", 4.7#, L-80, ST-L slotted liner; liner top billet on top. 1E-05AL1-01 8700' 9535' 6197' 6219' 23/", 4.7#, L-80, ST-L slotted liner; liner top billet on top. 1E-05AL1-02 7025' 9590' 6144' 6192' 23/", 4.7#, L-80, ST-L slotted liner; shorty deployment sleeve on top. 1 E-05AL2 7435' 8265' 6217' 6283' 2%' 4.7#, L-80, ST-L slotted liner; anchored aluminum billet on top. 1 E-05AL2-01 7225' 8275' 6230' 6222' 2%", 4.7#, L-80, ST-L slotted liner; liner top billet on top. 1 E-05AL2-02 6780' 7700' 5940' 6185' 2'/", 4.7#, L-80, ST-L slotted liner; shorty deployment sleeve on top. Existing Casing/Liner Information Category OD Weight Grade Connection Top Btm Top Btm Burst Collapse (ppf) MD MD TVD TVD psi psi Conductor 20" 94 H-40 Welded 0' 95' 0' 95' 1530 520 Surface 13-3/8" 72 N-80 BTC 0' 2416' 0' 2210' 5380 2670 Casing 9-5/8" 47 L-80 BTC 0' 5012' 0' 4356' 6870 4750 Liner 5-1/2 " 15.5 L-80 BTCM 4802' 7267' 4159' 6446' 4990 7000 Tubing 3-1/2 " 9.3 L-80 EUE 8rd-mod 0' 4725' 0' 4088' 10540 10160 Tubing 3-1/2 " 9.3 L-80 Hydril 563 4725' 6649' 4088' 5929' 10540 10160 Tubing 3-1/2 " 9.3 L-80 EUE 8rd-mod 6649' 6788' 5929' 6048' 10540 10160 7. Diverter System Information (Requirements of 20 AAC 25.005(c)(7)) N/A for this thru-tubing drilling operation. Nabors CDR2-AC will be operating under 20 AAC 25.036, for thru-tubing drilling operations. Therefore, a diverter system is not required. - L i I \ r L.1 Page 4 of 8 3/19/2012 PTD Application: 1 E-05AL1, 1 E-05AL1-01, 1 E-05AL1-02, 1 E-05AL2, 1 E-05AL2-01, 1 E-05AL2-02 8. Drilling Fluids Program (Requirements of 20 AAC 25.005(c)(8)) Diagram of Drilling System Diagram of Nabors CDR2-AC mud system is on file with the Commission. Description of Drilling Fluid System — Window milling operations: Chloride-based Biozan brine (8.6 ppg) — Drilling operations: Chloride-based Flo-Pro Flo Vis mud (9.7 ppg). While this mud weight does not hydrostatically overbalance the reservoir pressure, overbalanced conditions will be maintained using MPD practices described below. — Completion operations: 1 E-05A contains a subsurface safety valve (SSSV). The SSSV will be used to pressure deploy the liner in lieu of loading the well with completion fluid. In the event that the SSSV becomes inoperable, the well will be loaded with 12.0 ppg Sodium Bromide completion fluid in order to maintain managed pressure on open reservoir while running completions. — Emergency Kill Weight fluid: Two well bore volumes (-170 bbl) of 12.0 ppg emergency kill weight fluid will be within a short drive to the rig during drilling operations. In this situation, a "wellbore volume" is defined as the tubing volume plus the volume of the longest lateral. Managed Pressure Drilling Practice Managed pressure drilling (MPD) techniques will be employed to maintain a constant overbalanced pressure on the openhole formation throughout the coiled tubing drilling (CTD) process. Maintaining a constant BHP promotes wellbore stability, particularly in shale sections, while at the same time providing an overbalance on the reservoir. Through experience with drilling CTD laterals in the Kuparuk sands, 11.8 ppg has been identified as the minimum EMW to ensure stability of shale sections. For the CTD work at 1E-05A, a constant BHP target of 11.8 ppg will be targeted at the window. Since this well is proposed as an infield development candidate in an actively water flooded field, expected reservoir pressures can be difficult to estimate. The constant BHP target will be adjusted to maintain overbalanced conditions if increased reservoir pressure is encountered during drilling. The constant BHP target will be maintained utilizing the surface choke. Any change of circulating friction pressure due to change in pump rates or change in depth of circulation will be offset with back pressure adjustments. 9. Abnormally Pressured Formation Information (Requirements of 20 AAC 25.005(c)(9)) N/A-Application is not for an exploratory or stratigraphic test well. 10. Seismic Analysis (Requirements of 20 AAC 25.005(c)(10)) N/A-Application is not for an exploratory or stratigraphic test well. 11. Seabed Condition Analysis (Requirements of 20 AAC 25.005(c)(11)) N/A-Application is not for an exploratory or stratigraphic test well. 12. Evidence of Bonding (Requirements of 20 AAC 25.005(c)(12)) Evidence of bonding for ConocoPhillips Alaska, Inc. is on file with the Commission. tri tF ` l.. Page 5 of 8 3/19/2012 PTD Application: 1 E-05AL1, 1 E-05AL1-01, 1 E-05AL1-02, 1 E-05AL2, 1 E-05AL2-01, 1 E-05AL2-02 13. Proposed Drilling Program (Requirements of 20 AAC 25.005(c)(13)) Summary of Operations Background Kuparuk well 1E-05A was rotary sidetracked from parent wellbore 1E-05A and completed in February 2012 as a set-up for the six CTD laterals that this application covers. The liner across the reservoir was cemented in place and has not been perforated. The plan for the parent wellbore is to leave it as "suspended"; i.e. not open the parent up to production. After the CTD laterals are drilled, a 10-404 form will be submitted changing the 1E-05A status from "Suspended" to "Oil-Development". The only production however will come from the CTD laterals from 1 E-05A. The CTD sidetracks at 1E-05A are intended to improve areal sweep efficiency and oil recovery from the 1 E- 05 pattern. The 1E-05A CTD project is the seventh well in the Re-development program at 1 E pad. Pre-Rig Work 1. Perform drift and tag. If necessary, perform a FCO to remove any fill (i.e. drilling mud) in the wellbore. 2. Perform a dummy whipstock drift as well. 3. Perform GR/CCL log for tie-in purposes to confirm KOP is spaced between collars. 4. Set BPV and prepare wellsite for rig arrival. Rig Work 1. MIRU Nabors CDR2-AC rig using 2" coil tubing. NU 7-1/16" BOPE, test. 2. Set 3.5" x 5.5" thru-tubing whipstock at 7030' MD in 1E-05A (+/- 10' to adjust for actual collar locations). 3. Mill a 2.80", single string window exit with high-side orientation. 4. Drill 1E-05AL1 Lateral a. Drill 2.70"x 3" bi-center lateral in the A4/A5 sands to a TD of 8650' MD b. Run 2%" slotted liner from TD to—7575', utilizing the SSSV for deploying the liner 5. Drill 1E-05AL1-01 Lateral a. Drill 2.70"x 3" bi-center lateral in the A4/A5 sands to a TD of 9535' MD b. Run 2%" slotted liner from TD to—8700', utilizing the SSSV for deploying the liner 6. Drill 1E-05AL1-02 Lateral a. Drill 2.70"x 3" bi-center lateral in the A4/A5 sands to a TD of 9590' MD b. Run 2%" slotted liner from TD up into the 3.5"tubing (to—7025' MD). Leave the top of liner just above the top of the whipstock at—7030' MD. 7. Set 3.5" x 5.5" thru-tubing whipstock at 6980' MD in 1E-05A (+/- 10' to adjust for actual collar locations). 8. Mill a 2.80", single string window exit with high-side orientation. 9. Drill 1 E-05AL2 Lateral a. Drill 2.70"x 3" bi-center lateral in the A4/A5 sands to a TD of 8265' MD b. Run 2%" slotted liner from TD to—7435', utilizing the SSSV for deploying the liner 10. Drill 1 E-05AL2-01 Lateral a. Drill 2.70"x 3" bi-center lateral in the A4/A5 sands to a TD of 8275' MD b. Run 2%" slotted liner from TD to —7225', utilizing the SSSV for deploying the liner 11. Drill 1 E-05AL2-02 Lateral a. Drill 2.70"x 3" bi-center lateral in the A4/A5 sands to a TD of 7700' MD b. Run 2%" slotted liner from TD up into the 3.5"tubing (to—6780' MD). Leave the top of liner below the X nipple at 6776' to allow for use of the X nipple. ... ' Page 6 of 8 I I ' 3/19/2012 PTD Application: 1 E-05AL1, 1 E-05AL1-01, 1 E-05AL1-02, 1 E-05AL2, 1 E-05AL2-01, .1 E-05AL2-02 12. POOH swapping well over to brine. Freeze protect. 13. Set BPV. ND BOPE. RDMO Nabors CRD2-AC. 14. Handover to Production group. Post-Rig Work 1. Pull BPV and install gas lift design. 2. Put on production. Pressure Deployment of BHA The planned bottomhole assemblies (BHAs) are too long to simply isolate by closing the double swab valves on the Christmas tree. Because of this, MPD operations require the BHA to be lubricated under pressure using a system of double swab valves on the Christmas tree, double deployment rams, double check valves and double ball valves in the BHA, and a slickline lubricator. This pressure control equipment listed ensures there are always two barriers to reservoir pressure, both internal and external to the BHA, during the deployment process. During BHA deployment, the following steps are observed. — Initially the double swab valves on the tree are closed to isolate reservoir pressure. The lubricator is installed on the BOP riser with the BHA inside the lubricator. — Pressure is applied to the lubricator to equalize across the swab valves. The swab valves are opened and the BHA is lowered in place via slickline. — When the BHA is spaced out properly, the double deployment rams are closed on the BHA to isolate reservoir pressure via the annulus. A closed set of double ball valves and double check valves isolate reservoir pressure internal to the BHA. Slips on the double deployment rams prevent the BHA from moving when differential pressure is applied. The lubricator is removed once pressure is bled off above the deployment rams. — The coiled tubing is made up to the BHA with the double ball valves plus the double check valves in the closed position. Pressure is applied to the coiled tubing to equalize internal pressure and then the double ball valves are opened. The injector head is made up to the riser, annular pressure is equalized, and the deployment rams are opened. The BHA and coiled tubing are now ready to run in the hole. During BHA undeployment, the steps listed above are observed, only in reverse. Liner Running — Since 1 E-05A is equipped with a SSSV, the 1E-05A CTD laterals will not need to be displaced to an overbalancing fluid prior to running liner. See the"Drilling Fluids" section for more details. — While running 2%" slotted liner, a joint of 2%" non-slotted tubing will be standing by for emergency deployment. A floor valve is made up onto this joint ahead of time, and the rig crew conducts a deployment drill with this emergency joint on every slotted liner run. The 2%" rams will provide secondary well control while running 2%" liner. L Page 7 of 8 3/19/2012 PTD Application: 1 E-05AL1, 1 E-05AL1-01, 1 E-O5AL1-02, 1 E-05AL2, 1 E-05AL2-01, 1 E-05AL2-02 14. Disposal of Drilling Mud and Cuttings (Requirements of 20 AAC 25.005(c)(14)) — No annular injection on this well. — Class II liquids to KRU 1R Pad Class II disposal well — Class II drill solids to Grind & Inject at PBU Drill site 4 — Class I wastes will go to Pad 3 for disposal. 15. Directional Plans for Intentionally Deviated Wells (Requirements of 20 AAC 25.050(b)) — The Applicant is the only affected owner. — Please see Attachment 1: Directional Plans — Magnetic and inclination surveys will be taken every 30 ft. No gyro will be run. — MWD directional, resistivity, and gamma ray will be run over the entire openhole section. — Distance to Nearest Property Line (measured to Kuparuk PA boundary at closest point) Lateral Name Distance 1 E-05AL1 20700' 1 E-05AL1-01 21200' 1 E-05AL1-02 21750' 1 E-05AL2 19400' 1 E-05AL2-01 19400' 1 E-05AL2-02 20050' — Distance to Nearest Well within Pool Lateral Name Distance Well 1 E-05AL1 930' 1E-19 1 E-05AL1-01 860' 1E-09 1 E-05AL1-02 820' 1E-09 1 E-05AL2 775' 1 E-19 1 E-05AL2-01 850' 1E-19 1 E-05AL2-02 850' 1E-19 16. Quarter Mile Injection Review (for injection wells only) (Requirements of 20 AAC 25.402) N/A for this well because it will be put on production service. 17. Attachments Attachment 1: Directional Plans for 1E-O5AL1, 1E-O5AL1-01, 1E-O5AL1-02, 1E-O5AL2, 1E- O5AL2-01, 1E-O5AL2-02 Attachment 2: Current Well Schematic for 1E-O5A Attachment 3: Proposed Well Schematic for 1E-O5AL1, 1E-O5AL1-01, 1E-O5AL1-02, 1E-O5AL2, 1E-O5AL2-01, 1E-O5AL2-02 Page 8 of 8 3/19/2012 1E-05A SIDETRACK Updated on 02/21/2012 9-5/8"casing tie-back @ 182' _ w/Hydril563 02/05/12 _ 20"Condutor Arctic Pack Job done in @ 95' 8/13/1980 - —f 3 ''/z" • ::: 49 bbls cement =_ _ _-_- :::: 116 bbls diesel X-.`` No record of press.test CMTTRMSC CMT SCSS 2.813"ID Q 1,785'MD/ 1,694'TVD 13-3/8"72#N80 casing @ 2,416'MD/2,210'TVD 3-'V2"9.3#,L-80,EUE Tubing @4,714' MD and above 111 IIII X/O EUE B X Hydri1563 P Baker ZXP lir er ' packer @ I... KOP in 9-5/8"@ .4,802'MD/4,1: :: : 5,012'MD/4,362'TVD TVD' GLM# TVD ft MD ft Valve Type Mandrel Type 1 2,488 2,762 Dummy 3-1/2"x 1-1/2" MMG 2 3,789 4,389 Dummy 3-1/2"x 1-1/2" MMG 3 4,733 5,400 Open 3-1/2"x 1" KBG-2-9 4 5,411 6,091 Dummy 3-1/2"x 1" KBG-2-9 5 5,901 6,633 SOV 3-1/2"x 1" KBG-2-9 E: *SOV(annulus to tubing shear) Cement retainer: 3-'Y2"9.2#,L-80,Hydril 563 Special +/-5,100'MDc::.,:::.:„.,.:.;.:,.„? Clearance Tubing 3.886”4,725'-6,649' Squeeze pert.-- ::-:*::::: :':<::::::::. - MD below retainel:::::::::•:•:•:•:::::::::::::::::::;::::.;:::::::::::::: :: ::::f:;:;;:< :::.::•:::•::• •: •ubing Cut @ :: ..:.:::;: :/ ;•:•:::: ::::•:5,246'MD . Backer Production Packer ,/� : ., +/-6 747'MD/5,998' TVD 7”liner Seal ::: -!.. . 40.-•::::.: Assembly "'` `` ' //. 6,399'MD :. ,... :.: 3 '/2" HES"X"selective @ .'*:.: 9-5/8"47#BTC nipple w/2.813"ID @ '' '`•`; @ 6,694'MD 6,776'MD/6,025 TVD Packer @ � oZt 6,587' '� ..'.• >: Perfs @ 6,766'–6,902' 3 '/z" WLEG @ 6,788' ... Mg MD/6,035'TVD,50' @ above Kuparuk C sand. Packer 1Z� i�� : 5-1/2" 15.5#BTCM 6,923' 7,267'MD/6,452'TVD ---mss:•:`•>: >:`•:.: o Perfs @ _......:•:•:•:•:::::::::::•:•:::::::i::.:------ 6,976 6,994 Perfs @ -:---;.-- 0::]:; : :;: -- 7,000'–7,014' 7"26#K-55 7,195'MD/6,514'TVD 0 R I Li IA L 0 2 O a M n c0 N Ud N .-N 0 r- m¢0 m Q a ^� aW� Coco O Cr) O _ —W co N N N o m ol _ Q EEm F. N HW Q o 22mmm N -,s' o a 6 I I w o aonuiOOI Q a A x x x x x W uJOo II II a 2 in in in in in r 66eiei Q II II `n J CO o `r C/3 I II II om � io CO � o W II II it H NM V t�n� (U u N. I IIF O o x ` N O) O C) - y C Q O CO O m co C t N \ I I I 0 r co V O co O co > S u 1:C2 N V N c0 (0 c..1 O- i N a \ 0 A C (V CO X O m N a N M V in j ed W cn0 x c I\ 0X N= N N iv 2 -. Z-vvic,2. coLti M 2 1C] ,co ~ J // CL M 1-N r /V/ Q ___ . \_ .2c ii i'll n 1 .r, ,v-eil, N. .o U .., V N m r �� \ V„,. N N r ..„.., „a �\ @J I o N \ I Io o _E I1 H E E / moo} o O a 1 In a r m C M 4� c_ C rn 3 J o o O c / I O Y Q ” II ec II II o a LLJ II II II L4 � —w� III � QmIoIWYa w 2 II II ILO W I II 9 ms y 0 C.1 fj_ n o Q.-c, moo s� O I.-. 4Wm :'oo CL d J E,n owl a o m n o-°-@ r, E m LU ae 1-oo oa© woo OR1GN /\ ! ConocoPhillips Alaska ConocoPhillips(Alaska) Inc. Kuparuk River Unit Kuparuk 1E Pad 1E-05 1 E-05AL1-01 Plan: 1 E-05AL1-01_wp03 Standard Planning Report 09 March, 2012 � ConocoPhillips or its affiliates ConocoPhillips Planning Report Alaska Database: EDM Alaska Prod v16 Local Co-ordinate Reference: Well 1E-05 Company: ConocoPhillips(Alaska)Inc. TVD Reference: Mean Sea Level Project: Kuparuk River Unit MD Reference: 1E-05A @ 101.10ft(Nor3(69.5+31.6)) - Site: Kuparuk 1E Pad North Reference: True Well: 1 E-05 Survey Calculation Method: Minimum Curvafure , Wellbore: 1 E-05AL1-01 Design: 1 E-05AL1-01_wp03 Project Kuparuk River Unit Map System: US State Plane 1927(Exact solution) System Datum: Mean Sea Level Geo Datum: NAD 1927(NADCON CONUS) Using Well Reference Point Map Zone: Alaska Zone 04 Using geodetic scale factor Site Kuparuk 1 E Pad Site Position: Northing: 5,959,760.24ft Latitude: 70°18'3.022 N From: Map Easting: 549,889.51 ft Longitude: 149°35'45.358 W Position Uncertainty: 0.00 ft Slot Radius: " Grid Convergence: 0.38 ° Well 1 E-05 Well Position +N/-S 0.00 ft Northing: 5,960,237.32 ft / Latitude: 70°18'7.714 N +E/-W 0.00 ft Easting: 549,890.40 ft ✓ Longitude: 149°35'45.239 W Position Uncertainty 0.00 ft Wellhead Elevation: ft Ground Level: 69.50ft Wellbore 1E-05AL1-01 Magnetics Model Name Sample Date Declination Dip Angle Field Strength (°) (0) (nT) BGGM2011 4/15/2012 16.37 79.91 57,376 Design 1 E-05AL1-01_wp03 Audit Notes: Version: Phase: PLAN Tie On Depth: 7,575.00 Vertical Section: Depth From(TVD) +N/-S +E/-W Direction P <, (ft) (ft) (ft) (0) -69.50 0.00 0.00 270.00 Plan Sections Measured TVD Below Dogleg Build Turn Depth Inclination Azimuth System +N/-S +E/-W Rate Rate Rate TFO (ft) (0) (°) (ft) (ft) (ft) (°/100ft) (°/100ft) (°/100ft) (°) Target 7,575.00 82.54 250.77 6,259.04 1,684.19 2,064.19 0.00 0.00 0.00 0.00 7,730.00 101.14 250.77 6,254.08 1,633.38 1,918.55 12.00 12.00 0.00 0.00 7,830.00 100.90 262.99 6,234.90 1,611.15 1,823.15 12.00 -0.25 12.22 90.00 7,920.00 90.10 262.99 6,226.29 1,600.24 1,734.37 12.00 -12.00 0.00 180.00 8,120.00 90.09 286.99 6,225.97 1,617.52 1,536.58 12.00 0.00 12.00 90.00 8,345.00 90.08 259.99 6,225.64 1,631.10 1,314.07 12.00 0.00 -12.00 270.00 8,425.00 98.38 255.16 6,219.74 1,613.97 1,236.24 12.00 10.38 -6.04 330.00 8,520.00 98.21 266.68 6,205.98 1,599.16 1,143.58 12.00 -0.18 12.13 90.00 8,820.00 80.11 297.93 6,210.46 1,661.85 855.26 12.00 -6.03 10.42 119.60 8,995.00 87.73 278.23 6,229.17 1,715.34 690.72 12.00 4.35 -11.25 290.00 9,110.00 95.83 267.05 6,225.58 1,720.65 576.18 12.00 7.05 -9.73 306.00 9,215.00 90.19 278.34 6,220.05 1,725.59 471.65 12.00 -5.37 10.75 116.20 9,365.00 90.18 260.34 6,219.55 1,723.86 322.28 12.00 -0.01 -12.00 270.00 9,535.00 90.17 280.74 6,219.01 1,725.44 153.19 12.00 -0.01 12.00 90.00 3/9/2012 3:08:24PM Page 2 COMPASS 2003.16 Build 69 -0•' ConocoPhillips or its affiliates ConocoPhillips Planning Report Alaska Database: EDM Alaska Prod v16 Local Co-ordinate Reference: Well 1 E-05 Company: ConocoPhillips(Alaska)Inc. TVD Reference: Mean Sea Level Project: Kuparuk River Unit MD Reference: 1E-05A @ 101.10ft(Nor3(69.5+31.6)) Site: Kuparuk 1 E Pad North Reference: True Well: 1 E-05 Survey Calculation Method: Minimum Curvature Wellbore: 1 E-05AL1-01 Design: 1 E-05AL1-01_wp03 Planned Survey Measured TVD Below Vertical Dogleg Toolface Map Map Depth Inclination Azimuth System +N/S +EI-W Section Rate Azimuth Northing Easting (ft) (°) (°) (ft) (ft) (ft) (ft) (°/100ft) (°) (ft) (ft) 7,575.00 82.54 250.77 6,259.04 1,684.19 2,064.19 -2,064.19 0.00 0.00 5,961,935.01 551,943.16 TIP KOP 7,600.00 85.54 250.77 6,261.63 1,676.00 2,040.71 -2,040.71 12.00 0.00 5,961,926.67 551,919.74 7,700.00 97.54 250.77 6,258.95 1,643.13 1,946.50 -1,946.50 12.00 0.00 5,961,893.18 551,825.76 7,730.00 101.14 250.77 6,254.08 1,633.38 1,918.55 -1,918.55 12.00 0.00 5,961,883.25 551,797.88 2 7,800.00 101.02 259.33 6,240.60 1,615.68 1,852.25 -1,852.25 12.00 90.00 5,961,865.10 551,731.70 7,830.00 100.90 262.99 6,234.90 1,611.15 1,823.15 -1,823.15 12.00 91.65 5,961,860.39 551,702.64 3 7,900.00 92.50 262.99 6,226.74 1,602.68 1,754.21 -1,754.21 12.00 -180.00 5,961,851.46 551,633.76 7,920.00 90.10 262.99 6,226.29 1,600.24 1,734.37 -1,734.37 12.00 -180.00 5,961,848.89 551,613.94 4 8,000.00 90.09 272.59 6,226.16 1,597.16 1,654.52 -1,654.52 12.00 90.00 5,961,845.28 551,534.12 8,100.00 90.09 284.59 6,226.00 1,612.08 1,555.82 -1,555.82 12.00 90.02 5,961,859.54 551,435.33 8,120.00 90.09 286.99 6,225.97 1,617.52 1,536.58 -1,536.58 12.00 90.04 5,961,864.85 551,416.06 5 8,200.00 90.09 277.39 6,225.85 1,634.40 1,458.48 -1,458.48 12.00 -90.00 5,961,881.21 551,337.85 8,300.00 90.08 265.39 6,225.70 1,636.82 1,358.69 -1,358.69 12.00 -90.01 5,961,882.97 551,238.06 8,345.00 90.08 259.99 6,225.64 1,631.10 1,314.07 -1,314.07 12.00 -90.03 5,961,876.95 551,193.48 6 8,400.00 95.79 256.68 6,222.82 1,620.01 1,260.31 -1,260.31 12.00 -30.00 5,961,865.50 551,139.80 8,425.00 98.38 255.16 6,219.74 1,613.97 1,236.24 -1,236.24 12.00 -30.17 5,961,859.31 551,115.78 7 8,500.00 98.28 264.25 6,208.85 1,600.73 1,163.31 -1,163.31 12.00 90.00 5,961,845.58 551,042.94 8,520.00 98.21 266.68 6,205.98 1,599.16 1,143.58 -1,143.58 12.00 91.32 5,961,843.89 551,023.23 8 8,600.00 93.40 275.03 6,197.88 1,600.37 1,064.09 -1,064.09 12.00 119.60 5,961,844.57 550,943.74 8,700.00 87.30 285.37 6,197.26 1,618.05 965.86 -965.86 12.00 120.45 5,961,861.59 550,845.40 8,800.00 81.28 295.81 6,207.23 1,652.93 872.86 -872.86 12.00 120.51 5,961,895.85 550,752.19 8,820.00 80.11 297.93 6,210.46 1,661.85 855.26 -855.26 12.00 119.47 5,961,904.65 550,734.52 9 8,900.00 83.50 288.85 6,221.89 1,693.22 782.66 -782.66 12.00 -70.00 5,961,935.54 550,661.73 8,995.00 87.73 278.23 6,229.17 1,715.34 690.72 -690.72 12.00 -68.70 5,961,957.04 550,569.65 10 9,000.00 88.08 277.75 6,229.35 1,716.04 685.77 -685.77 12.00 -54.00 5,961,957.71 550,564.70 9,100.00 95.13 268.03 6,226.54 1,721.08 586.12 -586.12 12.00 -53.98 5,961,962.08 550,465.03 9,110.00 95.83 267.05 6,225.58 1,720.65 576.18 -576.18 12.00 -54.26 5,961,961.59 550,455.09 11 9,200.00 91.00 276.73 6,220.20 1,723.63 486.52 -486.52 12.00 116.20 5,961,963.97 550,365.42 9,215.00 90.19 278.34 6,220.05 1,725.59 471.65 -471.65 12.00 116.78 5,961,965.84 550,350.541 12 9,300.00 90.19 268.14 6,219.76 1,730.38 386.90 -386.90 12.00 -90.00 5,961,970.06 550,265.77 9,365.00 90.18 260.34 6,219.55 1,723.86 322.28 -322.28 12.00 -90.03 5,961,963.11 550,201.201'1 13 9,400.00 90.18 264.54 6,219.44 1,719.25 287.59 -287.59 12.00 90.00 5,961,958.28 550,166.54 9,500.00 90.18 276.54 6,219.12 1,720.19 187.78 -187.78 12.00 90.01 5,961,958.55 550,066.74 9,535.00 90.17 280.74 6,219.01 1,725.44 153.19 -153.19 12.00 90.05 5,961,963.57 550,032.11 TD 3/9/2012 3:08:24PM Page 3 COMPASS 2003.16 Build 69 ConocoPhillips or its affiliates ConocoPhillips Planning Report Alaska Database: EDM Alaska Prod v16 Local Co-ordinate Reference: Well 1 E-05 Company: ConocoPhillips(Alaska)Inc. TVD Reference: Mean Sea Level Project: Kuparuk River Unit MD Reference: 1 E-05A @ 101.10ft(Nor3(69.5+31.6)) Site: Kuparuk 1E Pad North Reference: True Well: 1 E-05 Survey Calculation Method: Minimum Curvature Wellbore: 1 E-05AL1-01 Design: 1 E-05AL1-01_wp03 Targets Target Name -hit/miss target Dip Angle Dip Dir. TVD +N/-S +E/-W Northing Easting -Shape (°) (°) (ft) (ft) (ft) (ft) (ft) Latitude Longitude 1E-05AL1-01_T6 0.00 0.00 6,223.00 1,703.82 554.21 5,961,944.62 550,433.24 70°18'24.471 N 149°35'29.077 W -plan misses target center by 16.18ft at 9131.54ft MD(6223.61 TVD,1719.98 N,554.74 E) -Point 1E-05AL1-01_T5 0.00 0.00 6,230.00 1,722.32 629.34 5,961,963.62 550,508.23 70°18'24.653 N 149°35'26.886 W -plan misses target center by 1.54ft at 9056.74ft MD(6229.26 TVD,1720.97 N,629.28 E) -Point 1E-05AL1-01_T1 0.00 0.00 6,226.00 1,601.21 1,845.66 5,961,850.60 551,725.21 70°18'23.459 N 149°34'51.416 W -plan misses target center by 18.19ft at 7811.35ft MD(6238.44 TVD,1613.75 N,1841.28 E) -Point 1E-05AL1-01_T2 0.00 0.00 6,227.00 1,650.65 1,329.94 5,961,896.61 551,209.22 70°18'23.947 N 149°35'6.455 W -plan misses target center by 16.92ft at 8326.76ft MD(6225.66 TVD,1633.93 N,1332.08 E) -Point 1E-05AL1-01_T4 0.00 0.00 6,196.00 1,687.55 1,045.16 5,961,931.61 550,924.23 70°18'24.310 N 149°35'14.760 W -plan misses target center by 84.47ft at 8634.15ft MD(6196.47 TVD,1604.41 N,1030.22 E) -Point 1E-05AL1-01_Fault2 0.00 0.00 6,227.00 1,835.36 1,377.17 5,962,081.60 551,255.22 70°18'25.763 N 149°35'5.077 W -plan misses target center by 197.69ft at 8286.32ft MD(6225.72 TVD,1637.73 N,1372.34 E) -Polygon Point 1 6,227.00 1,835.36 1,377.17 5,962,081.60 551,255.22 Point2 6,227.00 1,626.54 1,346.79 5,961,872.60 551,226.23 Point 3 6,227.00 1,452.65 1,325.64 5,961,698.59 551,206.24 1E-05A West Polygon 0.00 0.00 102.00 1,839.92 842.15 5,962,082.61 550,720.23 70°18'25.809 N 149°35'20.680 W -plan misses target center by 6100.55ft at 8700.00ft MD(6197.26 TVD,1618.05 N,965.86 E) -Polygon Point 1 102.00 1,839.92 842.15 5,962,082.61 550,720.23 Point 2 102.00 1,904.59 134.49 5,962,142.57 550,012.23 Point 3 102.00 1,879.68 -182.71 5,962,115.56 549,695.23 Point4 102.00 1,621.27 -125.41 5,961,857.56 549,754.24 Point 5 102.00 1,566.32 473.30 5,961,806.59 550,353.24 Point6 102.00 1,531.88 843.12 5,961,774.61 550,723.25 Point7 102.00 1,410.48 1,660.42 5,961,658.65 551,541.26 Point8 102.00 1,508.94 2,047.11 5,961,759.67 551,927.25 Point 9 102.00 1,608.80 2,222.79 5,961,860.69 552,102.24 Point 10 102.00 1,564.31 2,296.51 5,961,816.69 552,176.25 Point 11 102.00 1,410.43 2,274.49 5,961,662.68 552,155.25 Point 12 102.00 1,364.61 2,398.20 5,961,617.69 552,279.25 Point 13 102.00 1,535.06 2,485.34 5,961,788.70 552,365.25 Point 14 102.00 1,723.54 2,415.57 5,961,976.69 552,294.24 Point 15 102.00 1,798.44 2,280.05 5,962,050.68 552,158.24 Point 16 102.00 1,764.36 1,988.79 5,962,014.67 551,867.24 Point 17 102.00 1,764.89 1,452.73 5,962,011.64 551,331.24 Point 18 102.00 1,839.92 842.15 5,962,082.61 550,720.23 1E-05AL1-01_T3 0.00 0.00 6,219.00 1,648.19 1,248.91 5,961,893.61 551,128.22 70°18'23.923 N 149°35'8.818 W -plan misses target center by 30.25ft at 8404.63ft MD(6222.34 TVD,1618.94 N,1255.82 E) -Point 1E-05AL1-01_T7 0.00 0.00 6,219.00 1,752.48 155.50 5,961,990.63 550,034.24 70°18'24.949 N 149°35'40.705 W -plan misses target center by 27.14ft at 9535.00ft MD(6219.01 TVD,1725.44 N,153.19 E) -Point 3/9/2012 3:08:24PM Page 4 COMPASS 2003.16 Build 69 ORGNAL Nor' ConocoPhillips or its affiliates ConocoPhillips Planning Report Alaska Database: EDM Alaska Prod v16 Local Co-ordinate Reference: Well 1 E-05 Company: ConocoPhillips(Alaska)Inc. TVD Reference: Mean Sea Level Project: Kuparuk River Unit MD Reference: 1E-05A @ 101.10ft(Nor3(69.5+31.6)) Site: Kuparuk 1 E Pad North Reference: True Well: 1E-05 Survey Calculation Method: Minimum Curvature Wellbore: 1 E-05AL1-01 Design: 1 E-05AL1-01_wp03 Casing Points Measured Vertical Casing Hole Depth Depth Diameter Diameter (ft) (ft) Name (") (") 2,411.60 2,104.99 13 3/8" 13-3/8 17-1/2 9,535.00 6,219.01 2-3/8" 3 3 Plan Annotations Measured Vertical Local Coordinates Depth Depth +N/-S +E/-W (ft) (ft) (ft) (ft) Comment 7,575.00 6,259.04 1,684.19 2,064.19 TIP KOP 7,730.00 6,254.08 1,633.38 1,918.55 2 7,830.00 6,234.90 1,611.15 1,823.15 3 7,920.00 6,226.29 1,600.24 1,734.37 4 8,120.00 6,225.97 1,617.52 1,536.58 5 8,345.00 6,225.64 1,631.10 1,314.07 6 8,425.00 6,219.74 1,613.97 1,236.24 7 8,520.00 6,205.98 1,599.16 1,143.58 8 8,820.00 6,210.46 1,661.85 855.26 9 8,995.00 6,229.17 1,715.34 690.72 10 9,110.00 6,225.58 1,720.65 576.18 11 9,215.00 6,220.05 1,725.59 471.65 12 9,365.00 6,219.55 1,723.86 322.28 13 1 9,535.00 6,219.01 1,725.44 153.19 TD 3/9/2012 3:08:24PM Page 5 COMPASS 2003.16 Build 69 1 I I o 0 TrN J///// \ 4 r a O 4 N W o 1 g 'N W .O W .O V oN V .8 O izi - OO • N 1 •8 0 P.-. h .0 WI o € z Y Z HS •p__ -- °1 CC $ i 2 ;11 o0 - N �k . 3 iC.?U _---- - O On 2: a .$ r o O ! 00 9 -__-_- C O 4 T O \ W _ J - - O� _ ,4_.j yOj O ff= O l• ¢� P. 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U Le) , t t \ it� )u�nos 4 w Ph- ConocoPhillips or its affiliates ConocoPhillips Travelling Cylinder Report Company: ConocoPhillips(Alaska)Inc.-Kup1 Local Co-ordinate Reference: Well 1E-05 Project: Kuparuk River Unit TVD Reference: 1E-05A @ 101.10ft(Nor3(69.5+31.6)) Reference Site: Kuparuk 1 E Pad MD Reference: 1E-05A @ 101.10ft(Nor3(69.5+31.6)) Site Error: O.00ft North Reference: True Reference Well: 1 E-05 Survey Calculation Method: Minimum Curvature Well Error: 0.00ft Output errors are at 1.00 sigma Reference Wellbore 1E-05AL1-01 Database: EDM Alaska Prod v16 Reference',Design: 1 E-05AL1-01_wp03 Offset TVD Reference: Offset Datum Reference 1E-05AL1-01_wp03 Filter type: GLOBAL FILTER APPLIED:All wellpaths within 200'+100/1000 of refer( Interpolation Method: MD Interval 25.00ft Error Model: ISCWSA Depth Range: 7,575.00 to 9,535.00ft Scan Method: Tray.Cylinder North Results Limited by: Maximum center-center distance of 1,150.34ft Error Surface: Elliptical Conic Survey Tool Program Date 3/8/2012 From To (ft) (ft) Survey(Wellbore) Tool Name Description 45.60 4,995.60 1 E-05 GyroData_9.625 casing(1 E-05) GYD-CT-CMS Gyrodata cont.casing m/s 5,014.74 6,967.53 1 E-05A MWD(8200)(1 E-05A) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 6,967.53 7,575.00 1 E-05AL1wp06(1 E-05AL1) MWD MWD-Standard 7,575.00 9,535.00 1 E-05AL1-_01_wp03(1 E-05AL1-01) MWD MWD-Standard Casing Points Measured Vertical Casing Hole Depth Depth Diameter Diameter (ft) (ft) Name (") (•) 2,411.60 2,206.09 13 3/8" 13-3/8 17-1/2 9,535.00 6,320.11 2-3/8" 3 3 CC-Min centre to center distance or covergent point,SF-min separation factor,ES-min ellipse separation 3/9/2012 11:42:52AM Page 2 of 12 COMPASS 2003.16 Build 69 ConocoPhillips or its affiliates ConocoPhillips Travelling Cylinder Report Company: ConocoPhillips(Alaska)Inc.-Kup1 Local Co-ordinate Reference: Well 1 E-05 Project: Kuparuk River Unit TVD Reference: 1E-05A @ 101.10ft(Nor3(69.5+31.6)) Reference Site: Kuparuk 1E Pad MD Reference: 1E-05A @ 101.10ft(Nor3(69.5+31.6)) Site Error: 0.00ft North Reference: True Reference Well: 1E-05 Survey Calculation Method: Minimum Curvature Well Error: 0.00ft Output errors are at 1.00 sigma Reference Wellbore 1E-05AL1-01 Database: EDM Alaska Prod v16 Reference Design: 1E-05AL1-01_wp03 Offset TVD Reference: Offset Datum Summary Reference Offset Centre to No-Go Allowable Measured Measured Centre Distance Deviation Warning Site Name Depth Depth Distance (ft) from Plan Offset Well-Wellbore-Design (ft) (ft) (ft) (ft) "Kuparuk l E Pad 1 E-102-B-Lateral-B-Lat Actual Out of range 1 E-102-D-Lateral-D-Lat Actual Out of range 1E-121-B Lateral-B-Lat Survey Out of range 1E-121-D Lateral-D-Lat Survey Out of range Kuparuk 1E Pad 1 E-03-1 E-03-1 E-03 Out of range 1 E-04-1 E-04-1 E-04 Out of range 1E-05-1 E-05-1E-05 7,698.61 7,025.00 677.16 70.18 607.08 Pass-Major Risk 1 E-05-1 E-05A-1 E-05A 7,758.84 6,200.00 1,011.19 49.91 978.65 Pass-Major Risk 1E-05-1 E-05AL1 -1 E-05AL1_wp06 7,599.98 7,600.00 0.75 0.62 0.33 Pass-Minor 1/10 1 E-05-1 E-05AL1-02-1 E-05AL1-02_wp02 8,724.95 8,725.00 1.14 2.19 -0.22 FAIL-Major Risk 1 E-05-1 E-05AL2-1 E-05AL2_wp03 7,758.84 6,200.00 1,011.19 49.90 978.65 Pass-Major Risk 1 E-05-1 E-05AL2-01 -1 E-05AL2-01_wp02 7,758.84 6,200.00 1,011.19 49.90 978.65 Pass-Major Risk 1 E-05-1 E-05AL2-02-1 E-05AL2-02_wp03 7,758.84 6,200.00 1,011.19 49.90 978.65 Pass-Major Risk 1 E-06-1 E-06-1 E-06 Out of range 1 E-07-1 E-07-1 E-07 Out of range 1E-07-1E-07A-1E-07A Out of range 1 E-07-1 E-07AL1 -1 E-07AL1 Out of range 1 E-07-1 E-07AL2-1 E-07AL2 Out of range 1E-07-1 E-07AL2-01 -1 E-07AL2-01 Out of range 1E-102-1E-102-1E-102 Out of range 1 E-102-1 E-102L1 -1 E-102L1 Out of range 1E-102-1 E-102L1 PB1 -1 E-102L1 PB1 Out of range 1 E-102-1 E-102PB1 -1 E-102PB1 Out of range 1E-102-1 E-102PB1 -Plan 1E-102 B lat(wp5.0) Out of range 1E-102-1 E-102PB2-1 E-102PB2 Out of range 1E-121-1E-121 -1E-121 Out of range 1E-121-1E-121-Plan:1 E-121 B Lat(wp06) Out of range 1E-121-1E-121L1 -1E-121L1 Out of range 1E-121-1E-121L1 -Plan 1E-121 D Lat(wp06) Out of range 1E-123-1E-123-1E-123 Out of range 1E-123-1E-123L1 -1E-123L1 Out of range 1E-123-1E-123PB1 -1E-123PB1 Out of range 1E-126-1E-126-1E-126 Out of range 1E-126-1E-126L1 -1E-126L1 Out of range 1 E-126-1 E-126L2-1E-126L2 Out of range 1E-14-1E-14-1E-14 Out of range 1E-18-1E-18-1E-18 Out of range 1E-19-1E-19-1E-19 Out of range 1 E-31 -1 E-31 -1 E-31 Out of range 1E-31 -1 E-31 PB1-1 E-31 PB1 Out of range 1 E-34-1 E-34-1 E-34 Out of range CC-Min centre to center distance or covergent point,SF-min separation factor,ES-min ellipse separation 3/9/2012 11:42:52AM Page 3 of 12 COMPASS 2003.16 Build 69 TRANSMITTAL LETTER CHECKLIST� WELL NAME !�i /L s A PTD# I Ca3S— Develo ment Service Exploratory Stratigraphic Test Non-Conventional Well • FIELD: /kU r � � (�r 1r- POOL: k-1- C� Check Box for Appropriate Letter/Paragraphs to be Included in Transmittal Letter CHECK ADD-ONS WHAT (OPTIONS) TEXT FOR APPROVAL LETTER APPLIES MULTI LATERAL The permit is for a new wellbore segment of existing well /<(2±( l �--c sA (If last two digits in Permit No. (/ /5E ,API No. 50-62.9- 2I 79- - G r API number are between 60-69) Production should continue to be reported as a function of the original API number stated above. PILOT HOLE In accordance with 20 AAC 25.005(f), all records, data and logs acquired for the pilot hole must be clearly differentiated in both well name ( PH) and API number (50- - - ) from records, data and logs acquired for well SPACING The permit is approved subject to full compliance with 20 AAC EXCEPTION 25.055. Approval to produce/inject is contingent upon issuance of a conservation order approving a spacing exception. assumes the liability of any protest to the spacing exception that may occur. DRY DITCH All dry ditch sample sets submitted to the Commission must be in SAMPLE no greater than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals through target zones. Non-Conventional Please note the following special condition of this permit: Well production or production testing of coal bed methane is not allowed for (name of well) until after (Company Name) has designed and implemented a water well testing program to provide baseline data on water quality and quantity. (Company Name) must contact the Commission to obtain advance approval of such water well testing program. Rev:9/09/2011 CD 7 aCn D O D CD D T v 0 r v CO -n v 3 o m C v °.< -, 3or 0rj3 0 .< co .o w w 3 w CO o m co `°« -. o ; v o o 03 CD •• N N N w w w w w w w w w CO N N N N N N N N N N -. CO Co V CA CJ) A w N O n r CO CO V °) CA A w N -* O CO CO V O 01 A w NUA w NV -. O CO CoOD 7 -. O .� m ' 0Cncbb ,K .r * 0boboo = D �, D00 ;00n0 b > * 0bvQQ '� 0fD *CD CD* *° C ';r" -D Z .<5 °-.- 0 = cu o b .7: ,0 _ 2 ,m _ _ 0. 0m mDCD co m m aN rN y .6 0 v To F = g3D : : 3 c7i i0 1) N a .Q3 3 3 n • ,A- 'm . ' .._ ` : . vN Co f o w CDc / Cc 0 g < < ;Don' ac va m o m _ -' v ° v• o ,o :o CT). 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