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Home My WebLink About213-032213-032: The Current Well Status was changed to EXPIR on the effective date of 3/14/2015. This change was performed by user SEM. THE STATE Atas a Olt, and Gas LASKA C'Gnservati(an COMMISSiGn 1 1. GOVERNOR SEAN PARNELL 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 Lamar Gantt CT Drilling Supervisor ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510-0360 Re: Kuparuk River Field, Kuparuk River Oil Pool, 1H-19AL1-01 ConocoPhillips Alaska, Inc. Permit No: 213-032 Surface Location: 582' FNL, 1160' FEL, SEC. 33, T12N, R10E, UM Bottomhole Location: 4616' FNL, 103' FEL, SEC. 20, T12N, R1OE, UM Dear Mr. Gantt: Enclosed is the approved application for permit to redrill the above referenced service well. The permit is for a new wellbore segment of existing well KRU 11-1-19AL1, Permit No 213-003, API 50-029-22312-60-00. 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 jjday of March, 2013. RECEIVED STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 MAR 0 7 2013 AOCCC 1 a. Type of Work: Drill �❑ , Lateral ❑✓ Redrill El Reentry ❑ 1 b. Proposed Well Class: Development - Oil ❑ Service - W'ini Single Zone ❑✓ Stratigraphic Test ❑ Development - Gas ❑ Service - Supply ❑ Multiple Zone ❑ Exploratory ❑ Service -WAG ❑ Service - Disp ❑ 1c. Specify if well is proposed for: Coalbed Gas ❑ Gas Hydrates ❑ Geothermal ❑ Shale Gas ❑ 2. Operator Name: ConocoPhillips Alaska, Inc. 5. Bond: ✓ Blanket Single Well Bond No. 59-52-180 11. Well Name and Number: 1H-19AL1-01 3. Address: P.O. Box 100360 Anchorage, AK 99510-0360 6. Proposed Depth: MD: 11400' • TVD: 6581' 12. Field/Pool(s): Kuparuk River Field Kuparuk River Oil Pool 4a. Location of Well (Governmental Section): Surface: 582' FNL, 1160' FEL, Sec. 33, T12N, R10E, UM Top of Productive Horizon: 1212' FNL, 3665' FEL, Sec. 28, T12N, R10E, UM Total Depth: 4616' FNL, 103' FEL, Sec. 20, T12N, R10E, UM 7. Property Designation (Lease Number as fe 3� ADL 25639, 25635 j �1Ln 8. Land Use Permit: 464, 2568 13. Approximate Spud Date: 3/2/2013 9. Acres in Property: 7568 14. Distance to Nearest Property: 9650 4b. Location of Well (State Base Plane Coordinates - NAD 27): Surface: x- 549187 y- 5980119 Zone- 4 10. KB Elevation above MSL: 96 feet GL Elevation above MSL: 54 feet 15. Distance to Nearest Well Open to Same Pool: 1R-02 , 1050 16. Deviated wells: Kickoff depth: 8760 ft. Maximum Hole Angle: 94.5° deg 17. Maximum Anticipated Pressures in psig (see 20 AAC 25,035) Downhole: 4200 psig • Surface: 3550 psig 18. Casing Program: Specifications Top - Setting Depth - Bottom Cement Quantity, c.f. or sacks i cluding stage data Hole Casing Weight Grade Coupling Length MD TVDSS MD TVDSS 3" 2.375" 4.7# L-80 ST-L 2885' 8515' 6474' 11400' 6581' slotted liner 19 PRESENT WELL CONDITION SUMMARY (To be completed for Redrill and Re -Entry Operations) Total Depth MD (ft): 8990 Total Depth TVD (ft): 6928 Plugs (measured) none Effective Depth MD (ft): 1 8887 Effective Depth TVD (ft): 6849 Junk (measured) none Casing Length Size Cement Volume MD TVD Conductor/Structural 79' 16" 200 sx PF C 121' 121' Surface 5303' 9.625" 1390 sx PF E, 500 sx Cl G, 5345 4270' Intermediate 44 bbls PF C Production 8935' 7" 270 sx Class G 8970' 6913' Liner Perforation Depth MD (ft): 8340-8404, 8430-8470, 8673-8693, 8706-8726 Perforation Depth TVD (ft): 6441-6488, 6507-6536, 6687-6702, 6712-6727 20. Attachments: Property Plat ❑ BOP Sketch ❑ Drilling Program ❑✓ Time v. Depth Plot ❑ Shallow Hazard Analysis ❑ Diverter Sketch ❑ Seabed Report ❑ Drilling Fluid Program ❑✓ 20 AAC 25.050 requirements ❑✓ 21. Verbal Approval: Commission Representative: Victoria Ferguson Date: 2/28/2013 22. 1 hereby certify that the foregoing is true and correct. Contact James Ohlinger @ 265-1102 Email James.J.OhlinoerCcDconocophillios.corr Printed Name Lamar Gantt Title CT Drilling Supervisor Signature fX Phon 263-41-121 Date Commission Use Only Permit to Drill Number: d. I O 3 API Number: 50- Q a9 _ a �� 2 — (Q 3 — O0 Permit Approv I Date: I I See cover letter for other requirements Conditions of approval : If box is checked, well may not be used to explore for, test, or produce coalbed methane, gas hydrates, or gas contained in shales: Other: 2 f S 7,_ �o L� (� U Samples req'd: Yes ❑ No 2 Mud log req'd: Yes ❑ No a [� H2S measures: Yes 0 No ❑ Directional svy req'd: Yes EJ No ❑ Spacing exception req'd: Yes ❑ No Inclination -only svy req'd: Yes ❑ No ❑� ACPIROVEWY HE Approved by: COMMISSIONER COMMISsiol Date: ` Form 10-401 (Revised 10/2012) This permit is valid for 24 rriokiis fro6khe date.oiapproval (20 AAC 25.005(g)) VL-r- VW I3 RECEIVED ConocoPhilli s p Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 March 6, 2013 Commissioner - State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Dear Commissioner: MAR 0 7 2013 AOGCC ConocoPhillips Alaska, Inc. hereby submits a revised application for a permit to drill an additional lateral out of the Kuparuk Well 1 H-19AL1 (PTD # 213-003) using the coiled tubing drilling rig, Nabors CDR2-AC. This application is to replace the previously submitted 1 H-19AL1-02 The work was conducted March 2, 2013. The CTD objective was to drill lateral 1 H-19AL1-01, to pick up missed footage in the Kuparuk A4 sand interval; due to the lost footage from the 1 H-19APB1, 1 H-19AL1 PB1, and 1 H- 19AL1-01 P131. Laterals 1H-19A, AP131, AL1, AL1P61, and AU-01PB1 have been drilled. The original A & C-sand perforations have been cemented off before CTD operations commence, as per submitted Sundry (312-473). Attached to this application are the following documents - Permit to Drill Application Form for 1 H-19AL1-01 - Detailed Summary of Operations - Directional Plans - Proposed Schematic If you have any questions or require additional information please contact me at 907-265-1102. Sincerely, James J. Ohlinger Coiled Tubing Drilling Engineer Kuparuk CTD Laterals NABORSALASXA 1 H-19A, 1 H-19AL1, 1 H-19AL1-01 & 1 H-19AL2 CDR, Application for Permit to Drill Document 2AC 1. Well Name and Classification...........................................................................................................2 (Requirements of 20 AAC 25.005(f) 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.....................................................................3 (Requirements of 20 AAC 25.005(c)(5))...................................................................................................................................................... 3 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.....................................................................................................................4 (Requirements of 20 AAC 25.005(c)(8))...................................................................................................................................................... 4 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...............................................................................................................5 (Requirements of 20 AAC 25.005(c)(13)).................................................................................................................................................... 5 Summaryof Operations................................................................................................................................................... 5 PressureDeployment of BHA.......................................................................................................................................... 7 LinerRunning.................................................................................................................................................................. 7 14. Disposal of Drilling Mud and Cuttings.............................................................................................7 (Requirements of 20 AAC 25.005(c)(14)).................................................................................................................................................... 7 15. Directional Plans for Intentionally Deviated Wells..........................................................................7 (Requirements of 20 AAC 25.050(b)).......................................................................................................................................................... 7 16. Quarter Mile Injection Review (for injection wells only).................................................................8 (Requirements of 20 AAC 25.402) .......--.................................................................................................................................................. 8 17. Attachments.......................................................................................................................................9 Attachment 1: Directional Plans for 1 H-19A, 1 H-19AL1, 1 H-19AL1-01 & 1 H-19AL2...................................................... 9 Attachment 2: Current Well Schematic for 1 H-19........................................................................................................... 9 Attachment 3: Proposed Well Schematic for 1 H-19A, 1 H-19AL1, 1 H-19AL1-01 & 1 H-19AL2........................................ 9 Page 1 of 9 3/6/2013 PTD Application: 1 H-19A, 1 H-19AL1, 1 H-19AL1-01 P131, 1 H-19AL1-01 & 1 H-19AL2 1. Well Name and Classification (Requirements of 20 AA 25.005(f) and 20 AA 25.005(b)) The proposed laterals described in this document are 1 H-19A, 1 H-19AL1, 1 H-19AL1-01 & 1 H-19AL2. All four of these laterals will be classified as "Service" wells. 2. Location Summary . (Requirements of 20 AA 25.005(c) (2)) This wellbore is planned to be a lateral targeting the A sand package in the Kuparuk reservoir. Location at Surface 582' FNL, 1160FEL, Sec 33, T12N, R10E, UM NAD 1927 Northings: 5,980,119 Eastings: 549,187 RKB Elevation 96 AMSL Pad Elevation 54 AMSL 1 H-19A Location at Top of Productive Horizon Ku aruk 1183' FNL, 3695' FEL, Sec 28, T12N, R10E, UM NAD 1927 Measured Depth, RKB: 8,800' Northings: 5,984,780 Eastings: 546,611 Total Vertical Depth, SS: 6,594' Location at Total Depth 4515' FNL, 171' FEL, Sec 20, T12N, R10E, UM NAD 1927 Northings: 5,986,718 Eastings: 544,838 Measured Depth, RKB: 11,500' Total Vertical Depth, SS: 1 6,580' 1 H-19AL1 Location at Top of Productive Horizon Ku aruk 1404' FNL, 3575' FEL, Sec 28, T12N, R10E, UM NAD 1927 Measured Depth, RKB: 8,515' Northings: 5,984,561 Eastings: 546,733 Total Vertical Depth, SS: 6,474' Location at Total Depth 4485' FNL, 160' FEL, Sec 20, T12N, R10E, UM NAD 1927 Northings: 5,986,748 Eastings: 544,848 Measured Depth, RKB: 11,500' Total Vertical Depth, SS: 1 6,605' 1 H-19AL1-01 PB1 Location at Top of Productive Horizon 21' FNL, 4641' FEL, Sec 28, T12N, R10E, UM Ku aruk NAD 1927 Measured Depth, RKB: 10,370' Northings: 5,985,937 Eastings: 545,655 Total Vertical Depth, SS: 6,595' Location at Total Depth 4535' FNL, 117' FEL, Sec 20, T12N, R10E, UM NAD 1927 Northings: 5,986,698 Eastings: 544,892 Measured Depth, RKB: 11,500' Total Vertical Depth, SS: 6,595' 1H-19AL1-01 Location at Top of Productive Horizon 1212' FNL, 3665' FEL, Sec 28, T12N, R10E, UM Ku aruk NAD 1927 Measured Depth, RKB: 8,760' Northings: 5,984,752 Eastings: 546,641 Total Vertical Depth SS: 6,592' Location at Total Depth 4616' FNL, 103' FEL, Sec 20, T12N, R10E, UM NAD 1927 Northings: 5,986,617 Eastings: 544,907 Measured Depth, RKB: 11,400' Total Vertical Depth, SS: 6,581' Page 2 of 9 3/6/2013 0 �EG I t PTD Application: 1 H-19A, 1 H-19AL1, 1 H-19AL1-01 PB1, 1 H-19AL1-01 & 1 H-19AL2 1 H-19AL2 Location at Top of Productive Horizon Ku aruk 1416' FNL, 3569' FEL, Sec 28, T12N, R10E, UM NAD 1927 Measured Depth, RKB: 8,495' Northings: 5,984,549 Eastings: 546,739 Total Vertical Depth, SS: 1 6,459' Location at Total Depth 3337' FNL, 4742' FEL, Sec 28, T12N, R10E, UM NAD 1927 Northings: 5,982,620 Eastings: 545,583 Measured Depth, RKB: 11,500' Total Vertical Depth, SS: 6,510' 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 4000 psi. (Using the maximum pressure in the area of 4200 psi, the maximum possible surface pressure, assuming a gas gradient of 0.1 psi/ft, would be 3550 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)) A static bottom hole pressure of 1 H-19 in October 2012 indicated a reservoir pressure of 4097 psi or 11.9 ppg equivalent mud weight. The maximum down hole pressure in the 1 H-19 pattern is at injector 1 R-26 with 4200 psi. It is not expected that reservoir pressure as high as 1 R-26 well will be encountered while drilling the 1 H-19 laterals because of offset distance and faulting. Using the 1R-26 pressure as the maximum possible in 1R- 29, the maximum possible surface pressure, assuming a gas gradient of 0.1 psi/ft, would be 3550 psi. - Potential Gas Zones (Requirements of 20 AAC 25.005 (c)(4)(b)) No specific gas zones will be drilled; however, 1 H Pad hasn't had any MI injection since early 2008. There was some MI injected into the C-sand (with some more than likely getting into the A) to the North in 1 R-26. Potential Causes of Hole Problems (Requirements of 20 AAC 25.005 (c)(4)(c)) The largest, expected risk of hole problems in the 1 H-19 laterals will be crossing a fault into a lower pressurized reservoir block and experiencing losses. 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(o, thru-tubing drilling operations need not perform additional formation integrity tests. Page 3 of 9 3/6/2013 PTD Application: 1 H-19A, 1 H-19AL1, 1 H-19AL1-01 PB1, 1 H-19AL1-01 & 1 H-19AL2 6. Casing and Cementing Program (Requirements of 20 AAC 25.005(c)(6)) New Completion Details Lateral Name Liner Top Liner Btm Liner Top Liner Btm Liner Details MD MD TVDSS TVDSS 1 H-19A 8800' 11500' 6594' 6580' 2%", 4.7#, L-80, ST-L slotted liner; aluminum billet on top. 1H-19AL1 10,370' 11500' 6595' 6605' 2'/", 4.7#, L-80, ST-L slotted liner; aluminum billet on top. 1H-19AL1-01PB1 8760' 11500' 6592' 6595' 2%", 4.7#, L-80, ST-L slotted liner; deployment sleeve on top. 1H-19AL1-01 8515' 11,400' 6474' 6581' 2'/", 4.7#, L-80, ST-L slotted liner; deployment sleeve on top. 1 H-19AL2 8495' 11500' 6459' 6510' 23/", 4.7#, L-80, ST-L slotted liner; de to ment sleeve on top. Existing Casing/Liner Information Category OD Weight (ppf)MD Grade Connection Top Btm MD Top TVD Btm TVD Burst psipsi Collapse Conductor 16" 62.55 H-40 Welded 42' 121' 0' 121' 1640 630 Surface 9-5/8" 40 L-80 BTC 42' 5345' 0' 4270' 5750 3090 Casing 7" 26.0 J-55 AB -Mod 35' 8970' 0' 6913' 4980 4330 Tubing 3-1/2 " 9.3 J-55 ABM-EUE 38' 8560' 0' 6603' 6990 7400 Tubing 2-7/8 " 6.5 NA NA 1 8560' 8600' 6603' 6632' 7260 7680 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. 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 Flo -Pro FloVis mud (9.6 ppg) — Drilling operations: Chloride -based Flo -Pro FloVis mud (9.6 ppg). While this mud weight may not hydrostatically overbalance the reservoir pressure, overbalanced conditions will be maintained using MPD practices described below. — Completion operations: 1 H-19 does not contain a subsurface safety valve (SSSV). 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 (-200 bbl) of 13.1 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. Page 4 of 9 3/6/2013 ._Ii~el��l cmrtlg, PTD Application: 1 H-19A, 1 H-19AL1, 1 H-19AL1-01 P131, 1 H-19AL1-01 & 1 H-19AL2 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. Since this well is proposed as an infield development candidate in an actively water flooded field, expected reservoir pressures can be difficult to estimate. In this case, however, a constant BHP of 12.0 ppg will be initially targeted at the window based on the recent static bottom hole pressure. 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. 13. Proposed Drilling Program (Requirements of 20 AAC 25.005(c)(13)) Summary of Operations Background Well 1 H-19 is a Kuparuk A-sand/C-sand injection well equipped with 3'/2" tubing and 7" production casing with the C-sand behind a straddled selective. Three proposed A -sand CTD laterals will increase reservoir exposure in two adjoining fault blocks. Prior to drilling, the existing C-sand perfs in 1 H-19 will be plugged with cement to provide a means to kick out of the 3-1/2" and 7" casing. The existing A -sand perfs will be plugged off with a CA-2 plug in the tubing tail, then covered with cement when the C-sands are cemented. The well is currently an injector, however the injection point will be moved to —250' from the upper packer, once the C-sands are cemented and the windows are milled. The 3-1/2" tubing in the C-sand selective straddle will be perforated in two intervals to allow cement in the 3-1/2" by 7" annulus. The intervals will be at the whipstock setting locations with 10' of perforations. After plugging off the existing A & C-sand perfs with cement, mechanical whipstocks will be placed in the 3-1/2" tubing at the planned kickoff points. The 1 H-19A sidetrack will exit through the 3-1/2" tubing and 7" casing at 8,515' MD and will target the A4 sand west of the existing well with a 2985' lateral. The hole will be completed with a 2 %" slotted liner to the TD of 11,500' MD with an aluminum billet at 8,800' MD. The 1H-19AL1 lateral will kick off from the aluminum billet at 8,800' MD and will target the A3 sand west of the existing well with a 2700' lateral. The hole will be completed with a 2%" slotted liner to the TD of 11,500' MD with an aluminum billet at 10,370' MD. Page 5 of 9 3/6/2013 PTD Application: I H-19A, 1 H-19AL1, 1 H-19AL1-01 P131, 1 H-19AL1-01 & 1 H-19AL2 1H-19ALl-OIPB1 lateral will kickoff from an aluminum billet at 11,370' MD and will target the A3 sand west of the existing well with a 1130' lateral. The hole will be completed with a 2%" slotted liner to the TD of 11,500' MD with an aluminum billet at 8,760' MD. 1H-19AL1-01 lateral will kickoff from an aluminum billet at 8,760' MD and will target the A4 sand west of the existing well with a 2640' lateral. The hole will be completed with a 2%" slotted liner to the TD of 11,400' MD with the liner top located inside the 3'/2" tubing at 8,510' MD. The 1H1-9AL2 sidetrack will exit through the 3-1/2" tubing and 7" casing at 8,495' MD and will target the A4 sand south of the existing well with a 2805' lateral. The hole will be completed with a 2%" slotted liner to the TD of 11,500' MD with the final liner top located inside the 3'V2" tubing at 8,490' MD. Pre -Rig Work (Asper submitted Sundry) 1. Positive pressure and drawdown tests on MV and SV. 2. Test Packoffs — T & IC. 3. MIT -IA 4. RU slickline. Tag fill, drift dummy whipstock 5. RU Eline: GR/CCL/CBL Logs for jewelry correlation and bond log 6. RU Eline: Perforate tubing at 8,510' and 8,490' RKB 7. RU slickline. Set CA-2 plug in tubing tail nipple, set BPC sleeve in the AVA BPL nipple 8. RU coil: Place cement in the 3-1/2" tubing from the CA-2 up to—8,490' and in the annulus of the C-sand straddle 9. RU slickline. Tag top of cement and pressure test. RD slickline. 10. RU coil: Mill out cement in the 3-1/2" tubing down to the BPC sleeve in the AVA BPL nipple 11. Prep site for Nabors CDR2-AC, including setting BPV Rig Work 1. MIRU Nabors CDR2-AC rig using 2" coil tubing. NU 7-1/16" BOPE, test. 2. 1H-19A Sidetrack (A4 sand, west) a. Set whipstock at 8,515' MD b. Mill 2.80" window at 8,515' MD. c. Drill 2.70" x 3.25" bi-center lateral to TD of 11,500' MD d. Run 2%" slotted liner with an aluminum billet from TD up to 8,800' MD 3. 1H-19AL1 Lateral (A3 sand, west) a. Kickoff of the aluminum billet at 8,800' MD b. Drill 2.70" x 3.25" bi-center lateral to TD of 11,500' MD c. Run 2%" slotted liner with an aluminum billet from TD up to 10,370' MD 4. 1H-19AL1-01PB1 Lateral (A3 sand, west) a. Kick off of the aluminum billet at 10,370' MD b. Drill 2.70" x 3.25" bi-center lateral to TD of 11,500' MD c. Run 2%" slotted liner with an aluminum billet from TD up to 8,760' MD 5. 1H-19AL1-01 Lateral (A4 sand, west) a. Kick off of the aluminum billet at 8,760' MD b. Drill 2.70" x 3.25" bi-center lateral to TD of 11,400' MD c. Run 2%" slotted liner from TD up to 8,510' MD, inside the 3'/2" tubing tail 6. 1H-19AL2 Lateral (A4 sand, south) a. Set whipstock at 8,495' MD b. Mill 2.80" window at 8,495' MD. c. Drill 2.70" x 3.0" bi-center lateral to TD of 11,500' MD d. Run 2%" slotted liner from TD up to 8,490' MD, inside the 3'/2" tubing tail 7. Freeze protect. Set BPV, ND BOPE. RDMO Nabors CRD2-AC. Page 6 of 9 3/6/2013 PTD Application: 1 H-19A, 1 H-19AL1, 1 H-19AL1-01 PB1, 1 H-19AL1-01 & 1 H-19AL2 Post -Rig Work 1. Pull BPV 2. Obtain static BHP. Install GLV's. 3. Return to pre -production before injection 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 — The 1 H-19 CTD laterals will be displaced to an overbalancing fluid (12 ppg Na-Br) 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. 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 1 R 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 Plan — 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. Page 7 of 9 3/6/2013 PTD Application: 1 H-19A, 1 H-19AL1, 1 H-19AL1-01 PB1, 1 H-19AL1-01 & 1 H-19AL2 — Distance to Nearest Property Line (measured to KPA boundary at closest point) Lateral Name Distance 1 H-19A 9750' 1 H-19AL1 9760' 1 H-19AL1-01 PB1 10824' 1 H-19AL1-01 9650' 1 H-19AL2 9710' — Distance to Nearest Well within Pool (toe measured to offset well) Lateral Name Distance Well 1 H-19A 1150' 1 R-02 1 H-19AL1 1100, 1 R-02 1 H-19AL1-01 PB1 1214' 1 R-02 1 H-19AL1-01 1050' 1 R-02 1 H-19AL2 1100, 1 H-03 16. Quarter Mile Injection Review (for injection wells only) (Requirements of 20 AAC 25.402) The only wells that lie within %<-mile of the proposed 1 H-19 CTD laterals are the 1 H-19 motherbore and 1 R-02. The casing and cementing of 1 H-19 is described below. The A & C-sand perforations will be permanently plugged as part of this CTD sidetrack proposal. See the attached schematic for clarification. 1 H-19 Mother Bore Well 1 H-19 was drilled and completed in 1993. The 7", 26 ppf, J-55, BTC-Mod production casing was set at 8,970' MD in the Miluveach. 1 H-19 is a Service well with a "Normal Well" Ann -Comm status, was capable of injecting to both of the Kuparuk A & C sands with a straddle completion. The C-sand will be cemented off during the pre -rig procedures (Sundry # 312-473). 1 R-29 Well 1 R-29 (PTD #191-094) was drilled and completed in 1991. The 7", 26 ppf, J-55, BTC-Mod production casing was set at 11,331' MD in the Miluveach. 1 R-29 was a Production well with a "Normal Well" Ann -Comm status, capable of producing both of the Kuparuk A & C sands with a straddle completion. It has recently been sidetracked in the Kuparuk A sand with Coiled Tubing Drilling. The original C-sand is still accessible via the selective straddle completion. The original A -sand was cemented off, and is now accessed by the 4 laterals that were completed with 2-3/8" 4.7ppf L-80 slotted liner. The 1 H-19 to 1 R-29 Center to Center distance is roughly 1270 feet; the 1 H-19 laterals will be the injector offset to the 1 R-29 production laterals. 1 R-02 Well 1 R-02 (PTD #185-176) was drilled and completed in 1985. The 7", 26 ppf, J-55, BTC-Mod production casing was set at 9,291' MD in the Miluveach. 1 R-02 is a Production well with a "Normal Well" Ann -Comm status, capable of producing both of the Kuparuk A & C sands with a straddle completion. The last SBHP for the A sand was 2261 psi in Sept. '11, and the C sand measured 2485 psi. 1 H-03 Well 1 H-03 (PTD #182-115) was drilled and completed in 1982. The 7", 26 ppf, J-55, BTC-Mod production casing was set at 8,141' MD in the Miluveach. 1 H-03 is a Service well with a "Normal Well" Ann -Comm status, and capable of injecting to both of the Kuparuk A & C sands with a straddle completion. The well will be shut-in prior (4 weeks) to CDR2-AC arrival to 1 H-19. The last SBHP measured 3970 psi (12.1 ppg EMW) on Oct. '12. Page 8 of 9� �+, 3/6/2013 PTD Application: 1 H-19A, 1 H-19AL1, 1 H-19AL1-01 PB1, 1 H-19AL1-01 & 1 H-19AL2 17. Attachments Attachment 1: Directional Plans for 1H-19A, 1H-19AL1, 1H-19AL1-01PB1, 1H-19AL1-01 & 1H- 19AL2 Attachment 2: Current Well Schematic for 1H-19 Attachment 3: Proposed Well Schematic for 1H-19A, 1H-19AL1, 1H-19AL1-01PB1, 1H-19AL1- 01 & 1H-19AL2 Page 9 of 9 �`� 3/6/2013 OD _ N _ O m @ a m a 0 co P p rn v 0 a>i m h �¢ as v N ONO � .�+ (0 04 Ssio p �`i0N�a OD V� C E c N mO,ro m N - @ m E ea' o v N om CO [i m o a� Q Mco E a) � S o a5 L n« Q Z> e>CD 2 h A) m m 'O p NYC G N M o U d O) U fl- N U N N Cl)E N E w Q M aEn of U �s U W Q (m7-UN (V fV N N (V fV N Y Y 3 M 07 _._ UO m co r) m mn ca m N O Q � � � o JQ- 1 jtOOOcl ag o� S� g co co m �n d ap _ m Y 0 ¢ 0m J ? Q M rn�c �W r V 'N N N 0 00 N Q NCL y 0 JM N Da00 N p ,tom 0 0 to CIL c d� N 10 N r rn0 O G O" m 'O 'ct N 4t S� p C r fO0 Q'vm f) Q-00 0 Nn m N U m U m CD (a) 4 i , ConocoPhillips Alaska ConocoPhillips(Alaska) Inc. Kuparuk River Unit Kuparuk 1 H Pad 1 H-19 1 H-19AL1-01 Plan: 1 H-19AL1-01_wp02 Standard Planning Report 01 March, 2013 we P JA ill BAKER HUGNES ConocoPhillips Alaska Database: EDM Alaska Prod v16 Company: ConocoPhillips(Alaska) Inc. Project: Kuparuk River Unit Site: Kuparuk 1H Pad Well: 1H-19 Wellbore: 1 H-19AL1-01 Design: 1H-19AL1-01_wp02 ConocoPhillips or its affiliates Planning Report Local Co-ordinate Reference: Well 1 H-19 TVD Reference: Mean Sea Level MD Reference: 1 H-19 @ 96.00ft (1 H-19) North Reference: True Survey Calculation Method: Minimum Curvature 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 BAKER • HUGHES Site Kuparuk 1 H Pad Site Position: Northing: 5,979,968.84ft Latitude: 70° 21' 21.831 N From: Map Easting: 549,197.16ft Longitude: 149° 36' 1.675 W Position Uncertainty: 0.00 ft Slot Radius: Grid Convergence: 0.38 ° Well 1H-19 Well Position +N/-S 0.00 ft Northing: 5,980,118.88 ft Latitude: 70° 21' 23.308 N +E/-W 0.00 ft Easting: 549,186.59 ft Longitude: 149° 361.955 W Position Uncertainty 0.00 ft Wellhead Elevation: ft Ground Level: 0.00ft Wellbore 11-1-19AL1-02 Magnetics Model Name Sample Date Declination Dip Angle Field Strength V) (°) (nT) BG G M2011 12/31 /2012 16.03 79.99 57,387 Design 1H-19AL1-01_wp02 Audit Notes: Version: Phase: PLAN Tie On Depth: 8,740.47 Vertical Section: Depth From (TVD) +N/-S +E/-W Direction (ft) (ft) (ft) (I 0.00 0.00 0.00 315.00 31112013 2:07:28PM Page 2 COMPASS 2003.16 Build 69 ✓ ConocoPhillips or its affiliates .&A.■ ConocoPhillips Planning Report BAKER Alaska HUGHES Database: EDM Alaska Prod v16 Company: ConocoPhillips(Alaska) Inc. Project: Kuparuk River Unit Site: Kuparuk 1 H Pad Well: 11-1-19 Wellbore: 1 H-19AL1-01 Design: 1 H-19AL1-01_wp02 Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Well 1 H-19 Mean Sea Level 1 H-19 @ 96.00ft (1 H-19) True Minimum Curvature Plan Sections Measured TVD Below Dogleg Build Turn Depth Inclination Azimuth System +N/-S +E/-W Rate Rate Rate TFO (ft) (°) (°) (ft) (ft) (ft) (°/100ft) (°/100ft) (°1100ft) (°) Target 8,740.47 64.14 326.77 6,584.09 4,635.55 -2,505.36 0.00 0.00 0.00 0.00 8,760.00 67.53 325.74 6,592.08 4,650.36 -2,515.26 18.01 17.36 -5.27 -15.71 8,790.00 74.02 332.35 6,601.97 4,674.64 -2,529.78 30.00 21.64 22.02 45.00 8,865.00 94.54 341.68 6,609.42 4,742.94 -2,558.63 30.00 27.35 12.45 25.00 8,965.00 93.93 311.61 6,601.87 4,825.27 -2,612.84 30.00 -0.61 -30.08 270.00 9,065.00 90.47 302.21 6,598.02 4,885.20 -2,692.64 10.00 -3.46 -9.39 250.00 9,215.00 92.52 317.08 6,594.08 4,980.60 -2,807.78 10.00 1.37 9.91 82.00 9,390.00 91.50 334.56 6,587.90 5,124.72 -2,905.64 10.00 -0.58 9.99 93.00 9,490.00 88.08 343.96 6,588.27 5,218.12 -2,941.01 10.00 -3.43 9.40 110.00 9,615.00 90.06 331.61 6,590.31 5,333.60 -2,988.17 10.00 1.59 -9.87 279.00 9,815.00 89.72 311.62 6,590.70 5,489.57 -3,111.73 10.00 -0.17 -10.00 269.00 9,965.00 92.81 326.30 6,587.38 5,602.35 -3,209.92 10.00 2.06 9.79 78.00 10,090.00 93.82 313.82 6,580.12 5,697.84 -3,289.87 10.00 0.81 -9.98 275.00 10,340.00 88.85 338.34 6,574.19 5,903.62 -3.428.20 10.00 -1.99 9.81 101.00 10,540.00 88.92 318.33 6,578.11 6,072.95 -3,532.64 10.00 0.03 -10.00 270.00 10,665.00 91.53 306.10 6,577.62 6,156.78 -3,625.03 10.00 2.08 -9.78 282.00 10,915.00 91.38 281.10 6,571.17 6,256.04 -3,852.23 10.00 -0.06 -10.00 270.00 11,065.00 88.25 295.77 6,571.65 6,303.33 -3,994.13 10.00 -2.09 9.78 102.00 11,400.00 88.54 329.28 6,581.29 6,526.46 -4,237.41 10.00 0.09 10.00 90.00 31112013 2:07:28PM Page 3 COMPASS 2003.16 Build 69 0 Rvt� I F I N! !\� L ConocoPhillips or its affiliates Fel.. ConocoPhillips Planning Report BAILER Aaska HUGHES Database: EDM Alaska Prod v16 Company: ConocoPhillips(Alaska) Inc. Project: Kuparuk River Unit Site: Kuparuk 1 H Pad Well: 11-1-19 Wellbore: 1 H-19AL1-01 Design: 1 H-19AL1-01_wp02 Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Well 1H-19 Mean Sea Level 1 H-19 @ 96.00ft (1 H-19) True Minimum Curvature Planned Survey Measured TVD Below Vertical Dogleg Toolface Map Map Depth Inclination Azimuth System +Nl-S +El-W Section Rate Azimuth Northing Easting (ft) (°) (°) (ft) (ft) (ft) (ft) (°/100ft) (°) (ft) (ft) 8,740.47 64.14 326.77 6,584.09 4,635.55 -2,505.36 5,049.38 0.00 0.00 5,984,737.43 546,651.09 TIP 8,760.00 67.53 325.74 6,592.08 4,650.36 -2,515.26 5,066.86 18.01 -15.71 5,984,752.17 546,641.10 KOP 8,790.00 74.02 332.35 6,601.97 4,674.64 -2,529.78 5,094.30 30.00 45.00 5,984,776.36 546,626.42 Start 30 dls 8,800,00 76.74 333.65 6,604.49 4,683.26 -2,534.17 5,103.50 30.00 25.00 5,984,784.95 546,621.97 8,865.00 94.54 341.68 6,609.42 4,742.94 -2,558.63 5,162.99 30.00 24.67 5,984,844.46 546,597.12 4 8,900.00 94.46 331.15 6,606.67 4,774.87 -2,572.57 5,195.43 30.00 -90.00 5,984,876.30 546,582.97 8,965.00 93.93 311.61 6,601.87 4,825.27 -2,612.84 5,259.54 30.00 -90.83 5,984,926.42 546,542.38 5 9,000.00 92.73 308.31 6,599.83 4,847.71 -2,639.62 5,294.34 10.00 -110.00 5,984,948.68 546,515.46 9,065.00 90.47 302.21 6,598.02 4,885.20 -2,692.64 5,358.34 10.00 -110.19 5,984,985.82 546,462.19 Start 10 dls 9,100.00 90.96 305.68 6,597.58 4,904.74 -2,721.67 5,392.69 10.00 82.00 5,985,005.17 546,433.04 9,200.00 92.32 315.59 6,594.72 4,969.75 -2,797.43 5,492.23 10.00 82.04 5,985,069.68 546,356.86 9,215.00 92.52 317.08 6,594.08 4,980.60 -2,807.78 5,507.21 10.00 82.33 5,985,080.45 546,346.45 7 9,300.00 92.05 325.57 6,590.69 5,046.84 -2,860.80 5,591.55 10.00 93.00 5,985,146.34 546,292.99 9,390.00 91.50 334.56 6,587.90 5,124.72 -2,905.64 5,678.32 10.00 93.34 5,985,223.92 546,247.65 8 9,400.00 91.16 335.50 6,587.67 5,133.78 -2,909.86 5,687.72 10.00 110.00 5,985,232.95 546,243.37 9,490.00 88.08 343.96 6,588.27 5,218.12 -2,941.01 5,769.38 10.00 110.02 5,985,317.07 546,211.67 9 9,500.00 88.23 342.97 6,588.59 5,227.70 -2,943.85 5,778.16 10.00 -81.00 5,985,326.63 546,208.76 9,600.00 89.82 333.09 6,590.29 5,320,31 -2,981.21 5,870.06 10.00 -80.97 5,985,418.98 546,170.80 9,615.00 90.06 331.61 6,590.31 5,333.60 -2,988.17 5,884.38 10.00 -80.80 5,985,432.22 546,163.76 10 9,700.00 89.91 323.12 6,590.33 5,405.11 -3,033.97 5,967.33 10.00 -91.00 5,985,503.43 546,117.49 9,800.00 89.74 313.12 6,590.63 5,479.47 -3,100.65 6,067.06 10.00 -91.00 5,985,577.34 546,050.34 9,815.00 89.72 311.62 6,590.70 5,489.57 -3,111.73 6,082.04 10.00 -90.97 5,985,587.37 546,039.19 11 9,900.00 91.48 319.93 6,589.81 5,550.43 -3,170.96 6,166.95 10.00 78.00 5,985,647.83 545,979.57 9,965.00 92.81 326.30 6,587.38 5,602.35 -3,209.92 6,231.22 10.00 78.09 5,985,699.49 545,940.27 12 10,000.00 93.11 322.81 6,585.57 5,630.82 -3,230.19 6,265.68 10.00 -85.00 5,985,727.83 545,919.81 10,090.00 93.82 313.82 6,580.12 5,697.84 -3,289.87 6,355.27 10.00 -85.18 5,985,794.45 545,859.70 13 10,100.00 93.63 314.80 6,579.47 5,704,81 -3,297.01 6,365.25 10.00 101.00 5,985,801.37 545,852.52 10,200.00 91.67 324.62 6,574.83 5,780.92 -3,361.52 6,464.68 10.00 101.06 5,985,877.04 545,787.52 10,300.00 89.66 334.42 6,573.67 5,866.99 -3,412.17 6,561.36 10.00 101.52 5,985,962.76 545,736.30 10,340.00 88.85 338.34 6,574.19 5,903.62 -3,428.20 6,598.59 10.00 101.63 5,985,999.29 545,720.04 14 10,400.00 88.86 332.33 6,575.39 5,958.11 -3,453.22 6,654.82 10.00 -90.00 5,986,053.61 545,694.66 10,500.00 88.90 322.33 6,577.35 6,042.17 -3,507.12 6,752.37 10.00 -89.88 5,986,137.31 545,640.22 10,540.00 88.92 318.33 6,578.11 6,072.95 -3,532.64 6,792.18 10.00 -89.68 5,986,167.91 545,614.50 15 10,600.00 90.17 312.46 6,578.59 6,115.65 -3,574.75 6,852.15 10.00 -78.00 5,986,210.33 545,572.11 10,665.00 91.53 306.10 6,577.62 6,156.78 -3,625.03 6,916.78 10.00 -77.95 5,986,251.13 545,521.57 16 10,700.00 91.52 302.60 6,576.69 6,176.52 -3,653.91 6,951.16 10.00 -90.00 5,986,270.67 545,492.56 31112013 2:07:28PM Page 4� COMPASS 2003.16 Build 69 ConocoPhillips or its affiliates rigs ConocoPhillips Planning Report Alaska MIXER HES Database: EDM Alaska Prod v16 Company: ConocoPhillips(Alaska) Inc. Project: Kuparuk River Unit Site: Kuparuk I Pad Well: 1H-19 Wellbore: 1 H-19AL1-01 Design: 1H-19AL1-01_wp02 Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Well 1 H-19 Mean Sea Level 1 H-19 @ 96.00ft (1 H-19) True Minimum Curvature Planned Survey Measured TVD Below Vertical Dogleg Toolface Map Map Depth Inclination Azimuth System +N/S +E/-W Section Rate Azimuth Northing Easting (ft) (°) (°) (ft) (ft) (ft) (ft) (°/100ft) (°) (ft) (ft) 10,800.00 91.48 292.60 6,574.06 6,222.78 -3,742.39 7,046.43 10.00 -90.09 5,986,316.35 545,403.79 10,900.00 91.40 282.60 6,571.54 6,252.96 -3,837.55 7,135.07 10.00 -90.36 5,986,345.90 545,308.44 10,915.00 91.38 281.10 6,571.17 6,256.04 -3,852.23 7,147.63 10.00 -90.61 5,986,348.89 545,293.74 17 11,000.00 89.61 289.41 6,570.44 6,278.38 -3,934.16 7,221.36 10.00 102.00 5,986,370.69 545,211.68 11,065.00 88.25 295.77 6,571.65 6,303.33 -3,994.13 7,281.40 10.00 102.07 5,986,395.24 545,151.55 18 11,100.00 88.26 299.27 6,572.72 6,319.49 -4,025.15 7,314.77 10.00 90.00 5,986,411.20 545,120.43 11,200.00 88.30 309.27 6,575.73 6,375.71 -4,107.64 7,412.85 10.00 89.89 5,986,466.86 545,037.57 11,300.00 88.40 319.28 6,578.62 6,445.40 -4,179.12 7,512.67 10.00 89.59 5,986,536.08 544,965.65 11,400.00 88.54 329.28 6,581.29 6,526.46 -4,237.41 7,611.20 10.00 89.30 5,986,616.74 544,906.84 TD at 11400.00 31112013 2:07:28PM Page 5 COMPASS 2003.16 Build 69 ✓ ConocoPhillips or its affiliates rel.. ConocoPhillips Planning Report gpR Alaska HUGHES Database: EDM Alaska Prod v16 Company: ConocoPhillips(Alaska) Inc. Project: Kuparuk River Unit Site: Kuparuk1HPad Well: 1H-19 Wellbore: 1 H-19AL1-01 Design: 1 H-19AL1-01_wp02 Targets Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Well 1 H-19 Mean Sea Level 1H-19 @ 96.00ft (11-1-19) True Minimum Curvature Target Name hit/miss target Dip Angle Dip Dir. TVD +N/-S +E/-W Northing Easting Shape V) (I (ft) (ft) (ft) (ft) (ft) Latitude Longitude 1 H-19AL1-02_T7 0.00 0.00 6,572.00 5,773.76-3,474.64 5,985,869.14 545,674.46 70° 22' 20.084 N 149° 37' 43.609 W plan misses target center by 99.00ft at 10251.31ft MD (6573.80 TVD, 5823.99 N,-3389.35 E) Point 11-1-19 CTD Polygon_So 0.00 0.00 0.00 5,498.84-3,946.50 5,985,591.16 545,204.45 70' 22' 17.378 N 149° 37' 57.410 W - plan misses target center by 6605.62ft at 10300.00ft MD (6573.67 TVD, 5866.99 N,-3412.17 E) - Polygon Point 1 0.00 5,498.84-3,946.50 5,985,591.16 545,204.45 Point 0.00 4,756.24-3,100.24 5,984,854.20 546,055.49 Point 3 0.00 2,257.57-3,503.56 5,982,353.18 545,668.62 Point 4 0.00 2,270.54-3,958.53 5,982,363.16 545,213.62 Point 5 0.00 5,498.84-3,946.50 5,985,591.16 545,204.45 1H-19AL1-02_T10 0.00 0.00 6,580.00 6,465.76-4,224.18 5,986,556.14 544,920.46 70' 22' 26.886 N 149° 38' 5.549 W plan misses target center by 49.47ft at 11300.00ft MD (6578.62 TVD, 6445.40 N,-4179.12 E) Point 1H-19 CTD Polygon_No 0.00 0.00 0.00 6,817.08-4,266.88 5,986,907.13 544,875.46 70° 22' 30.341 N 149' 38' 6.804 W - plan misses target center by 6587.77ft at 11400.00ft MD (6581.29 TVD, 6526.46 N,-4237.41 E) - Polygon Point 1 0.00 6,817.08-4,266.88 5,986,907.13 544,875.46 Point 2 0.00 5,035.68-2,242.24 5,985,139.24 546,911.55 Point 3 0.00 4,229.82-2,432.52 5,984,332.23 546,726.59 Point4 0.00 5,043.41-3,428.33 5,985,139.18 545,725.55 Point 5 0.00 6,132.02-4,577.38 5,986,220.12 544,569.49 Point 0.00 6,817.08-4,266.88 5,986,907.13 544,875.46 1 H-19A_Fault6 (copy) (c 0.00 0.00 0.00 5,490.26-3,098.45 5,985,588.14 546,052.46 70' 22' 17.297 N 149° 37' 32.600 W plan misses target center by 6585.74ft at 10113.74ft MD (6578.63 TVD, 5714.59 N,-3306.62 E) Rectangle (sides W1,000.00 H1.00 D0.00) 1H-19A_FaultB (copy) (c 0.00 0.00 0.00 5,684.09-3,374.21 5,985,780.14 545,775.46 70' 22' 19.203 N 149' 37' 40.670 W plan misses target center by 6575.56ft at 10200.00ft MD (6574.83 TVD, 5780.92 N,-3361.52 E) Rectangle (sides W1,000.00 H1.00 D0.00) 1H-19AL1-02_Ti (copy) 0.00 0.00 6,600.00 4,813.46-2,682.86 5,984,914.15 546,472.45 70' 22' 10.643 N 149' 37' 20.435 W plan misses target center by 53.56ft at 9015.53ft MD (6599.17 TVD, 4857.17 N,-2651.91 E) Point 1H-19A_Faultl (copy) (c 0.00 0.00 0.00 9,066.24-4,104.07 5,989,157.09 545,023.48 70° 22' 52.462 N 149° 38' 2.077 W plan misses target center by 7055.61ft at 11400.00ft MD (6581.29 TVD, 6526.46 N,-4237.41 E) Polygon Point 1 0.00 9,066.24-4,104.07 5,989,157.09 545,023.48 Point 0.00 6,724.80-4,232.34 5,986,815.09 544,910.60 Point 0.00 9,066.24-4,104.07 5,989,157.09 545,023.48 1H-19A_FaultD (copy) (c 0.00 0.00 0.00 6,262.26-4,150.51 5,986,353.15 544,995.46 70° 22' 24.885 N 1490 38' 3.390 W plan misses target center by 6573.64ft at 11065.O0ft MD (6571.65 TVD, 6303.33 N,-3994.13 E) Rectangle (sides W1,000.00 1-11.00 D0.00) 1H-19A_FaultC (copy) (c 0.00 0.00 0.00 6,133.02-3,964.34 5,986,225.15 545,182.46 70° 22' 23.615 N 1490 37' 57.941 W plan misses target center by 6572.11ft at 11000.00ft MD (6570.44 TVD, 6278.38 N,-3934.16 E) Rectangle (sides W1,000.00 H1.00 D0.00) 1 H-19AL1-02_T6 0.00 0.00 6,592.00 5,494.95-3,202.44 5,985,592.15 545,948.46 70° 22' 17.343 N 1490 37' 35.642 W plan misses target center by 60.26ft at 9882.16ft MD (6590.22 TVD, 5536.96 N,-3159.27 E) Point 1 H-19A_FaultA (copy) (c 0.00 0.00 0.00 5,044.09-2,827.21 5,985,143.81 546,326.60 70' 22' 12.910 N 149° 37' 24.660 W plan misses target center by 6588.79ft at 9400.00ft MD (6587.67 TVD, 5133.78 N,-2909.86 E) Rectangle (sides W1,000.00 1-11.00 D0.00) 1H-19AL1-02_T9 0.00 0.00 6,570.00 6,175.06-3,970.06 5,986,267A4 545,176.46 70° 22' 24.028 N 149' 37' 58.109 W - Ian misses target center by 109.38ft at 11000.00ft MD 6570.44 TVD, 6278.38 N,-3934.16 E) 31112013 2:07:28PM Page 6 COMPASS 2003.16 Build 69 ✓ ConocoPhillips or its affiliates rS.. ConocoPhillips Planning Report BAKER Alaska HUGHES Database: EDM Alaska Prod v16 Company: ConocoPhillips(Alaska) Inc. Project: Kuparuk River Unit Site: Kuparuk 1 H Pad Well: 11-1-19 Weflbore: 1 H-19AL1-01 Design: 1H-19AL1-01_wp02 Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Well 1H-19 Mean Sea Level 1 H-19 @ 96.00ft (1 H-19) True Minimum Curvature ,- Point 1 H-1 9AL1 -02_T3 (copy) 0.00 0.00 6,585.00 5,107.58-3,000.96 5,985,206.15 546,152.46 70' 22' 13.534 N 149' 37' 29.743 W plan misses target center by 94.09ft at 9406.97ft MD (6587.54 TVD, 5140.14 N,-2912.71 E) Point 1H-19AL1-02_T2 (copy) 0.00 0.00 6,592.00 4,976.10-2,929.81 5,985,075.15 546,224.45 70' 22' 12.241 N 149' 37' 27.661 W plan misses target center by 97.32ft at 9287.84ft MD (6591.13 TVD, 5036.89 N,-2853.82 E) Point 1H-19AL1-02_T4 (copy) 0.00 0.00 6,590.00 5,251.82-3,035.01 5,985,350.15 546,117.46 70° 22' 14.953 N 1490 37' 30.741 W plan misses target center by 77.63ft at 9556.56ft MD (6589.89 TVD, 5280.87 N,-2963.02 E) Point 1H-19AL1-02_T8 0.00 0.00 6,580.00 6,039.63-3,602.91 5,986,134.14 545,544.46 70° 22' 22.698 N 149' 37' 47.365 W plan misses target center by 74.19ft at 10565.64ft MD (6578.47 TVD, 6091.73 N,-3550.10 E) Point 11-1-19AL1-02_T5 0.00 0.00 6,590.00 5,426.46-3,129.88 5,985,524.15 546,021.46 70' 22' 16.670 N 149' 37' 33.519 W plan misses target center by 58.55ft at 9780.03ft MD (6590.55 TVD, 5465.56 N,-3086.31 E) Point Casing Points Measured Vertical Casing Hole Depth Depth Diameter Diameter (ft) (ft) Name (') (") 5,345.00 4,174.22 9 5/8" 9-5/8 12-1/4 11,400.00 6,581.29 2 3/8" 2-3/8 3 Formations Measured Vertical Dip Depth Depth Dip Direction (ft) (ft) Name Lithology (I V) 8,812.54 6,607.00 Formation 2 0.00 Plan Annotations Measured Vertical Local Coordinates Depth Depth +N/-S +E/-W (ft) (ft) (ft) (ft) Comment 8,740.47 6,584.09 4,635.55 -2,505.36 TIP 8,760.00 6,592.08 4,650.36 -2,515.26 KOP 8,790.00 6,601.97 4,674.64 -2,529.78 Start 30 dls 8,865.00 6,609.42 4,742.94 -2,558.63 4 8,965.00 6,601.87 4,825.27 -2,612.84 5 9,065.00 6,598.02 4,885.20 -2,692.64 Start 10 dls 9,215.00 6,594.08 4,980.60 -2,807.78 7 9,390.00 6,587.90 5,124.72 -2,905.64 8 9,490.00 6,588.27 5,218.12 -2,941.01 9 9,615.00 6,590.31 5,333.60 -2,988.17 10 9,815.00 6,590.70 5,489.57 -3,111.73 11 9,965.00 6,587.38 5,602.35 -3,209.92 12 10,090.00 6,580A2 5,697.84 -3,289.87 13 10,340.00 6,574.19 5,903.62 -3,428.20 14 10,540.00 6,578.11 6,072.95 -3,532.64 15 10,665.00 6,577.62 6,156.78 -3,625.03 16 10,915.00 6,571.17 6,256.04 -3,852.23 17 11,065.00 6,571.65 6,303.33 -3,994.13 18 11,400.00 6,581.29 6,526.46 -4,237.41 TD at 11400.00 31112013 2:07.28PM Page 7 COMPASS 2003.16 Build 69 ConocoPhillips %UasI , Inc, HANGER, CONDUCTOR, 42-121 NIPPLE, 1,81 SURFACE, Q 42-5,345 GAS LIFT, 8,180 PER. 8,230 PACKER, 8,242 INJECTION, 8,294 IPERF, 8,340d,404 IPERF, 8,430-8,470 SEAL ASSY, 8,566 'ACKER, 8,569 NIPPLE, 8,587 SOS, 8,599 RPERF, 8.673.8,693 RPERF, 8, 70" 726 KUP 1 H-19 Well Attributes Max Annie & MD TD Wellbore API/UWI 500292231200 Field Name Well Status KUPARUK RIVER UNIT INJ Inc[ (1 46.17 MD (ftKB) 5,677.00 Act Btm (ftKB) 8,990.0 Comment H2S (ppm) SSSV: WRDP Date Annotation Last two: End Date 6/14/1993 KB-Grd (ft) Rig Release Data 12/18/1992 Annotation Depth Tag: SLM (ftKB) 8,683.0 End Date 102/2012 Annotation Rev Reason: GLV C/O, TAG, PULL SLEEVE Last Mod ... End ninam 10/92012 Date k4sLast it1 Strings Casing Description CONDUCTOR String 0- 16 String ID 15.060 ... Top (ttKB) Set 41.9 Depth If... 121.0 Set Depth (TVD) ... String 121.0 Wt... String 62.50 ... H-40 String Top Third WELDED Casing Description SURFACE String 0... 95✓8 String ID 8.835 ... Top (ftKB) Set 41.9 Depth If... 5,344.6 Set Depth (TVD) ... String 4,269.9 Wt... String 40.00 ... L-80 String Top Third BTC Casing Description PRODUCTION String 0... 7 String ID 6.276 ... Top (ftKB) Set 35.2 Depth (f... 8,970.2 Set Depth (TVD) ... String 6,913.2 Wt... String 26.00 ... J-55 String Top Third AB -MOD Tubing Strin s Tubing Description string 0... String ID ... Top (ftKB) Set Depth (f- Set Depth (TVD) ... String Wt... String ... String Top Thrtl TUBING3.5 x2.875 31/2 2.992 37.6 8,599.8 6,632.4 9.30 J-55 ABM-EUE Com ietion Details Top (ftKB) Top Depth (TVD) (ftKB) Top Ind (°) Item Description Comment Nomi... ID (in) 37.6 37.6 0.05 HANGER FMC GEN IV HANGER 3.500 1,810.1 1,692.1 37.81 NIPPLE OTIS SELECTIVE LANDING NIPPLE 2.813 8,229.7 6,360.9 43.39 PBR OTIS PBR 2.970 8,241.9 6,369.8 43.66 PACKER OTIS HVT RETRIEVABLE PACKER 2.972 8,337.2 6,439.1 43.19 BLASTJTS BLASTJOINTS 2.992 8,526.6 6,578.1 42.32 NIPPLE AVA BPL PORTED NIPPLE 2.320 8,560.7 6,603.4 42.08 XO Reducing CROSSOVER 3.5 x2.875 2.875 8,565.5 6,607.0 42.05 SEAL ASSY BAKER GBH-22 LOCATOR SEAL ASSEMBLY 2.406 8,568.6 6,609.3 42.03 PACKER BAKER D PERMANENT PACKER (7 SPACE OUT ABOVE PKR) 3.250 8,587.3 6,623.2 41.84 NIPPLE CAMCO D NIPPLE NO GO 2.250 8,599.0 6,631.8 41.82 SOS OTIS SHEAR OUT SUB. ELMD TTL 8596 ON 5/29/06 2.441 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) St. (TVD) (ftKB) Zone Date Shot Dens (sh... Type Comment 8,340 8,404 6,441.1 6,487.9 C-4, C-3, 11-1-19 6/14/1993 12.0 160 deg Phasing 8,430 8,470 6,506.9 6,536.3 C-2, C-1, UNIT B, 1H-19 6/14/1993 12.0 IPERF 60 deg Phasing 8,673 8,693 6,687.0 6,702.0 A-4, 11-1-19 2/18/2007 6.0 RPERF 0 deg Phasing 8,706 8,726 6,711.7 6,726.8 A-3, 11-1-19 2/18/2007 6.0 RPERF 0deg Phasing Notes: General & Safetv End Date Annotation 9/272010 NOTE: View Schematic w/ Alaska Schematic9.0 2/1/2011 NOTE: APPARENT C-SAND LEAK @ 8294' MANDREL Mandrel Details Stn lop (ttK8) Top Depth (TVD) (ftKB) Top Inc' (°) Make Model OD (in) Sery Valve Type Latch Type Port size (in) 7RO Run (Psi) Run Date Com... 1 8,179.8 6,324.6 43.40 CAMCO MMG 1 12 GAS LIFT DMY RK 10.000 0.0 11/14/20101 2 8,294.0 6,407.6 43.36 CAMCO MMG 1 1/2 INJ DMY RK 0.000 0.0 10/62012 Et Pkg PRODUCTION, 35 8,970 `a TD, 8,990 RECEIVED STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION MAR 0 4 2013 PERMIT TO DRILL �� AOGCC 20 AAC 25.005 S Ff �tcJ 3��1 1a. Type of Work: Drill ❑ - Lateral ❑✓ Redrill Reentry ❑ 1 In Proposed Well Class: Development - Oil ❑ Service - Winj ❑ Single Zone ❑✓ Stratigraphic Test ❑ Development -Gas ❑ Service - Supply ❑ Multiple Zone ❑ Exploratory ❑ Service - WAG ❑ Service - Disp ❑ 1c. Specify if well is proposed for., Coalbed Gas ❑ Gas Hydrates ❑ Geothermal ❑ Shale Gas ❑ 2. Operator Name: ConocoPhillips Alaska, Inc. 5. Bond: ✓ Blanket Lj Single Well Bond No. 59-52-180 • 11. Well Name and Nu er: 1 H-19AL1-02 3. Address: P.O. Box 100360 Anchorage, AK 99510-0360 6. Proposed Depth: MD: 11400' + TVD: 6581' - 12. Field/Pool(s): Kuparuk.River Field KupBruk River Oil Pool 4a. Location of Well (Governmental Section): Surface: 582' FNL, 1160' FEL, Sec. 33, T12N, R10E, UM Top of Productive Horizon: 1212' FNL, 3665' FEL, Sec. 28, T12N, R10E, UM Total Depth: 4616' FNL, 103' FEL, Sec. 20, T12N, R10E, UM 7. Property Designation (Lease Number a -(� IZoi3 y ADL 25639, 25635 1,ls 8. Land Use Permit: 464, 2568 13. Approximate Spud Date: 3/2/2013 9. Acres in Property: 7568 • 14. Distance to Nearest Property: 9650 - 4b. Location of Well (State Base Plane Coordinates - NAD 27): Surface: x- 549187 y- 5980119 Zone- 4, 10. KB Elevation above MSL: 96 feet GL Elevation above MSL: 54 feet 15. Distance to Nearest Well Open to Same Pool: 1R-02 , 1050 16. Deviated wells: Kickoff depth: 8760 ft. Maximum Hole Angle: 94.5° deg 17. Maximum Anticipated Pressures in psig (see 20 AAC 25.035) Downhole: 4200 psig . Surface: 3550 psig 18. Casing Program: Specifications Top - Setting Depth - Bottom Cement Quantity, c.f. or sacks stage data Hole Casing Weight Grade Coupling Length MD TVDSS MD TVDSS(including 3" 2.375" 4.7# L-80 ST-L 2885' 8515' 6474' 11400' 6581' slotted liner 19 PRESENT WELL CONDITION SUMMARY (To be completed for Redrill and Re -Entry Operations) Total Depth MD (ft): 8990 Total Depth TVD (ft): 6928 Plugs (measured) none Effective Depth MD (ft): 1 8887 Effective Depth TVD (ft): 6849 Junk (measured) none Casing Length Size Cement Volume MD TVD Conductor/Structural 79' 16" 200'sx PF C 121' 121' Surface 5303' 9.625" 1390 sx,,PF E, 500 sx Cl G, 5345 4270' Intermediate 44 bbls PF C Production 8935' 7" 270 sx Class G 8970' 6913' Liner Perforation Depth MD (ft): ___[Perforation 8340-8404, 8430-8470, 8673-8693, 870 -8726 Depth TVD (ft): 6441-6488, 6507-6536, 6687-6702, 6712-6727 20. Attachments: Property Plat ❑ BOP Sketch Drilling Program ❑ Time v. Depth Plot ❑ Shallow Hazard Analysis Diverter Sket ❑ Seabed Report ❑ Drilling Fluid Program ❑✓ 20 AAC 25.050 requirements ❑✓ 21. Verbal Approval: Commission Rep/veta Ferguson Date: 2/28/2013 D 22. 1 hereby certify that the foregoing is Contact James Ohlinger @ 265Email James.J.OhlingerCcDconocophillips.corr Printed Name LamTitle CT Drilling Supervisor Signature � �' .� Phon 2Ei3-4U11 Date Commission Use Only Permit to Drill Number: � 13 o3)_ API Number: 50- ()oc l _ a23 j a-- 6 3 Permit Approval Date: See cover letter for other requirements Conditions of approval ' If box is checked, well may not be used to explore for, test, or produce coalbed methane, gas hydrates, or gas contained in shales: Other: Samples req'd: Yes ❑ No Mud log req'd: Yes ❑ No H2S measures: Yes Q No ❑ Directional svy req'd: Yes No ❑ Spacing exception req'd: Yes ❑ No Inclination -only svy req'd: Yes ❑ No Q APPROVED BY THE Approved by: COMMISSIONER comlvissloN Date: Form 10-401 (Revised 10/2012) This permit is valid, for 24 months from the date of approval (20 AAC 25.005(g)) ,�p�La� ��5 ConocoPhilli s p Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 February 28, 2013 Commissioner - State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Dear Commissioner: RECEIVED MAR 0 4 2013 A®`, CC ConocoPhillips Alaska, Inc. hereby submits an application for a permit to drill an additional lateral out of the Kuparuk Well 1 H-19AL1 (PTD # 213-003) using the coiled tubing drilling rig, Nabors CDR2-AC. The work is scheduled to begin March 2, 2013. The CTD objective will be to drill lateral 1 H-19AL1-02, to pick up missed footage in the Kuparuk A4 sand interval; due to the lost footage from the 1 H-19APB1, 1 H-19AL1 P131, and 1 H-19AL1-01 P131. Laterals 1H-19A, AP61, AL1, AL1PB1, AL1-01, and AL1-01P131 have been drilled. The original A & C-sand perforations have been cemented off before CTD operations commence, as per submitted Sundry (312-473). Attached to this application are the following documents - Permit to Drill Application Form for 1 H-19AL1-02 - Detailed Summary of Operations - Directional Plans - Proposed Schematic If you have any questions or require additional information please contact me at 907-265-1102. Sincerely, James J. Ohlinger Coiled Tubing Drilling Engineer Kuparuk CTD Laterals NABORSALASKA 1 H-19A, 1 H-19AL1, 1 H-19AL1-01, 1 H-19AL1-02 & 1 H-19AL2 CD� Application for Permit to Drill Document 2RC 1. Well Name and Classification........................................................................................................ 2 (Requirements of 20 AAC 25.005(0 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................................................................... 3 (Requirements of 20 AAC 25.005(c)(5))................................................................................................................................................. 3 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..................................................................................................................4 (Requirements of 20 AAC 25.005(c)(8))................................................................................................................................................. 4 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............................................................................................................5 (Requirements of 20 AAC 25.005(c)(13))............................................................................................................................................... 5 Summaryof Operations.................................................................................................................................................. 5 PressureDeployment of BHA......................................................................................................................................... 7 LinerRunning.................................................................................................................................................................. 7 14. Disposal of Drilling Mud and Cuttings.......................................................................................... 7 (Requirements of 20 AAC 25.005(c)(14))............................................................................................................................................... 7 15. Directional Plans for Intentionally Deviated Wells....................................................................... 7 (Requirements of 20 AAC 25.050 b.............................................................. 7 16. Quarter Mile Injection Review (for injection wells only)..............................................................8 (Requirements of 20 AAC 25.402)......................................................................................................................................................... 8 17. Attachments.................................................................................................................................... 9 Attachment 1: Directional Plans for 1H-19A, 1H-19AL1, 1H-19AL1-01, 1H-19AL1-02 & 1H-19AL2 ............................. 9 Attachment 2: Current Well Schematic for 1 H-19.......................................................................................................... 9 Attachment 3: Proposed Well Schematic for 1 H-19A, 1 H-19AL1, 1 H-19AL1-01, 1 H-19AL1-02 & 1 H-19AL2............... 9 Pagel of 9 0 I I � `� 3/4/2013 PTD Application: 1 H-19A, 1 H-19AL1, 1 H-19AL1-01, 1 H-19AL1-02 & 1 H-19AL2 1. Well Name and Classification (Requirements of 20 AA 25.005(f) and 20 AA 25.005(b)) The proposed laterals described in this document are 1 H-19A, 1 H-19AL1, 1 H-19AL1-01, 1 H-19AL1-02 & 1 H- 19AL2. All three of these laterals will be classified as "Service" 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 582' FNL, 1160' FEL, Sec 33, T12N, R10E, UM NAD 1927 Northings: 5,980,119 Eastings: 549,187 RKB Elevation 96 AMSL Pad Elevation 54 AMSL 1 H-19A Location at Top of Productive Horizon 1183' FNL, 3695' FEL, Sec 28, T12N, R10E, UM Ku aruk NAD 1927 Measured Depth, RKB: 8,800' Total Vertical Depth, SS: 6,594' Northings: 5,984,780 Eastings: 546,611 Location at Total Depth 4515' FNL, 171' FEL, Sec 20, T12N, R10E, UM NAD 1927 Northings: 5,986,718 Eastings: 544,838 Measured Depth, RKB: 11,500' Total Vertical Dept , SS: 6,580' 1 H-19AL1 Location at Top of Productive Horizon 1404' FNL, 3575' FEL, Sec 28, T12N, R10E, UM Ku aruk) NAD 1927 Measured Depth, RKB: 8,515' Northings: 5,984,561 Eastings: 546,733 Total Vertical Depth, SS: 1 6,474' Location at Total Depth 4485' IF 160' FEL, Sec 20, T12N, R10E, UM NAD 1927 Northings: 5,986,748 Eastings: 544,848 Measured Depth, RKB: 11,500' Total Vertical Dept , SS: 6,605' 1 H-19AL1-01 Location at Top of Productive Horizon 21' FNL, 4641' FEL, Sec 28, T12N, R10E, UM Ku aruk NAD 1927 Measured Depth, RKB: 10,370' Total Vertical Depth, SS: 6,595' Northings: 5,985,937 Eastings: 545,655 Location at Total Depth 4535' FNL, 117' FEL, Sec 20, T12N, R10E, UM NAD 1927 Northings: 5,986,698 Eastings: 544,892 Measured Depth, RKB: 11,500' Total Vertical Dept , SS: 6,595' 1 H-19AL1-02 Location at Top of Productive Horizon 1212' FNL, 3665' FEL, Sec 28, T12N, R10E, UM Ku aruk NAD 1927 Measured Depth, REEF-8,760' Total Vertical Depth, SS: 1 6,592' Northings: 5,984,752 Eastings: 546,641 Location at Total Depth 4616' FNL, 103' FEL, Sec 20, T12N, R10E, UM NAD 1927 Northings: 5,986,617 Eastings: 544,907 Measured Depth, RKB: 11,400' Total Vertical Depth, SS: 6,58V Page 2 of 9 ! ° 3/4/2013 g PTD Application: 1 H-19A, 1 H-19AL1, 1 H-19AL1-01, 1 H-19AL1-02 & 1 H-19AL2 1 H-19AL2 Location at Top of Productive Horizon 1416' FNL, 3569' FEL, Sec 28, T12N, R10E, UM Kuparuk NAD 1927 Measured Depth, RKB: 8,495' Total Vertical Depth, SS: 1 6,459' Northings: 5,984,549 Eastings: 546,739 Location at Total Depth 3337' FNL, 4742' FEL, Sec 28, T12N, R10E, UM NAD 1927 Northings: 5,982,620 Eastings: 545,583 Measured Depth, RKB: 11,500' Total Vertical Depth, SS: 6,510' 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 4000 psi. (Using the maximum pressure in the area of 4200 psi, the maximum possible surface pressure, assuming a gas gradient of 0.1 psi/ft, would be 3550 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)) A static bottom hole pressure of 1 H-19 in October 2012 indicated a reservoir pressure of 4097 psi or 11.9 ppg • equivalent mud weight. The maximum down hole pressure in the 1 H-19 pattern is at injector 1 R-26 with 4200 psi. It is not expected that reservoir pressure as high as 1 R-26 well will be encountered while drilling the 1 H-19 laterals because of offset distance and faulting. Using the 1R-26 pressure as the maximum possible in 1R- 29, the maximum possible surface pressure, assuming a gas gradient of 0.1 psi/ft, would be 3550 psi. Potential Gas Zones (Requirements of 20 AAC 25.005 (c)(4)(b)) No specific gas zones will be drilled-, however, 1 H Pad hasn't had any MI injection since early 2008. There was some MI injected into the C-sand (with some more than likely getting into the A) to the North in 1 R-26. Potential Causes of Hole Problems (Requirements of 20 AAC 25.005 (c)(4)(c)) The largest, expected risk of hole problems in the 1 H-19 laterals will be crossing a fault into a lower pressurized reservoir block and experiencing losses. 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(f), thru-tubing drilling operations need not perform additional formation integrity tests. Page 3 of 9 3/4/2013 PTD Application: 1 H-19A, 1 H-19AL1, 1 H-19AL1-01, 1 H-19AL1-02 & 1 H-19AL2 6. Casing and Cementing Program (Requirements of 20 AAC 25.005(c)(6)) New Completion Details Lateral Liner Top Liner Btm Liner Top Liner Btm Name MD MD TVDSS TVDSS Liner Details 1 H-19A 8800' 11500' 6594' 6580' 2'/", 4.7#, L-80, ST-L slotted liner; aluminum billet on top. 1 H-19AL1 10,370' 11500' 6595' 6605' 2%", 4.7#, L-80, ST-L slotted liner, - aluminum billet on top. 1H-19AL1-01 8760' 11500' 6592' 6595' 2%111 4.7#, L-80, ST-L slotted liner; deployment sleeve on top. 1 H-19AL1-02 8515' 11,400' 6474' 6581' 2'/", 4.7#, L-80, ST-L slotted liner; deployment sleeve on top. 1 H-19AL2 8495' 11500' 6459' 6510' 23/a', 4.7#, L-80, ST-L slotted liner; deployment sleeve on top. Existing Casing/Liner Information OD Weight (ppCategory f Grade Connection Top MD Btm MD Top TVD Btm TVD Burst psi Collapse psi Conductor 16" 62.55 H-40 Welded 42' 121' 0' 121' 1640 630 Surface 9-5/8" 40 L-80 BTC 42' 5345' 0' 4270' 5750 3090 Casing 7" 26.0 J-55 AB -Mod 35' 8970' 0' 6913' 4980 4330 Tubing 3-1/2 " 9.3 J-55 ABM-EUE 38' 8560' 0' 6603' 6990 7400 Tubing 2-7/8 " 6.5 NA NA 8560' 1 8600' 6603' 1 6632' 7260 7680 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. 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 Flo -Pro FloVis mud (9.6 ppg) — Drilling operations: Chloride -based Flo -Pro FloVis mud (9.6Yppg). While this mud weight may not hydrostatically overbalance the reservoir pressure, overbalanced conditions will be maintained using MPD practices described below. — Completion operations: 1 H-19 does not contain a subsurface safety valve (SSSV). 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 (-200 bbl) of 13.1 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. Page 4 of 9 �0 i II ,L v 3/4/2013 PTD Application: 1 H-19A, 1 H-19AL1, 1 H-19AL1-01, 1 H-19AL1-02 & 1 H-19AL2 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. Since this well is proposed as an infield development candidate in an actively water flooded field, expected reservoir pressures can be difficult to estimate. In this case, however, a constant BHP of 12.0 ppg will be initially targeted at the window based on the recent static bottom hole pressure. 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. 13. Proposed Drilling Program (Requirements of 20 AAC 25.005(c)(13)) Summary of Operations Background Well 1H-19 is a Kuparuk A-sand/C-sand injection well equipped with 3Yz" tubing and 7" production casing with the C-sand behind a straddled selective. Three proposed A -sand CTD laterals will increase reservoir exposure in two adjoining fault blocks. Prior to drilling, the existing C-sand perfs in 1H-19 will be plugged with cement to provide a means to kick out of the 3-1/2" and 7" casing. The existing A -sand perfs will be plugged off with a CA-2 plug in the tubing tail, then covered with cement when the C-sands are cemented. The well is currently an injector, however the injection point will be moved to —250' from the upper packer, once the C-sands are cemented and the windows are milled. The 3-1/2" tubing in the C-sand selective straddle will be perforated in two intervals to allow cement in the 3-1/2" by 7" annulus. The intervals will be at the whipstock setting locations with 10' of perforations. After plugging off the existing A & C-sand perfs with cement, mechanical whipstocks will be placed in the 3-1/2" tubing at the planned kickoff points. The l H-19A sidetrack will exit through the 3-1/2" tubing and 7" casing at 8,515' MD and will target the A4 sand west of the existing well with a 2985' lateral. The hole will be completed with a 2-%" slotted liner to the TD of 11,500' MD with an aluminum billet at 8,800' MD. The l H-19AL1 lateral will kick off from the aluminum billet at 8,800' MD and will target the A3 sand west of the existing well with a 2700' lateral. The hole will be completed with a 2%" slotted liner to the TD of l 1,500' MD with an aluminum billet at 10,370' MD. Page 5 of 9 3/4/2013 PTD Application: 1 H-19A, 1 H-19AL1, 1 H-19AL1-01, 1 H-19AL1-02 & 1 H-19AL2 1H-19AL1-01 lateral will kickoff from an aluminum billet at 11,370' MD and will target the A3 sand west of the existing well with a 1130' lateral. The hole will be completed with a 2%" slotted liner to the TD of 11,500' MD with an aluminum billet at 8,760' MD. 1H-19AL1-02 lateral will kick off from an aluminum billet at 8,760' MD and will target the A4 sand west of the existing well with a 2640' lateral. The hole will be completed with a 2%" slotted liner to the TD of 11,400' MD with the liner top located inside the 3'/2" tubing at 8,510' MD. The 1 H1-9AL2 sidetrack will exit through the 3-1/2" tubing and 7" casing at 8,495' MD and will target the A4 sand south of the existing well with a 2805' lateral. The hole will be completed with a 2%" slotted liner to the TD of 11,500' MD with the final liner top located inside the 3'/2" tubing at 8,490' MD. Pre -Rig Work (As per submitted Sundry) 1. Positive pressure and drawdown tests on MV and SV. 2. Test Packoffs — T & IC. 3. MIT -IA 4. RU slickline. Tag fill, drift dummy whipstock 5. RU Eline: GR/CCL/CBL Logs for jewelry correlation and bond log 6. RU Eline: Perforate tubing at 8,510' and 8,490' RKB 7. RU slickline. Set CA-2 plug in tubing tail nipple, set BPC sleeve in the AVA BPL nipple 8. RU coil: Place cement in the 3-1/2" tubing from the CA-2 up to—8,490' and in the annulus of the C-sand straddle 9. RU slickline. Tag top of cement and pressure test. RD slickline. 10. RU coil: Mill out cement in the 3-1/2" tubing down to the BPC sleeve in the AVA BPL nipple 11. Prep site for Nabors CDR2-AC, including setting BPV Rig Work 1. MIRU Nabors CDR2-AC rig using 2" coil tubing. NU 7-1/16" BOPE, test. 2. 1H-19A Sidetrack (A4 sand, west) a. Set whipstock at 8,515' MD b. Mill 2.80" window at 8,515' MD. c. Drill 2.70" x 3.25" bi-center lateral to TD of 11,500' MD d. Run 2%" slotted liner with an aluminum billet from TD up to 8,800' MD 3. 1H-19AL1 Lateral (A3 sand, west) a. Kick off of the aluminum billet at 8,800' MD b. Drill 2.70" x 3.25" bi-center lateral to TD of 11,500' MD c. Run 2%" slotted liner with an aluminum billet from TD up to 10,370' MD 4. 1H-19AL1-01 Lateral (A3 sand, west) a. Kick off of the aluminum billet at 10,370' MD b. Drill 2.70" x 3.25" bi-center lateral to TD of 11,500' MD c. Run 2%" slotted liner with an aluminum billet from TD up to 8,760' MD 5. 1H-19AL1-02 Lateral (A4 sand, west) a. Kickoff of the aluminum billet at 8,760' MD b. Drill 2.70" x 3.25" bi-center lateral to TD of 11,400' MD c. Run 2%" slotted liner from TD up to 8,510' MD, inside the 3!/2" tubing tail 6. 1H-19AL2 Lateral (A4 sand, south) a. Set whipstock at 8,495' MD b. Mill 2.80" window at 8,495' MD. c. Drill 2.70" x 3.0" bi-center lateral to TD of 11,500' MD d. Run 2%" slotted liner from TD up to 8,490' MD, inside the 3'/2" tubing tail 7. Freeze protect. Set BPV, ND BOPE. RDMO Nabors CRD2-AC. Page 6 of 9 +� 3/4/2013 �� ; t11 s E PTD Application: 1 H-19A, 1 H-19AL1, 1 H-19AL1-01, 1 H-19AL1-02 & 1 H-19AL2 Post -Rig Work 1. Pull BPV 2. Obtain static BHP. Install GLV's. 3. Return to pre -production before injection 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 — The 1 H-19 CTD laterals will be displaced to an overbalancing fluid (12 ppg Na-Br) prior to running liner. See the "Drilling Fluids" section for more details. — While running 23/" 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. 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 1 R 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 Plan — 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. Page 7 of 9 3/4/2013 PTD Application: 1 H-19A, 1 H-19AL1, 1 H-19AL1-01, 1 H-19AL1-02 & 1 H-19AL2 — Distance to Nearest Property Line (measured to KPA boundary at closest point) Lateral Name Distance 1 H-19A 9750' 1 H-19AL1 9760' 1 H-19AL1-01 10824' 1H-19AL1-02 9650' 1 H-19AL2 9710' — Distance to Nearest Well within Pool (toe measured to offset well) Lateral Name Distance Well 1 H-19A 1150' 1 R-02 1H-19AL1 1100, 1R-02 1 H-19AL1-01 1214' 1 R-02 1H-19AL1-02 1050' 1R-02 1 H-19AL2 1100, 1 H-03 16. Quarter Mile Injection Review (for injection wells only) (Requirements of 20 AAC 25.402) The only wells that lie within %4-mile of the proposed 1 H-19 CTD laterals are the 1 H-19 motherbore and 1 R-02. The casing and cementing of 1 H-19 is described below. The A & C-sand perforations will be permanently plugged as part of this CTD sidetrack proposal. See the attached schematic for clarification. 1H-19 Mother Bore Well 1 H-19 was drilled and completed in 1993. The 7", 26 ppf, J-55, BTC-Mod production casing was set at 8,970' MD in the Miluveach. 1 H-19 is a Service well with a "Normal Well" Ann -Comm status, was capable of injecting to both of the Kuparuk A & C sands with a straddle completion. The C-sand will be cemented off during the pre -rig procedures (Sundry # 312-473). 1 R-29 Well 1 R-29 (PTD #191-094) was drilled and completed in 1991. The 7", 26 ppf, J-55, BTC-Mod production casing was set at 11,331' MD in the Miluveach. 1 R-29 was a Production well with a "Normal Well" Ann -Comm status, capable of producing both of the Kuparuk A & C sands with a straddle completion. It has recently been sidetracked in the Kuparuk A sand with Coiled Tubing Drilling. The original C-sand is still accessible via the selective straddle completion. The original A -sand was cemented off, and is now accessed by the 4 laterals that were completed with 2-3/8" 4.7ppf L-80 slotted liner. The 1 H-19 to 1 R-29 Center to Center distance is roughly 1270 feet; the 1 H-19 laterals will be the injector offset to the 1 R-29 production laterals. 1 R-02 Well 1 R-02 (PTD #185-176) was drilled and completed in 1985. The 7", 26 ppf, J-55, BTC-Mod production casing was set at 9,291' MD in the Miluveach. 1 R-02 is a Production well with a "Normal Well" Ann -Comm status, capable of producing both of the Kuparuk A & C sands with a straddle completion. The last SBHP for the A sand was 2261 psi in Sept. '11, and the C sand measured 2485 psi. 1 H-03 Well 1 H-03 (PTD #182-115) was drilled and completed in 1982. The 7", 26 ppf, J-55, BTC-Mod production casing was set at 8,141' MD in the Miluveach. 1 H-03 is a Service well with a "Normal Well" Ann -Comm status, and capable of injecting to both of the Kuparuk A & C sands with a straddle completion. The well will be shut-in prior (4 weeks) to CDR2-AC arrival to 1 H-19. The last SBHP measured 3970 psi (12.1 ppg EMW) on Oct. '12. Page 8 of 9 3/4/2013 PTD Application: 1 H-19A, 1 H-19AL1, 1 H-19AL1-01, 1 H-19AL1-02 & 1 H-19AL2 17. Attachments Attachment 1: Directional Plans for 1H-19A, 1H-19AL1, 1H-19AL1-01, 1H-19AL1-02 & 1H- 19AL2 Attachment 2: Current Well Schematic for 1H-19 Attachment 3: Proposed Well Schematic for 1H-19A, 1H-19AL1, 1H-19AL1-01, 1H-19AL1-02 & 1 H-19AL2 Page 9 of 9 f " ' 3/4/2013 ConocoPhillips Alaska ConocoPhillips(Alaska) Inc. Kuparuk River Unit Kuparuk 1 H Pad 1 H-19 1 H-19AL1-02 Plan: 1 H-19AL1-02_wp02 Standard Planning Report 01 March, 2013 FEW Arps BAKER HUGHES ConocoPhillips Alaska Database: EDM Alaska Prod v16 Company: ConocoPhillips(Alaska) Inc. Project: Kuparuk River Unit Site: Kuparuk 1 H Pad Well: 11-1-19 Wellbore: 1 H-19AL1-02 Design: 1 H-19AL1-02_wp02 ConocoPhillips or its affiliates Planning Report Local Co-ordinate Reference: Well 1 H-19 TVD Reference: Mean Sea Level MD Reference: 1 H-19 @ 96.00ft (1 H-19) North Reference: True Survey Calculation Method: Minimum Curvature 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 BAKrER•• HUGHES Site Kuparuk 1 H Pad Site Position: Northing: 5,979,968.84ft Latitude: 70' 21' 21.831 N From: Map Easting: 549,197.16ft Longitude: 149' 36' 1.675 W Position Uncertainty: 0.00 ft Slot Radius: Grid Convergence: 0.38 ° Well 1H-19 Well Position +N/-S 0.00 ft Northing: 5,980,118.88 ft Latitude: 700 21' 23.308 N +E/-W 0.00 ft Easting: 549,186.59 ft Longitude: 149' 36' 1.955 W Position Uncertainty 0.00 ft Wellhead Elevation: ft Ground Level: 0.00 ft Wellbore 11-1-19AL1-02 Magnetics Model Name Sample Date Declination Dip Angle Field Strength (1) (1 (nT) BGG M2011 12/31 /2012 16.03 79.99 57,387 Design 1H-19AL1-02_wp02 Audit Notes: Version: Phase: PLAN Tie On Depth: 8,740.47 Vertical Section: Depth From (TVD) +N/-S +E/-W Direction (ft) (ft) (ft) (1) 0.00 0.00 0.00 315.00 31112013 2:07:28PM Page 2 COMPASS 2003.16 Build 69 ✓ ConocoPhillips or its affiliates FGaI ConocoPhillips Planning Report BMER Alaska HUGHES Database: EDM Alaska Prod v16 Company: ConocoPhillips(Alaska) Inc. Project: Kuparuk River Unit Site: Kuparuk 1 H Pad Well: 11-1-19 Wellbore: 1 H-19AL1-02 Design: 1 H-19AL1-02_wp02 Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Well 1 H-19 Mean Sea Level 1 H-19 @ 96.O0ft (1 H-19) True Minimum Curvature Plan Sections Measured TVD Below Dogleg Build Turn Depth Inclination Azimuth System +NI-S +E/-W Rate Rate Rate TFO (ft) (°) (°) (ft) (ft) (ft) (°1100ft) (°1100ft) (/100ft) (°) Target 8,740.47 64.14 326.77 6,584.09 4,635.55 -2,505.36 0.00 0.00 0.00 0.00 8,760.00 67.53 325.74 6,592.08 4,650.36 -2,515.26 18.01 17.36 -5.27 -15.71 8,790.00 74.02 332.35 6,601.97 4,674.64 -2,529.78 30.00 21.64 22.02 45.00 8,865.00 94.54 341.68 6,609.42 4,742.94 -2,558.63 30.00 27.35 12.45 25.00 8,965.00 93.93 311.61 6,601.87 4,825.27 -2,612.84 30.00 -0.61 -30.08 270.00 9,065.00 90.47 302.21 6,598.02 4,885.20 -2,692.64 10.00 -3.46 -9.39 250.00 9,215.00 92.52 317.08 6,594.08 4,980.60 -2,807.78 10.00 1.37 9.91 82.00 9,390.00 91.50 334.56 6,587.90 5,124.72 -2,905.64 10.00 -0.58 9.99 93.00 9,490.00 88.08 343.96 6,588.27 5,218.12 -2,941.01 10.00 -3.43 9.40 110.00 9,615.00 90.06 331.61 6,590.31 5,333.60 -2,988.17 10.00 1.59 -9.87 279.00 9,815.00 89.72 311.62 6,590.70 5,489.57 -3,111.73 10.00 -0.17 -10.00 269.00 9,965.00 92.81 326.30 6,587.38 5,602.35 -3,209.92 10.00 2.06 9.79 78.00 10,090.00 93.82 313.82 6,580.12 5,697.84 -3,289.87 10.00 0.81 -9.98 275.00 10,340.00 88.85 338.34 6,574.19 5,903.62 -3,428.20 10.00 -1.99 9.81 101.00 10,540.00 88.92 318.33 6,578.11 6,072.95 -3,532.64 10.00 0.03 -10.00 270.00 10,665.00 91.53 306.10 6,577.62 6,156.78 -3,625.03 10.00 2.08 -9.78 282.00 10,915.00 91.38 281.10 6,571.17 6,256.04 -3,852.23 10.00 -0.06 -10.00 270.00 11,065.00 88.25 295.77 6,571.65 6,303.33 -3,994.13 10.00 -2.09 9.78 102.00 11,400.00 88.54 329.28 6,581.29 6,526.46 -4,237.41 10.00 0.09 10.00 90.00 31112013 2:07.28PM Page 3 COMPASS 2003.16 Build 69 ConocoPhillips Alaska Database: EDM Alaska Prod v16 Company: ConocoPhillips(Alaska) Inc. Project: Kuparuk River Unit Site: Kuparuk 1 H Pad Well: 11-1-19 Wellbore: 1 H-19AL1-02 Design: 1 H-19AL1-02_wp02 ConocoPhillips or its affiliates Planning Report Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Well 1H-19 Mean Sea Level 1 H-19 @ 96.00ft (1 H-19) True Minimum Curvature //FAI BAKER HUGHES Planned Survey Measured TVD Below Vertical Dogleg Toolface Map Map Depth Inclination Azimuth System +N/-S +E/-W Section Rate Azimuth Northing Easting (ft) (1) (1) (ft) (ft) (ft) (ft) (°/100ft) (1) (ft) (ft) 8,740.47 64.14 326.77 6,584.09 4,635.55 -2,505.36 5,049.38 0.00 0.00 5,984,737.43 546,651.09 TIP 8,760.00 67.53 325.74 6,592.08 4,650.36 -2,515.26 5,066.86 18.01 -15.71 5,984,752.17 546,641.10 KOP 8,790.00 74.02 332.35 6,601.97 4,674.64 -2,529.78 5,094.30 30.00 45.00 5,984,776.36 546,626.42 Start 30 dls 8,800.00 76.74 333.65 6,604.49 4,683.26 -2,534.17 5,103.50 30.00 25.00 5,984,784.95 546,621.97 8,865.00 94.54 341.68 6,609.42 4,742.94 -2,558.63 5,162.99 30.00 24.67 5,984,844.46 546,597.12 4 8,900.00 94.46 331.15 6,606.67 4,774.87 -2,572.57 5.195.43 30.00 -90.00 5,984,876.30 546,582.97 8,965.00 93.93 311.61 6,601.87 4,825.27 -2,612.84 5,259.54 30.00 -90.83 5,984,926.42 546,542.38 5 9,000.00 92.73 308.31 6,599.83 4,847.71 -2,639.62 5,294.34 10.00 -110.00 5,984,948.68 546,515.46 9,065.00 90.47 302.21 6,598.02 4,885.20 -2,692.64 5,358.34 10.00 -110.19 5,984,985.82 546,462.19 Start 10 dls 9,100.00 90.96 305.68 6,597.58 4,904.74 -2,721.67 5,392.69 10.00 82.00 5,985,005.17 546,433.04 9,200.00 92.32 315.59 6,594.72 4,969.75 -2,797.43 5,492.23 10.00 82.04 5,985,069.68 546,356.86 9,215.00 92.52 317.08 6,594.08 4,980.60 -2,807.78 5,507.21 10.00 82.33 5,985,080.45 546,346.45 7 9,300.00 92.05 325.57 6,590.69 5,046.84 -2,860.80 5,591.55 10.00 93.00 5,985,146.34 546,292.99 9,390.00 91.50 334.56 6,587.90 5,124.72 -2,905.64 5,678.32 10.00 93.34 5,985,223.92 546,247.65 a 9,400.00 91.16 335.50 6,587.67 5,133.78 -2,909.86 5,687.72 10.00 110.00 5,985,232.95 546,243.37 9,490.00 88.08 343.96 6,588.27 5,218.12 -2,941.01 5,769.38 10.00 110.02 5,985,317.07 546,211.67 9 9,500.00 88.23 342.97 6,588.59 5,227.70 -2,943.85 5,778.16 10.00 -81.00 5,985,326.63 546,208.76 9,600.00 89.82 333.09 6,590.29 5,320.31 -2,981.21 5,870.06 10.00 -80.97 5,985,418.98 546,170.80 9,615.00 90.06 331.61 6,590.31 5,333.60 -2,988.17 5,884.38 10.00 -80.80 5,985,432.22 546,163.76 10 9,700.00 89.91 323.12 6,590.33 5,405.11 -3,033.97 5,967.33 10.00 -91.00 5,985,503.43 546,117.49 9,800.00 89.74 313.12 6,590.63 5,479.47 -3,100.65 6,067.06 10.00 -91.00 5,985,577.34 546,050.34 9,815.00 89.72 311.62 6,590.70 5,489.57 -3,111.73 6,082.04 10.00 -90.97 5,985,587.37 546,039.19 11 9,900.00 91.48 319.93 6,589.81 5,550.43 -3,170.96 6,166.95 10.00 78.00 5,985,647.83 545,979.57 9,965.00 92.81 326.30 6,587.38 5,602.35 -3,209.92 6,231.22 10.00 78.09 5,985,699.49 545,940.27 12 10,000.00 93.11 322.81 6,585.57 5,630.82 -3,230.19 6,265.68 10.00 -85.00 5,985,727.83 545,919.81 10,090.00 93.82 313.82 6,580.12 5,697.84 -3,289.87 6,355.27 10.00 -85.18 5,985,794.45 545,859.70 13 10,100.00 93.63 314.80 6,579.47 5,704.81 -3,297.01 6,365.25 10.00 101.00 5,985,801.37 545,852.52 10,200.00 91.67 324.62 6,574.83 5,780.92 -3,361.52 6,464.68 10.00 101.06 5,985,877.04 545,787.52 10,300.00 89.66 334.42 6,573.67 5,866.99 -3,412.17 6,561.36 10.00 101.52 5,985,962.76 545,736.30 10,340.00 88.85 338.34 6,574.19 5,903.62 -3,428.20 6,598.59 10.00 101.63 5,985,999.29 545,720.04 14 10,400.00 88.86 332.33 6,575.39 5,958.11 -3,453.22 6,654.82 10.00 -90.00 5,986,053.61 545,694.66 10,500.00 88.90 322.33 6,577.35 6,042.17 -3,507.12 6,752.37 10.00 -89.88 5,986,137.31 545,640.22 10,540.00 88.92 318.33 6,578.11 6,072.95 -3,532.64 6,792.18 10.00 -89.68 5,986,167.91 545,614.50 15 10,600.00 90.17 312.46 6,578.59 6,115.65 -3,574.75 6,852.15 10.00 -78.00 5,986,210.33 545,572.11 10,665.00 91.53 306.10 6,577.62 6,156.78 -3,625.03 6,916.78 10.00 -77.95 5,986,251.13 545,521.57 16 10,700.00 91.52 302.60 6,576.69 6,176.52 -3,653.91 6,951.16 10.00 -90.00 5,986,270.67 545,492.56 31112013 2:07:28PM Page 4 COMPASS 2003.16 Build 69 ConocoPhillips Alaska Database: EDM Alaska Prod v16 Company: ConocoPhillips(Alaska) Inc. Project: Kuparuk River Unit Site: Kuparuk 1 H Pad Well: 11-1-19 Wellbore: 1 H-19AL 1-02 Design: 1 H-19AL1-02_wp02 ConocoPhillips or its affiliates Planning Report Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Well 1 H-19 Mean Sea Level 1 H-19 @ 96.00ft (1 H-19) True Minimum Curvature WIN .I BAKER HUGHES Planned Survey Measured TVD Below Vertical Dogleg Toolface Map Map Depth Inclination Azimuth System +W-S +EI-W Section Rate Azimuth Northing Easting (ft) (I (°) (ft) (ft) (ft) (ft) (°/100ft) (°) (ft) (ft) 10,800.00 91.48 292.60 6,574.06 6,222.78 -3,742.39 7,046.43 10.00 -90.09 5,986,316.35 545,403.79 10,900.00 91.40 282.60 6,571.54 6,252.96 -3,837.55 7,135.07 10.00 -90.36 5,986,345.90 545,308.44 10,915.00 91.38 281.10 6,571.17 6,256.04 -3,852.23 7,147.63 10.00 -90.61 5,986,348.89 545,293.74 17 11,000.00 89.61 289.41 6,570.44 6,278.38 -3,934.16 7,221.36 10.00 102.00 5,986,370.69 545,211.68, 11,065.00 88.25 295.77 6,571.65 6,303.33 -3,994.13 7,281.40 10.00 102.07 5,986,395.24 545,151.55 18 11,100.00 88.26 299.27 6,572.72 6,319.49 -4,025.15 7,314.77 10.00 90.00 5,986,411.20 545,120.43 11,200.00 88.30 309.27 6,575.73 6,375.71 -4,107.64 7,412.85 10.00 89.89 5,986,466.86 545,037.57 11,300.00 88.40 319.28 6,578.62 6,445.40 -4,179.12 7,512.67 10.00 89.59 5,986,536.08 544,965.65 11,400.00 88.54 329.28 6,581.29 6,526.46 -4,237.41 7,611.20 10.00 89.30 5,986,616.74 544,906.84 TD at 11400.00 31112013 2:07:28PM Page 5 COMPASS 2003.16 Build 69 ConocoPhillips or its affiliates ,edFA. ConocoPhillips Planning Report BAKER Aaska HUGHES Database: EDM Alaska Prod v16 Company: ConocoPhillips(Alaska) Inc. Project: Kuparuk River Unit Site: Kuparuk 1 H Pad Well: 11-1-19 Wellbore: 1 H-19AL1-02 Design: 1H-19AL1-02_wp02 Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Well 1 H-19 Mean Sea Level 1 H-19 @ 96.00ft (1 H-19) True Minimum Curvature Targets Target Name hit/miss target Dip Angle Dip Dir. TVD +N/-S +E/-W Northing Easting Shape (1) (1) (ft) (ft) (ft) (ft) (ft) Latitude Longitude 1 H-19AL1-02_T7 0.00 0.00 6,572.00 5,773.76 -3,474.64 5,985,869.14 545,674.46 70' 22' 20.084 N 149' 37' 43.609 W plan misses target center by 99.00ft at 10251.31ft MD (6573.80 TVD, 5823.99 N,-3389.35 E) Point 1H-19 CTD Polygon_So� 0.00 0.00 0.00 5,498.84 -3,946.50 5,985,591.16 545,204.45 70' 22' 17.378 N 149' 37' 57.410 W plan misses target center by 6605.62ft at 10300.00ft MD (6573.67 TVD, 5866.99 N,-3412.17 E) Polygon Point 1 0.00 5,498.84 -3,946.50 5,985,591.16 545,204.45 Point 2 0.00 4,756.24 -3,100.24 5,984,854.20 546,055.49 Point 3 0.00 2,257.57 -3,503.56 5,982,353.18 545,668.62 Point 4 0.00 2,270.54 -3,958.53 5,982,363.16 545,213.62 Point 5 0.00 5,498.84 -3,946.50 5,985,591.16 545,204.45 1 H-19AL1-02_T10 0.00 0.00 6,580.00 6,465.76 -4,224.18 5,986,556.14 544,920.46 70° 22' 26.886 N 149' 38' 5.549 W plan misses target center by 49.47ft at 11300.00ft MD (6578.62 TVD, 6445.40 N,-4179.12 E) Point 1 H-19 CTD Polygon_No 0.00 0.00 0.00 6,817.08 -4,266.88 5,986,907.13 544,875.46 70° 22' 30.341 N 149' 38' 6.804 W - plan misses target center by 6587.77ft at 11400.00ft MD (6581.29 TVD, 6526.46 N,-4237.41 E) - Polygon Point 1 0.00 6,817.08 -4,266.88 5,986,907.13 544,875.46 Point 0.00 5,035.68 -2,242.24 5,985,139.24 546,911.55 Point 3 0.00 4,229.82 -2,432.52 5,984,332.23 546,726.59 Point 0.00 5,043.41 -3,428.33 5,985,139.18 545,725.55 Point 5 0.00 6,132.02 -4,577.38 5,986,220.12 544,569.49 Point 6 0.00 6,817.08 -4,266.88 5,986,907.13 544,875.46 1 H-19A_Fault6 (copy) (c 0.00 0.00 0.00 5,490.26 -3,098.45 5,985,588.14 546,052.46 70° 22' 17.297 N 149° 37' 32.600 W plan misses target center by 6585.74ft at 10113.74ft MD (6578.63 TVD, 5714.59 N,-3306.62 E) Rectangle (sides W1,000.00 1-11.00 D0.00) 1 H-19A_FaultB (copy) (c 0.00 0.00 0.00 5,684.09 -3,374.21 5,985,780.14 545,775.46 70° 22' 19.203 N 149° 37' 40.670 W plan misses target center by 6575.56ft at 10200.00ft MD (6574.83 TVD, 5780.92 N,-3361.52 E) Rectangle (sides W1,000.00 1-11.00 D0.00) 1 H-19AL1-02_T1 (copy) 0.00 0.00 6,600.00 4,813.46 -2,682.86 5,984,914.15 546,472.45 70° 22' 10.643 N 149' 37' 20.435 W plan misses target center by 53.56ft at 9015.53ft MD (6599.17 TVD, 4857.17 N,-2651.91 E) Point 1 H-19A_Faultl (copy) (c 0.00 0.00 0.00 9,066.24 -4.104.07 5,989,157.09 545,023.48 70' 22' 52.462 N 149° 38' 2.077 W plan misses target center by 7055.61ft at 11400.00ft MD (6581.29 TVD, 6526.46 N,-4237.41 E) Polygon Point 1 0.00 9,066.24 -4,104.07 5,989,157.09 545,023.48 Point 2 0.00 6,724.80 -4,232.34 5,986,815.09 544,910.60 Point 0.00 9,066.24 -4,104.07 5,989,157.09 545,023.48 1 H-19A_FaultD (copy) (c 0.00 0.00 0.00 6,262.26 -4,150.51 5,986,353.15 544,995.46 700 22' 24.885 N 1490 38' 3.390 W plan misses target center by 6573.64ft at 11065.00ft MD (6571.65 TVD, 6303.33 N,-3994.13 E) Rectangle (sides W1,000.00 H1.00 D0.00) 1 H-19A_FaultC (copy) (c 0.00 0.00 0.00 6,133.02 -3,964.34 5,986,225.15 545,182.46 70° 22' 23.615 N 149' 37' 57.941 W plan misses target center by 6572.11ft at 11000.00ft MD (6570.44 TVD, 6278.38 N,-3934.16 E) Rectangle (sides W1,000.00 1-11.00 D0.00) 1H-19AL1-02_T6 0.00 0.00 6,592.00 5,494.95 -3,202.44 5,985,592.15 545,948.46 70° 22' 17.343 N 149° 37' 35.642 W plan misses target center by 60.26ft at 9882.16ft MD (6590.22 TVD, 5536.96 N,-3159.27 E) Point 1 H-19A_FaultA (copy) (c 0.00 0.00 0.00 5,044.09 -2,827.21 5,985,143.81 546,326.60 70' 22' 12.910 N 149' 37' 24.660 W plan misses target center by 6588.79ft at 9400.00ft MD (6587.67 TVD, 5133.78 N,-2909.86 E) Rectangle (sides W1,000.00 1-11.00 D0.00) 1H-19AL1-02_T9 0.00 0.00 6,570.00 6,175.06 -3,970.06 5,986,267.14 545,176.46 70° 22' 24.028 N 149° 37' 58.109 W - plan misses target center by 109.38ft at 11000.00ft MD (6570.44 TVD, 6278.38 N,-3934.16 E) 31112013 2:07:28PM Page 6 COMPASS 2003.16 Build 69 ConocoPhillips or its affiliates MAP.. ConocoPhillips Planning Report BAKER Alaska HUGHES Database: EDM Alaska Prod v16 Company: ConocoPhillips(Alaska) Inc. Project: Kuparuk River Unit Site: Kuparuk1HPad Well: 11-1-19 Wellbore: 1 H-19AL1-02 Design: 1H-19AL1-02_wp02 Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Well 1 H-19 Mean Sea Level 1 H-19 @ 96.00ft (1 H-19) True Minimum Curvature - Point 1 H-1 9AL1 -02_T3 (copy) 0.00 0.00 6,585.00 5,107.58-3,000.96 5,985,206.15 546,152.46 70' 22' 13.534 N 149' 37' 29.743 W plan misses target center by 94.09ft at 9406.97ft MD (6587.54 TVD, 5140.14 N,-2912.71 E) Point 1 H-19AL1-02_T2 (copy) 0.00 0.00 6,592.00 4,976.10-2,929.81 5,985,075.15 546,224.45 70° 22' 12.241 N 149' 37' 27.661 W plan misses target center by 97.32ft at 9287.84ft MD (6591.13 TVD, 5036.89 N. -2853.82 E) Point 1 H-19AL1-02_T4 (copy) 0.00 0.00 6,590.00 5.251.82-3,035.01 5,985,350.15 546,117.46 70' 22' 14.953 N 149' 37' 30.741 W plan misses target center by 77.63ft at 9556.56ft MD (6589.89 TVD, 5280.87 N,-2963.02 E) - Point 1 H-19AL1-02_T8 0.00 0.00 6,580.00 6,039.63-3,602.91 5,986,134.14 545,544.46 70" 22' 22.698 N 149' 37' 47.365 W plan misses target center by 74.19ft at 10565.64ft MD (6578.47 TVD, 6091.73 N,-3550.10 E) Point 1H-19AL1-02_T5 0.00 0.00 6,590.00 5,426.46-3,129.88 5,985,524.15 546,021.46 70° 22' 16.670 N 149° 37' 33.519 W plan misses target center by 58.55ft at 9780.03ft MD (6590.55 TVD, 5465.56 N,-3086.31 E) Point Casing Points Measured Vertical Casing Hole Depth Depth Diameter Diameter (ft) (ft) Name 5,345.00 4,174.22 9 5/8" 9-5/8 12-1/4 11,400.00 6,581.29 2 3/8" 2-3/8 3 Formations Measured Vertical Dip Depth Depth Dip Direction (ft) (ft) Name Lithology C) (�) 8,812.54 6,607.00 Formation 2 0.00 Plan Annotations Measured Vertical Local Coordinates Depth Depth +N/-S +El-W (ft) (ft) Ift) (ft) Comment 8,740.47 6,584.09 4,635.55 -2,505.36 TIP 8,760.00 6,592.08 4,650.36 -2,515.26 KOP 8,790.00 6,601.97 4,674.64 -2,529.78 Start 30 dls 8,865.00 6,609.42 4,742.94 -2,558.63 4 8,965.00 6,601.87 4,825.27 -2,612.84 5 9,065.00 6,598.02 4,885.20 -2,692.64 Start 10 dls 9,215.00 6,594.08 4,980.60 -2,807.78 7 9,390.00 6,587.90 5,124.72 -2,905.64 8 9,490.00 6,588.27 5,218.12 -2,941.01 9 9,615.00 6,590.31 5,333.60 -2,988.17 10 9,815.00 6,590.70 6,489.57 -3,111.73 11 9,965.00 6,587.38 5,602.35 -3,209.92 12 10,090.00 6,580.12 5,697.84 -3,289.87 13 10,340.00 6,574.19 5,903.62 -3,428.20 14 10,540.00 6,578.11 6,072.95 -3,532.64 15 10,665.00 6,577.62 6,156.78 -3,625.03 16 10,915.00 6,571.17 6,256.04 -3,852.23 17 11,065.00 6,571.65 6,303.33 -3.994.13 18 11,400.00 6,581.29 6,526.46 -4,237.41 TD at 11400.00 3/1/2013 2:07:28PM Page 7 COMPASS 2003.16 Build 69 �IA cog 11 pm � as c a T u IMEMEM■■■MMEME■■1 IM■■EMEMMUMENEEMI I■MEMERMHUME EME1 IMEM■NREMBEEMEME-1 loommau-®EEKmommo1 I®MEMEMER.�l� ■�®��®III o - o m a om a o (�/U OOZ) (t)uuON/(- glllOS 0 a a z z 0 o o 0 o "cam v�i,rn ��YMmm'i��N'Rmm�?�N �Ou NcS °j's "BmFIONN'=; 2 �mNNN��4R0000^o600cs cs d c� pp y o�N o-iLS3��oo��S�N wM V VQ o o o fAhmOst l�o�F^tGO INhm12 hc'twm�va �Nw�ry�R�� 9iu�i 5 � 0w'^m lgmmrvmoorniy �nc��'�m�m s� �oo� �o^N�mm��mm�m zo v m2i my EN a oo��mwrnui ci�ui m m ti m rn rn rn rn m a m rn rn m m rn m m ao 30 �v000000S0000S000�oS mmN o-o ------m--��mr a� 4 — S O O Z .- � O 2 R � x 4 x F� F W � wi x 4 2 S 5 - x �a a x g m T 2. d (u?/U 96) tgd3a Iv3pj3A onll KUP 1 H-19 ConocC Phil ipS Well Attributes Max Angle & MD TD Alaska, Inc. Wellbore APl/U1 Field Name Well Status Inca (') MD (ftKB) Act SIM (ftKB) 5002922312(q KUPARUK RIVER UNIT INJ 46.17 5,677.00 8,990.0 Comment I H2S (ppmJ Date Annotation End Date KB -Ord (it) Rig Release Date - WellCor :-1H-191019/201210,36:06AM SSSV:WRDP Last WO: 6/14/1993 12/18/1992 Schematk-Actual Annotation Depth(ftKB) Last Tag: SLM 8,683.0 End Date Annotation 10/2/2012 Rev Reason: GLV C/O, TAG, PULL SLEEVE Last Mod ... ninam End Date 10/9/2012 HANGER, 38 CONDUCTOR. 42-121 NIPPLE. 1,810 Casing Strings Casing Description CONDUCTOR String 0... 16 String ID ... 15.060 Top (ftKB) 41.9 Set Depth (f... 121.0 Set Depth (TVD) ... 121.0 String Wt... 62.50 String ... H40 String Top Thrd WELDED I` I l.._.l J Casing Description SURFACE String 0... 9 518 String 10 ... 8.835 Top (ftKB) 41.9 Set Depth If... 5,344.6 Set Depth (TVD) ... 4,269.9 String Wt... 40.00 String ... L-80 String Top Thrd BTC Casing Description PRODUCTION String 0... 7 String ID ... 6.276 Top (ftKB) 35.2 Set Depth if... 8,970.2 Set Depth (TVD) ... 6,913.2 String Wt... 26.00 String... J-55 String Top Thrd I AB -MOD Tubing Strings Tubing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (ND) ... String Wt... String ... String Top Thrd TUBING 3.5 x 2.875 3 1/2 2.992 37.E 8,599.8 6,632.4 9.30 J-55 ABM-EUE Completion Details Top (ftKB) Top Depth (TVD) (ftKB) Topincl (a) hem Description Comment Nomi.. ID (in) 37.6 37.6 0.05 HANGER FMC GEN IV HANGER 3.50( 1,810.1 1,692.1 37.81 NIPPLE OTIS SELECTIVE LANDING NIPPLE 2.81: 8,229.7 6,360.9 43.39 PBR OTIS PBR 2.97( 8,241.9 6,369.8 43.66 PACKER OTIS HVT RETRIEVABLE PACKER 2.97, 8,337.2 6,439.1 43.19 BLAST JTS BLASTJOINTS 2.99, 8,526.6 6,578.1 42.32 NIPPLE AVA BPL PORTED NIPPLE 2.32( 8,560.7 6,603.4 42.08 XO Reducing CROSSOVER 3.5 x 2.875 2.87E 8,565.5 6,607.0 42.05 SEAL ASSY BAKER GBH-22 LOCATOR SEAL ASSEMBLY 2.40E 8,568.E 6,609.3 42.03 PACKER BAKER D PERMANENT PACKER (2' SPACE OUT ABOVE PKR) 3.25C 8,587.3 6,623.2 41.84 NIPPLE CAMCO D NIPPLE NO GO 2.25C 8,599.0 6,631.8 41.82 SOS OTIS SHEAR OUT SUB. ELMD TTL 8596' ON 5/29/06 2.441 Top (TVD) I Btm (TVD) GAS LIFT, Top (ftKB) I Bt. (ftKB) (it (ftKB) Zone Data e,1eo 8,3401 8,4041 6,441.1 6,487.9 C-4, C-3, 1H-19 6/14/19! 8,430 8,470 6,5(I6.9 6,536.3 C-2, C-1, UNIT 6/14/19S ti B, 1H-19 PBR, 8.230 KER, 8,242 INJECTION, 8,294 IPERF, 8.340-8,404 IPERF, 8,43".470 NIPPLE,6527 SEAL ASSY, 8.566 NIPPLE, 8,587 SOS, 8,599 () I Inl I I I OD I I V,I- I Latch I Size ITRORunI Stn Too (ftKB) ftKB) (; Make Model (in) Sery Type Type (in) (psi) Run Date Com... RPERF, 8,67341,693 RPERF, 8,706-8,726 rioN, 8,970 i 8,990 Cl) 04 06 to m LL N 0 IN p a0 a g m U 0 m Y Y K N n a)v n O O V U n ❑ Q Q M N N 0� O OI - G m C co ❑ 2 � �1 V Q7 'o N R 7 �N N (0 -QvN an _v I� N a t~+1 a �In ❑ T C N C m E m U M N c m N I- E Q� �Y N 3 m❑In m �O E L o U U C N61 Gf Mn O 0. CL mcDva > m �O�--,,�� (D (CA 6 C (0 ��O11 a LSI Q aa) m U@ �E 2 a r Uv'C *`m❑c IC) N U 111 dW U co O a N Y NUCJ rn M ai U N� m U 7 W j Q mamas ob [V cV N N [V CV N Y Y 00 3 ` iz M M 8-8 M (7 CM m(0 m(6 N a a❑ oQ ocli � -j � to D c� oo � _ 0 Q1 p m� n p m` 4rn mrn it c 2 0 o +-f-J 07 �1 h v m a N ❑ N p� D O L N N N a ^ O -0a CL r. 0 U1 to NO a� y�M N@(O �❑ a� cc) 6 0 "6 C O Qv/W Nf` Q �N 00 N r C f0 O 0 ism Um Um L N 2 QO N 1C- t � II _ P Ferguson, Victoria L (DOA) From: Ferguson, Victoria L (DOA) Sent: Wednesday, March 06, 2013 10:28 AM To: 'Ohlinger, James X Subject: RE: 1 H-19 Naming You have already submitted a PTD for 1H-19AL1-02. Please modify this submission renaming it 1H-19AL1-01 and send me the modified PTD. I will change the pages out and keep the same PTD number(PTD 213-032). Close the remaining out with 407s(APB1, AL1PB1, AL1-0113131). From: Ohlinger, James J jmailto:James.J.Ohlinger@conocophillips. com] Sent: Wednesday, March 06, 2013 9:17 AM To: Ferguson, Victoria L (DOA) Subject: RE: 1H-19 Naming Correction... From: Ohlinger, James J Sent: Wednesday, March 06, 2013 9:16 AM To: 'Ferguson, Victoria L (DOA)' Subject: RE: 1H-19 Naming Do I need to submit something to adjust the Permit for the 1H-19AL1-01 lateral? Permit had kickoff point at 10370' MD, it was then lost so became 1H-19AL1-01PB1. We then kicked off at 8760' MD, was verbally approved for 1H-19AL1-02. However makes more sense to label it 1H- 19AL1-01. Please let me know what or if I need to submit anything, or just close them out with the 407's. From: Ferguson, Victoria L (DOA) rmailto:victoria.fergusonCabalaska.gov] Sent: Tuesday, March 05, 2013 9:58 AM To: Ohlinger, James J Subject: [EXTERNAL]RE: 1H-19 Naming We'd recommend naming the brown -colored segment 1H-19AL1-01 rather than 1H-19AL1-02. Otherwise it looks fine. From: Ohlinger, James J fmailto:James.J.OhlingerCa>conocophillips.com] Sent: Monday, March 04, 2013 8:32 AM To: Ferguson, Victoria L (DOA) Cc: Schwartz, Guy L (DOA) Subject: 1H-19 Naming I've attached two schematics. The first is the proposed naming, the second the completion. Ferguson, Victoria L (DOA) From: Davies, Stephen F (DOA) Sent: Monday, March 04, 2013 11:40 AM To: Ferguson, Victoria L (DOA) Cc: Schwartz, Guy L (DOA) Subject: RE: 1 H-19 Naming Victoria, I'd recommend calling the brown -colored wellbore segment 1H-19AL1-01 rather than 1H-19AL1-02, otherwise this looks file so long as the plug -backs are really plugged back with cement. I'd highly recommend placing color copies of the final version of this diagram in the history files for 11-1-19, 1H-19A, 1H- 19AL1, 1H-19AL1-01, and 1H-19AL2. Thanks, Steve D From: Ferguson, Victoria L (DOA) Sent: Monday, March 04, 2013 11:26 AM To: Davies, Stephen F (DOA) Cc: Schwartz, Guy L (DOA) Subject: Fwd: 1H-19 Naming Steve, Could you please look at 1H-19 laterals and Plug backs attached and see if you agree with the naming convention proposed or if you would propose something different. Thanx, Victoria Sent from my Whone Begin forwarded message: From: "Ohlinger, James J" <James.J.Ohlinger@conocophillips.com> Date: March 4, 2013, 8:32:14 AM AKST To: "'Ferguson, Victoria L (DOA)"' <victoria.ferguson@alaska.gov> Cc: "'Schwartz, Guy L (DOA)"' <guy.schwartz@alaska.gov> Subject: 1H-19 Naming I've attached two schematics. The first is the proposed naming, the second the completion. Please review and let me know if this is ok, or if I need to adjust the naming. Thanks. W O CL L a E L waY W m a L O E m z O 1-1 O O '-1 N N .--I N fV N N N N N (V 4 e-1 e-I c-1 '-i r-1 r-/ '-I m m rn m m m m m N N N N N N N N N N N N N N N N N N N N N N N lV O O O o q O O O 0 0 0 0 O 0 0 0 Iri u'i ui Ln Ln Ln un U') o In .-I o N m Ln OA � 'r-i O 1.0 ci a) a--1 -/ r-I 'A 00 ,1 0) 1-4 .-I z r-I 14 -41 N-N N Ln m t0 .4 0 0) 000000 o rn rqm 00 1-4 1.4 a m 11 `-1 r-4 o 0 m e-i aa-I a Q a a a a a r—I 71 � 0) N J Q 24 i I i I I I I I i I i I I I I 1 I i 1 I I J Q rr-i co CL . r-I I 0 i 1 e-i J i Q I /1 s N Q) 0 CL L 0 CL c 0 a 0. E 0 V i 0 to E m z 1 - Q c3i 1 r; 0001J 90 � D I 1 TRANSMITTAL LETTER CHECKLIST WELL NAME RILL 111 - I t A L l- 01 PTD# a 130321 Development " Service Exploratory Stratigraphic Test Non -Conventional Well FIELD: POOL: 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 0,IL Y (If last two digits in permit No.a 13 oco3 , API No. 50-D9-�2212 - 6O - Gb. 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 tar et 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: 9/09/201 1 WELL PERMIT CHECKLIST Field & Pool KUPARUK RIVER, KUPARUK RIV OIL - 490100 PTD#:2130320 Company CONOCOPHILLIPS ALASKA INC Initial Class/Type Well Name: KUPARUK RIV UNIT 1 H-19AL1-01 Program SER Well bore seg y SER / PEND GeoArea 890 Unit 11160 On/Off Shore On Annular Disposal Administration 17 Nonconven. gas conforms to AS31.05.030(j.1.A),(j.2.A-D) NA 1 Permit fee attached NA 2 Lease number appropriate Yes ADL0025639 Surf loc and Top Prod Interv; ADL0025636 Prod Intery (portion of); ADL0025635 3 Unique well name and number Yes KRU 1H-19AL1-01 4 Well located in a defined pool Yes KUPARUK RIVER, KUPARUK RIV OIL - 490100; governed by Conservation Order No. 432C 5 Well located proper distance from drilling unit boundary Yes CO No. 432C contains no spacing restrictions with respect to drilling unit boundaries. 6 Well located proper distance from other wells Yes CO No. 432C has no interwell spacing restrictions 7 Sufficient acreage available in drilling unit Yes 8 If deviated, is wellbore plat included Yes 9 Operator only affected party Yes Wellbore will be more than 500' from an external property line where ownership or landownership changes. 10 Operator has appropriate bond in force Yes Appr Date 11 Permit can be issued without conservation order Yes 12 Permit can be issued without administrative approval Yes PKB 3/8/2013 13 Can permit be approved before 15-day wait Yes 14 Well located within area and strata authorized by Injection Order # (put 10# in comments) (For Yes Area Injection Order No. 2B-Kuparuk River Unit 15 All wells within 1/4 mile area of review identified (For service well only) Yes 1H-19A, 1R-29, 1R-291-1-01, 1R-29L1, 1R-02, 1H-19AL1 16 Pre -produced injector: duration of pre -production less than 3 months (For service well only) Yes per James Ohlinger (ConocoPhillips) 18 Conductor string provided NA Conductor set in 1 H-19 Engineering 19 Surface casing protects all known USDWs NA Surface casing set in 1 H-19 20 CMT vol adequate to circulate on conductor & surf csg NA Surface casing set and fully cemented 21 CMT vol adequate to tie-in long string to surf csg NA 22 CMT will cover all known productive horizons No Production interval will be completed with 2-3/8" slotted liner 23 Casing designs adequate for C, T, B & permafrost Yes 24 Adequate tankage or reserve pit Yes Rig has steel pits. All waste to approved disposal wells. 25 If a re -drill, has a 10-403 for abandonment been approved Yes 312-473 26 Adequate wellbore separation proposed Yes Proximity analysis performed 27 If diverter required, does it meet regulations NA Appr Date 28 Drilling fluid program schematic & equip list adequate Yes Max form pressure 4200 psi(11.0 ppg EMW) Will drill with 9.6 mud and use MPD VLF 3/13/2013 29 BOPEs, do they meet regulation NA 30 BOPE press rating appropriate; test to (put psig in comments) Yes MPSP is 3550 psi. Will test BOPS to 4000 psi 31 Choke manifold complies w/API RP-53 (May 84) Yes 32 Work will occur without operation shutdown Yes 33 Is presence of H2S gas probable Yes H2S measures required 34 Mechanical condition of wells within AOR verified (For service well only) Yes AOR performed 35 Permit can be issued w/o hydrogen sulfide measures No Wells on 1H-Pad are H2S-bearing. H2S measures required. Geology 36 Data presented on potential overpressure zones Yes Expected reservoir pressure is 11.9 ppg EMW; will be drilled using 9.6 ppg mud and managed Appr Date 37 Seismic analysis of shallow gas zones NA pressure drilling technique. Two well volumes of 13.1 ppg emergency kill weight mud will be available. PKB 3/8/2013 38 Seabed condition survey (if off -shore) NA Onshore pad 39 Contact name/phone for weekly progress reports [exploratory only] NA Geologic Engineering Public Commissioner: Date: Commission : Date Co i . Date Cs jS V (j- 0 "Z