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Home My WebLink About208-0961. Type of Request: Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown Suspend Perforate Other Stimulate Pull Tubing Change Approved Program Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: Exploratory Development 3. Address: Stratigraphic Service 6. API Number: 7. If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Yes No 9. Property Designation (Lease Number): 10. Field: 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: Junk (MD): 11,501 8,095 Casing Collapse Structural Conductor Surface 3,090psi Intermediate Production 5,410psi Liner Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): 12. Attachments: Proposal Summary Wellbore schematic 13. Well Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: OIL WINJ WDSPL Suspended 16. Verbal Approval: Date: GAS WAG GSTOR SPLUG AOGCC Representative: GINJ Op Shutdown Abandoned Contact Name: Eric Dickerman Contact Email:Eric.Dickerman@hilcorp.com Contact Phone:(907) 564-4061 Authorized Title: Conditions of approval: Notify AOGCC so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other Conditions of Approval: Post Initial Injection MIT Req'd? Yes No APPROVED BY Approved by: COMMISSIONER THE AOGCC Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng 1/4/2026 4-1/2" See schematic See schematic Perforation Depth MD (ft): 6,750 - 6,989 9,982' 4,591 - 4,722 6,505'7" 9,982' 30" 9-5/8" 400' 4,747' MD 5,750psi 400' 3,486' 400' 4,747' Length Size Proposed Pools: L-80 TVD Burst 7,052 7,240psi STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0017589 / ADL0037831 208-096 3800 Centerpoint Drive, Suite 1400, Anchorage, AK 99503 50-883-20125-00-00 Hilcorp Alaska, LLC N Cook Inlet Unit A-14 AOGCC USE ONLY Tubing Grade: Tubing MD (ft):Perforation Depth TVD (ft): Operations Manager Subsequent Form Required: Suspension Expiration Date: Will perfs require a spacing exception due to property boundaries? Current Pools: MPSP (psi): Plugs (MD): 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name and Digital Signature with Date: Tubing Size: PRESENT WELL CONDITION SUMMARY Other: CT FCO, N2 North Cook Inlet Tertiary System Gas Same 7,482 7,036 4,748 1,201psi See schematic CO 68A No Form 10-403 Revised 06/2023 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov Digitally signed by Dan Marlowe (1267) DN: cn=Dan Marlowe (1267) Date: 2025.12.16 11:42:32 - 09'00' Dan Marlowe (1267) 325-762 By Grace Christianson at 12:36 pm, Dec 16, 2025 A.Dewhurst 16DEC25 10-404 MGR19DEC2025 * Service coil BOPE pressure test to 3000 psi. 48-hour notice to AOGCC for opportunity to witness. JLC 12/19/2025 12/19/25 Downhole Recomplete Well: North Cook Inlet Unit A-14 Well Name:NCIU A-14 API Number:50-883-20125-00-00 Current Status:Online, Gas Well Leg:Leg #2 (SW corner) Regulatory Contact:Juanita Lovett (8332)Permit to Drill Number:208-096 First Call Engineer:Eric Dickerman (907) 564-4061 Second Call Engineer:Casey Morse (907) 777-8322 Maximum Expected BHP:1,660 psi at 4,591 TVD - 0.37 psi/ft Shut in BHP survey 11/5/2022 Max. Potential Surface Pressure: 1,201 psi MPSP -0.1 psi/ft gas grad. to surface Field/Pool: North Cook Inlet Unit, Tertiary System Gas Pool Brief Well Summary: NCIU A-14 was drilled and completed in April 2009 in the Beluga Formation with a gravel pack completion. In October 2012, a deep gas lift system was installed through tubing. This deep gas lift system was pulled and replaced in January 2015. In May 2022, the deep gas lift system was removed and the IA was cemented to add perforations above the production packer. A water shut off was performed in November 2022, and perforations were added through the gravel pack screens. The well experienced high solids production (gravel pack sand) after perforating through the gravel pack screens. A removable bridge plug was installed above the gravel pack screens in May 2023 that stopped solids production, but also significantly reduced gas production rates. Objective: Produce from entire production interval. Pull plug. Flow test. Contingent coil cleanout and plug pull based on slickline pre-work. Because the gravel pack sand is a known fixed amount (13,688 # of 20/40), the objective is to cleanout the well, then flow until solids production ceases or drops to manageable rates. If this is not successful, the well will be returned to its current configuration. Wellbore information: North Cook Inlet Unit, Tertiary System Gas Pool top = Top of Sterling sands, at 4,393 md / 3,284 tvd. North Cook Inlet Unit, Tertiary System Gas Pool Bottom = Base of Beluga sands (below TD). Well is completed with a wireline retrievable subsurface safety valve. Downhole Recomplete Well: North Cook Inlet Unit A-14 Pre-sundry Wellwork Slickline: 1. MIRU Slickline. 2. Pressure test PCE 250 low / 2,000 psi high. 3. Pull SSSV at 472. 4. Pull 4-1/2 DD Packoff Plug at 7,036. 5. Drift and tag top of fill, bail as directed. 6. RDMO Slickline. Hand well over to production for flow test. Sundry Wellwork CONTINGENT Coiled Tubing Cleanout (if slickline is unable to recover plug or bail fill at a reasonable rate): 7. MIRU Fox Offshore Coiled Tubing Unit #9, pressure control equipment, and portable test unit. 8. Pressure test BOP and PCE to 250 psi low / 3,000 psi high. a. Provide AOGCC with 48 hr witness notification for BOP test. 9. Pull 4-1/2 DD Packoff Plug at 7,036 if slickline is unable to recover. 10. MU cleanout BHA. Dry tag top of fill, then begin cleaning out to Quadco Retainer at 8,035. b. Working fluid will be 6% KCl (8.6 ppg). c. Take returns to surface from the coiled tubing by 4-1/2 annulus. d. Add foam and nitrogen as necessary to carry solids to surface. 11. Hand well over to production to test. 12. Repeat fill cleanout as necessary. 13. RDMO CTU. CONTINGENT Slickline: (if unable to handle solids production) 14. MIRU Slickline. 15. Pressure test PCE to 250 psi low / 2,000 psi high. 16. Set 4-1/2 DD Packoff Plug to shut off unwanted perforated interval per Operations Engineer. 17. Set SSSV at 472. 18. RDMO Slickline. Operations: 19. Perform SVS test within 5 days of stable production. a. Provide AOGCC with 48 hr witness notification. Attachments: 1. Current Wellbore Schematic 2. Proposed Wellbore Schematic 3. CT BOP Drawing 4. Nitrogen procedure ____________________________________________________________________________________ Updated by EPD 12/15/25 North Cook Inlet Well:NCI A-14 Last Completed: 04/23/2009 PTD: 208-096 API: 50-883-20125-00-00 SCHEMATIC PBTD: 7,036 TD: 11,501 7 2 3 4 5 6 7 8 10 Beluga B 9-5/8 30 TOC @ 4,747 USIT 2008 11 13 7a 1 Beluga C Beluga D Beluga E Beluga F Beluga G Beluga M Beluga Q Beluga A TOC @6,600 5/18/22 Tbg Punches @ 6993-6996 5/16/22 Tag at 7163 with 3 bailer 5/15/23 12 SL Plug @ 7,036 Set 5/15/23 9 X CASING DETAIL Size Wt Grade Conn ID Top Btm 30 120.00 X-56 27.000 Surf 400 9-5/8 40.00 L-80 BTCM 8.835 Surf 4,747 7 26.00 L-80 BTCM 6.275 Surf 9,982 TUBING DETAIL 4-1/2 12.60 L-80 IBTM 3.958 Surf 7,052 JEWELRY DETAIL No Depth (MD) Depth (TVD)ID Item 23' 23' 3.900 Tubing Hanger - Vetco 1 472' 472' 3.813 SLB BP6i Landing Nipple: WL SSSV (Set 11/19/22) 2 6,926' 4,687' 3.813 X Nipple 3 7,008' 4,732' 3.880 Locator 7,011' 4,734' 4.750 Anchor PBR 7,035 4,747 -- AA Stop 7,036 4,748 -- 4-1/2 DD Packoff Plug (set 5/15/23) 7,039 4,750 -- AA Stop 7,039' 4,750' 4.000 Gravel Packer (Baker SC-2) 7,040' 4,750' 3.260 Seal Assy (Seal Unit 82-40) 7,047' 4,754' 4.000 Seal Bore Extension 7,051' 4,756' 3.260 WLEG 7,077' 4,771' 3.430 Shear Out Safety Jt 4 7,153' 4,813' 3.430 Excluder Screen 2000 5 7,419' 4,960' 3.430 Excluder Screen 2000 6 7,744' 5,137' 3.430 Excluder Screen 2000 7 7,892' 5,218' 3.430 Excluder Screen 2000 7a 8,035 5,296 -- Quadco TTS 4 Paragon 2 Ret. Packer 8 8,040' 5,298' 3.430 Excluder Screen 2000 9 8,237' 5,409' 3.260 Snap Latch 82-40 S22B 8,238' 5,409' 3.260 Seal Unit (82-40 90H) 8,238' 5,409' 4.000 Packer (Sump Model FS) 8,241' 5,411' 3.260 1/2 Mule Shoe 8,244' 5,413' 3.000 Crossover 5.5"x3.5" 10 8,563' 5,604' 3.010 WLEG 11 8,944 5,851 0.000 CIBP 12 9,441' 6,167' 0.000 Frac Sand 13 9,801' 6,391' 0.000 CIBP GAS LIFT MANDRELS STA MD TVD ID Valve Name Port Valve Type Psc Date 1 1,789' 1,754'Camco KBG-2-1R DUMMY 05/13/2023 2 3,485' 2,798'BK 16 DOME 859 05/13/2023 3 4,949' 3,599'BK 16 DOME 834 05/13/2023 4 6,024' 4,192'Gen 2 Mod 28 ORIFICE 05/13/2023 5 6,752'4,592'Camco KBG-2-1R DUMMY Cemented 6 6,839'4,640'Camco KBG-2-1R DUMMY Cemented FISH DETAIL @ ~8,095 5/31/22 EL Fish in Hole: 1' x 1 7/16" GO Cable Head w/ 1" Fish Neck, 5' x 3- 1/8" Gun Gamma, 3' x 2-3/4" Shock Sub, 24' x 2-7/8" Perforating Guns. OAL 33.1' Cement Details 9-5/812-1/4 Hole: Cemented with 1310sxs of 12.0ppg Type-1 cement. No losses and 70bbls returned to surface.ToC at surface. 78-3/4 Hole: Cemented with 254bbls 12.9ppg class G cement.11/29/08 USIT shows ToC at 4747 MD. ____________________________________________________________________________________ Updated by JLL 12/06/24 North Cook Inlet Well:NCI A-14 Last Completed: 04/23/2009 PTD: 208-096 API: 50-883-20125-00-00 SCHEMATIC Perforation Data Zone Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT Date Status Beluga A Upper 6,750 6,7634,591 4,598135/23/2022 Open Beluga A Lower 6,839 6,8694,640 4,656305/23/2022 Open Beluga B Upper 1 6,909 6,918 4,678 4,68395/22/2022 Open Beluga B Upper 2 6,938 6,9544,694 4648165/22/2022 Open Beluga B Upper 3 6,969 6,9894,711 4,722205/22/2022 Open Beluga B 7,161' 7,173' 4,817' 4,824' 12' 4/15/2009 Isolated 5/15/23 Beluga B Lower 7,162 7,1724,817' 4,824'1011/06/22 Isolated 5/15/23 Beluga C 7,220' 7,259' 4,850' 4,872' 39' 4/15/2009 Isolated 5/15/23 Beluga C Upper 7,220 7,259 4,850' 4,872'3911/06/22 Isolated 5/15/23 Beluga C 7,276' 7,283' 4,881' 4,885' 7' 4/15/2009 Isolated 5/15/23 Beluga C Mid 7,276 7,2824,881' 4,885'611/05/22 Isolated 5/15/23 Beluga C Lower 7,313 7,3184,902,4904511/05/22 Isolated 5/15/23 Beluga D Mid 7,471 7,485 4,989 4,9961411/05/22 Isolated 5/15/23 Beluga D 7,553' 7,608' 5,033' 5,063' 55' 4/15/2009 Isolated 5/15/23 Beluga D Lower 7,553 7,5935,033' 5,0554011/05/22 Isolated 5/15/23 Beluga D 7,639' 7,664' 5,080' 5,093' 25' 4/15/2009 Isolated 5/15/23 Beluga E Upper 1 7,639 7,6595,080' 5,0912011/04/22 Isolated 5/15/23 Beluga E Upper 2 7,678 7,6985,101 5,1122011/04/22 Isolated 5/15/23 Beluga E Mid 7,758 7,765 5,145 514875/22/22 Isolated 5/15/23 Beluga E 7,807' 7,827' 5,171' 5,182' 20' 4/15/2009 Isolated 5/15/23 Beluga E Lower 7,807 7,827 5,171' 5,182'205/22/22 Isolated 5/15/23 Beluga F 7,937' 7,945' 5,242' 5,247' 8' 4/15/2009 Isolated 5/15/23 Beluga F Upper 7,937 7,945 5,242' 5,247'85/21/22 Isolated 5/15/23 Beluga F 7,995' 8,005' 5,274' 5,279' 10' 4/15/2009 Isolated 5/15/23 Beluga F Mid 7,995 8,0055,274' 5,279'105/21/22 Isolated 5/15/23 Beluga G 8,068' 8,083' 5,314' 5,322' 15' 10/31/22 H2Zero - WSO Beluga G 8,198' 8,228' 5,386' 5,404' 30' 10/31/22 H2Zero - WSO Beluga G 8,214' 8,246' 5,395' 5,414' 32' 10/31/22 H2Zero - WSO Beluga M 9,023' 9,040' 5,902' 5,913' 17' 4/8/2009 Plugged Beluga Q 9,604' 9,624' 6,270' 6,282' 20' 4/8/2009 Plugged ____________________________________________________________________________________ Updated by EPD 12/15/25 North Cook Inlet Well:NCI A-14 Last Completed: 04/23/2009 PTD: 208-096 API: 50-883-20125-00-00 PROPOSED SCHEMATIC PBTD: 7,036 TD: 11,501 7 2 3 4 5 6 7 8 10 Beluga B 9-5/8 30 TOC @ 4,747 USIT 2008 11 13 7a 1 Beluga C Beluga D Beluga E Beluga F Beluga G Beluga M Beluga Q Beluga A TOC @6,600 5/18/22 Tbg Punches @ 6993-6996 5/16/22 Tag at 7163 with 3 bailer 5/15/23 12 9 X CASING DETAIL Size Wt Grade Conn ID Top Btm 30 120.00 X-56 27.000 Surf 400 9-5/8 40.00 L-80 BTCM 8.835 Surf 4,747 7 26.00 L-80 BTCM 6.275 Surf 9,982 TUBING DETAIL 4-1/2 12.60 L-80 IBTM 3.958 Surf 7,052 JEWELRY DETAIL No Depth (MD) Depth (TVD)ID Item 23' 23' 3.900 Tubing Hanger - Vetco 1 472' 472' 3.813 SLB BP6i Landing Nipple: WL SSSV (Set 11/19/22) 2 6,926' 4,687' 3.813 X Nipple 3 7,008' 4,732' 3.880 Locator 7,011' 4,734' 4.750 Anchor PBR 7,0354,747--AA Stop 7,0364,748--4-1/2 DD Packoff Plug (set 5/15/23) 7,0394,750--AA Stop 7,039' 4,750' 4.000 Gravel Packer (Baker SC-2) 7,040' 4,750' 3.260 Seal Assy (Seal Unit 82-40) 7,047' 4,754' 4.000 Seal Bore Extension 7,051' 4,756' 3.260 WLEG 7,077' 4,771' 3.430 Shear Out Safety Jt 4 7,153' 4,813' 3.430 Excluder Screen 2000 5 7,419' 4,960' 3.430 Excluder Screen 2000 6 7,744' 5,137' 3.430 Excluder Screen 2000 7 7,892' 5,218' 3.430 Excluder Screen 2000 7a 8,035 5,296 -- Quadco TTS 4 Paragon 2 Ret. Packer 8 8,040' 5,298' 3.430 Excluder Screen 2000 9 8,237' 5,409' 3.260 Snap Latch 82-40 S22B 8,238' 5,409' 3.260 Seal Unit (82-40 90H) 8,238' 5,409' 4.000 Packer (Sump Model FS) 8,241' 5,411' 3.260 1/2 Mule Shoe 8,244' 5,413' 3.000 Crossover 5.5"x3.5" 10 8,563' 5,604' 3.010 WLEG 11 8,944 5,851 0.000 CIBP 12 9,441' 6,167' 0.000 Frac Sand 13 9,801' 6,391' 0.000 CIBP GAS LIFT MANDRELS STA MD TVD ID Valve Name Port Valve Type Psc Date 1 1,789' 1,754'Camco KBG-2-1R DUMMY 05/13/2023 2 3,485' 2,798'BK 16 DOME 859 05/13/2023 3 4,949' 3,599'BK 16 DOME 834 05/13/2023 4 6,024' 4,192'Gen 2 Mod 28 ORIFICE 05/13/2023 5 6,752'4,592'Camco KBG-2-1R DUMMY Cemented 6 6,839'4,640'Camco KBG-2-1R DUMMY Cemented FISH DETAIL @ ~8,095 5/31/22 EL Fish in Hole: 1' x 1 7/16" GO Cable Head w/ 1" Fish Neck, 5' x 3- 1/8" Gun Gamma, 3' x 2-3/4" Shock Sub, 24' x 2-7/8" Perforating Guns. OAL 33.1' Cement Details 9-5/812-1/4 Hole: Cemented with 1310sxs of 12.0ppg Type-1 cement. No losses and 70bbls returned to surface.ToC at surface. 78-3/4 Hole: Cemented with 254bbls 12.9ppg class G cement.11/29/08 USIT shows ToC at 4747 MD. ____________________________________________________________________________________ Updated by JLL 12/06/24 North Cook Inlet Well:NCI A-14 Last Completed: 04/23/2009 PTD: 208-096 API: 50-883-20125-00-00 PROPOSED SCHEMATIC Perforation Data Zone Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT Date Status Beluga A Upper 6,750 6,7634,591 4,598135/23/2022 Open Beluga A Lower 6,839 6,8694,640 4,656305/23/2022 Open Beluga B Upper 1 6,909 6,918 4,678 4,68395/22/2022 Open Beluga B Upper 2 6,938 6,9544,694 4648165/22/2022 Open Beluga B Upper 3 6,969 6,9894,711 4,722205/22/2022 Open Beluga B 7,161' 7,173' 4,817' 4,824' 12' 4/15/2009 Open Beluga B Lower 7,162 7,1724,817' 4,824'1011/06/22 Open Beluga C 7,220' 7,259' 4,850' 4,872' 39' 4/15/2009 Open Beluga C Upper 7,220 7,259 4,850' 4,872'3911/06/22 Open Beluga C 7,276' 7,283' 4,881' 4,885' 7' 4/15/2009 Open Beluga C Mid 7,276 7,2824,881' 4,885'611/05/22 Open Beluga C Lower 7,313 7,3184,902,4904511/05/22 Open Beluga D Mid 7,471 7,485 4,989 4,9961411/05/22 Open Beluga D 7,553' 7,608' 5,033' 5,063' 55' 4/15/2009 Open Beluga D Lower 7,553 7,5935,033' 5,0554011/05/22 Open Beluga D 7,639' 7,664' 5,080' 5,093' 25' 4/15/2009 Open Beluga E Upper 1 7,639 7,6595,080' 5,0912011/04/22 Open Beluga E Upper 2 7,678 7,6985,101 5,1122011/04/22 Open Beluga E Mid 7,758 7,765 5,145 514875/22/22 Open Beluga E 7,807' 7,827' 5,171' 5,182' 20' 4/15/2009 Open Beluga E Lower 7,807 7,827 5,171' 5,182'205/22/22 Open Beluga F 7,937' 7,945' 5,242' 5,247' 8' 4/15/2009 Open Beluga F Upper 7,937 7,945 5,242' 5,247'85/21/22 Open Beluga F 7,995' 8,005' 5,274' 5,279' 10' 4/15/2009 Open Beluga F Mid 7,995 8,0055,274' 5,279'105/21/22 Open Beluga G 8,068' 8,083' 5,314' 5,322' 15' 10/31/22 H2Zero - WSO Beluga G 8,198' 8,228' 5,386' 5,404' 30' 10/31/22 H2Zero - WSO Beluga G 8,214' 8,246' 5,395' 5,414' 32' 10/31/22 H2Zero - WSO Beluga M 9,023' 9,040' 5,902' 5,913' 17' 4/8/2009 Plugged Beluga Q 9,604' 9,624' 6,270' 6,282' 20' 4/8/2009 Plugged STANDARD WELL PROCEDURE NITROGEN OPERATIONS 09/23/2016 FINAL v-offshore Page 1 of 1 1.) MIRU Nitrogen Pumping Unit and Liquid Nitrogen Transport. 2.) Notify Facility Operator of upcoming Nitrogen operations. 3.) Perform Pre-Job Safety Meeting. Review operating procedures and appropriate Safety Data Sheets (formerly MSDS). 4.) Document hazards and mitigation measures and confirm flow paths. Include review on asphyxiation caused by nitrogen displacing oxygen. Mitigation measures include appropriate routing of flowlines, adequate venting and atmospheric monitoring. 5.) Spot Pumping Unit and Nitrogen Tank. Confirm liquid N2 volumes in transport. 6.) Rig up lines from the Nitrogen Pumping Unit to the well and returns tank. Secure lines with whip checks. 7.) Place signs and placards warning of high pressure and nitrogen operations at areas where Nitrogen may accumulate or be released. 8.) Place pressure gauges downstream of liquid and nitrogen pumps to adequately measure tubing and casing pressures. 9.) Place pressure gauges upstream and downstream of any check valves. 10.) Wellsite Manager shall walk down valve alignments and ensure valve position is correct. 11.) Ensure portable 4-gas detection equipment is onsite, calibrated, and bump tested properly to detect LEL/H2S/CO2/O2 levels. Ensure supplier has a working and calibrated detector as well that measures O2 levels. 12.) Pressure test lines upstream of well to approved sundry pressure or MPSP (Maximum Potential Surface Pressure), whichever is higher. Test lines downstream of well (from well to returns tank) to 1,500 psi. Perform visual inspection for any leaks. 13.) Bleed off test pressure and prepare for pumping nitrogen. 14.) Pump nitrogen at desired rate, monitoring rate (SCFM) and pressure (PSI). All nitrogen returns are to be routed to the returns tank. 15.) When final nitrogen volume has been achieved, isolate well from Nitrogen Pumping Unit and bleed down lines between well and Nitrogen Pumping Unit. 16.) Once you have confirmed lines are bled down, no trapped pressure exists, and no nitrogen has accumulated begin rig down of lines from the Nitrogen Pumping Unit. 17.) Finalize job log and discuss operations with Wellsite Manager. Document any lessons learned and confirm final rates/pressure/volumes of the job and remaining nitrogen in the transport. 18.) RDMO Nitrogen Pumping Unit and Liquid Nitrogen Tank. Kyle Wiseman Hilcorp Alaska, LLC Geo Tech 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 564-4558 E-mail: Kyle.Wiseman@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal. Received By: Date: Date: 01/26/2023 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20230126 Well API #PTD #Log Date Log Company Log Type AOGCC Eset# TBU M-10 50733205880000 209154 12/30/2022 AK E-LINE Perf CLU 10RD 50133205530100 222113 12/29/2022 AK E-LINE GPT_Plug_Perf NCI A-14 50883201250000 208096 11/6/2022 AK E-LINE Perf BRU 214-13 50283201870000 222117 12/19/2022 AK E-LINE PPROF BRU 233-23 50283201360100 222050 12/21/2022 AK E-LINE PPROF SRU 224-10 50133101380100 222124 12/14/2022 AK E-LINE CBL Please include current contact information if different from above. By Meredith Guhl at 2:54 pm, Jan 26, 2023 T37473 T37474 T37475 T37476 T37477 T37478 NCI A-14 50883201250000 208096 11/6/2022 AK E-LINE Perf Meredith Guhl Digitally signed by Meredith Guhl Date: 2023.01.26 15:02:03 -09'00' 1. Operations Susp Well Insp Plug Perforations Fracture Stimulate Pull Tubing Operations shutdown Performed: Install Whipstock Perforate Other Stimulate Alter Casing Change Approved Program Mod Artificial Lift Perforate New Pool Repair Well Coiled Tubing Ops Other: N2 Operations Development Exploratory Stratigraphic Service 6. API Number: 7. Property Designation (Lease Number): 8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071): 10. Field/Pool(s): 11. Present Well Condition Summary: Total Depth measured 11,501 feet 8,035; 9,441 & 9,801 feet true vertical 7,482 feet 8,095 feet Effective Depth measured 8,035 feet See schematic feet true vertical 5,296 feet See schematic feet Perforation depth Measured depth 6,750 - 8,005 feet True Vertical depth 4,591 - 5,279 feet Tubing (size, grade, measured and true vertical depth) 4-1/2" 12.6# / L-80 7,052 (MD) 4,757 (TVD) Packers and SSSV (type, measured and true vertical depth) See schematic 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13a. Prior to well operation: Subsequent to operation: 13b. Pools active after work: 15. Well Class after work: Daily Report of Well Operations Exploratory Development Service Stratigraphic Copies of Logs and Surveys Run 16. Well Status after work: Oil Gas WDSPL Electronic Fracture Stimulation Data GSTOR GINJ SUSP SPLUG Sundry Number or N/A if C.O. Exempt: Authorized Name and Digital Signature with Date: Contact Name: Contact Email: Authorized Title: Contact Phone: 59 322-521 & 322-569 Sr Pet Eng: Sr Pet Geo: Sr Res Eng: WINJ WAG 329 Water-BblOil-Bbl 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Ryan Rupert ryan.rupert@hilcorp.com 907 777-8503Operations Manager N/A Tertiary System Gas Pool measured true vertical Packer Representative Daily Average Production or Injection Data Casing Pressure Tubing Pressure 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 0 Gas-Mcf MD N/A 11 Size 400 135 562380 0 5311 9-5/8" 7" STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 208-096 50-883-20125-00-00 3. Address: Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 N/A 5. Permit to Drill Number:2. Operator Name 4. Well Class Before Work: ADL0017589 / ADL0037831 North Cook Inlet Field / Tertiary System Gas Pool N Cook Inlet Unit A-14 Plugs Junk measured Length measured TVD Production Liner 9,982 Casing Structural 6,5059,982 400 4,747 400Conductor Surface Intermediate 30" 5,410psi 5,750psi 7,240psi 4,747 3,486 Burst Collapse 3,090psi pp kk tt Form 10-404 Revised 10/2022 Due Within 30 days of Operations Submit in PDF format to aogcc.permitting@alaska.gov By Anne Prysunka at 10:20 am, Dec 06, 2022 Digitally signed by Dan Marlowe (1267) DN: cn=Dan Marlowe (1267), ou=Users Date: 2022.12.05 11:13:44 -09'00' Dan Marlowe (1267) ____________________________________________________________________________________ Updated by JLL 12/02/22 North Cook Inlet Well:NCI A-14 Last Completed: 04/23/2009 PTD: 208-096 API: 50-883-20125-00-00 SCHEMATIC PBTD: 9,441 TD: 11,501 7 2 3 4 5 6 7 8 10 Beluga B 9-5/8 30 TOC @ 4,747 USIT 2008 11 12 7a 1 Beluga C BelugaD Beluga E Beluga F Beluga G Beluga M Beluga Q Beluga A TOC @ 6,600 5/18/22 Tbg Punches @ 6993-6996 5/16/22 9 X CASING DETAIL Size Wt Grade Conn ID Top Btm 30 120.00 X-56 27.000 Surf 400 9-5/8 40.00 L-80 BTCM 8.835 Surf 4,747 7 26.00 L-80 BTCM 6.275 Surf 9,982 TUBING DETAIL 4-1/2 12.60 L-80 IBTM 3.958 Surf 7,052 JEWELRY DETAIL No Depth (MD) Depth (TVD)ID Item 23' 23' 3.900 Tubing Hanger - Vetco 1 472' 472' 3.813 SLB BP6i Landing Nipple: WL SSSV (Set 11/19/22) 2 6,926' 4,687' 3.813 X Nipple 3 7,008' 4,732' 3.880 Locator 7,011' 4,734' 4.750 Anchor PBR 7,039' 4,750' 4.000 Gravel Packer (Baker SC-2) 7,040' 4,750' 3.260 Seal Assy (Seal Unit 82-40) 7,047' 4,754' 4.000 Seal Bore Extension 7,051' 4,756' 3.260 WLEG 7,077' 4,771' 3.430 Shear Out Safety Jt 4 7,153' 4,813' 3.430 Excluder Screen 2000 5 7,419' 4,960' 3.430 Excluder Screen 2000 6 7,744' 5,137' 3.430 Excluder Screen 2000 7 7,892' 5,218' 3.430 Excluder Screen 2000 7a 8,035 5,296 -- Quadco TTS 4 Paragon 2 Ret. Packer 8 8,040' 5,298' 3.430 Excluder Screen 2000 9 8,237' 5,409' 3.260 Snap Latch 82-40 S22B 8,238' 5,409' 3.260 Seal Unit (82-40 90H) 8,238' 5,409' 4.000 Packer (Sump Model FS) 8,241' 5,411' 3.260 1/2 Mule Shoe 8,244' 5,413' 3.000 Crossover 5.5"x3.5" 10 8,563' 5,604' 3.010 WLEG 11 9,441' 6,167' 0.000 CIBP 12 9,801' 6,391' 0.000 Sand Plug GAS LIFT MANDRELS STA MD TVD ID Type Port Valve Psc Date 1 1,789' 1,754'Camco KBG-2-1R DUMMY ~2009 2 3,485' 2,798'Camco KBG-2-1R DUMMY ~2009 3 4,949' 3,599'Camco KBG-2-1R 16 DOME 902 11/14/2022 4 6,024' 4,192'Camco KBG-2-1R 20 ORIFICE 11/19/2022 5 6,752'4,592'Camco KBG-2-1R DUMMY Cemented 6 6,839'4,640'Camco KBG-2-1R DUMMY Cemented FISH DETAIL @ ~8,095 5/31/22 EL Fish in Hole: 1' x 1 7/16" GO Cable Head w/ 1" Fish Neck, 5' x 3- 1/8" Gun Gamma, 3' x 2-3/4" Shock Sub, 24' x 2-7/8" Perforating Guns. OAL 33.1' ____________________________________________________________________________________ Updated by JLL 12/02/22 North Cook Inlet Well:NCI A-14 Last Completed: 04/23/2009 PTD: 208-096 API: 50-883-20125-00-00 SCHEMATIC Perforation Data Zone Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT Date Status Beluga A Upper 6,750 6,7634,591 4,598135/23/2022 Open Beluga A Lower 6,839 6,8694,640 4,656305/23/2022 Open Beluga B Upper 1 6,909 6,918 4,678 4,68395/22/2022 Open Beluga B Upper 2 6,938 6,9544,694 4648165/22/2022 Open Beluga B Upper 3 6,969 6,9894,711 4,722205/22/2022 Open Beluga B 7,161' 7,173' 4,817' 4,824' 12' 4/15/2009 Open Beluga B Lower 7,162 7,1724,817' 4,824'1011/06/22 Open Beluga C 7,220' 7,259' 4,850' 4,872' 39' 4/15/2009 Open Beluga C Upper 7,220 7,259 4,850' 4,872'3911/06/22 Open Beluga C 7,276' 7,283' 4,881' 4,885' 7' 4/15/2009 Open Beluga C Mid 7,276 7,2824,881' 4,885'611/05/22 Open Beluga C Lower 7,313 7,3184,902,4904511/05/22 Open Beluga D Mid 7,471 7,485 4,989 4,9961411/05/22 Open Beluga D 7,553' 7,608' 5,033' 5,063' 55' 4/15/2009 Open Beluga D Lower 7,553 7,5935,033' 5,0554011/05/22 Open Beluga D 7,639' 7,664' 5,080' 5,093' 25' 4/15/2009 Open Beluga E Upper 1 7,639 7,6595,080' 5,0912011/04/22 Open Beluga E Upper 2 7,678 7,6985,101 5,1122011/04/22 Open Beluga E Mid 7,758 7,765 5,145 514875/22/22 Open Beluga E 7,807' 7,827' 5,171' 5,182' 20' 4/15/2009 Open Beluga E Lower 7,807 7,827 5,171' 5,182'205/22/22 Open Beluga F 7,937' 7,945' 5,242' 5,247' 8' 4/15/2009 Open Beluga F Upper 7,937 7,945 5,242' 5,247'85/21/22 Open Beluga F 7,995' 8,005' 5,274' 5,279' 10' 4/15/2009 Open Beluga F Mid 7,995 8,0055,274' 5,279'105/21/22 Open Beluga G 8,068' 8,083' 5,314' 5,322' 15' 10/31/22 H2Zero - WSO Beluga G 8,198' 8,228' 5,386' 5,404' 30' 10/31/22 H2Zero - WSO Beluga G 8,214' 8,246' 5,395' 5,414' 32' 10/31/22 H2Zero - WSO Beluga M 9,023' 9,040' 5,902' 5,913' 17' 4/8/2009 Plugged Beluga Q 9,604' 9,624' 6,270' 6,282' 20' 4/8/2009 Plugged Rig Start Date End Date CTU / SL / EL 10/24/22 11/19/22 Hilcorp Alaska, LLC Well Operations Summary API Number Well Permit NumberWell Name NCI A-14 50-883-20125-00-00 208-096 10/29/22 - Saturday Offload Coil Equipment from Titan. Spot Ops Cab, coil reel, injector, power pack, generator, dog house, and fluid pump. RU hardline from pump to choke. Hookup hydraulic lines to power pack. Offload equipment from Sovereign. Spot return tank, N2 pump and tanks, YJ fluid pump, and batch mixer. SDFN 10/30/22 - Sunday SLB coil hold TBT and approve Hot work permit and PTW. RU test pump to BOPs and line up water . Get heater running with snorkel to water lines. Function test BOP rams. Test 1.75" BOPE to 250 psi low / 3000 psi high. AOGCC waived witness by Jim Regg via e-mail on 10/28/22 at 12:42. Stab 1.75" pipe through injector gripper blocks. MU coiled tubing connector and pull test to 40k Run water hose to batch mixer and to fluid pump. Stage KCl on top of batch mixer. Start fluid pump and N2 pump. SDFN. Daily Operations: 10/25/22- Tuesday Heliport & travel to Tyonek Platform. PJSM & permits. Crane unloading AK E-Line, Quadco equipment as well as other items from boat. Rig up AK E-Line and make up Quadco packer and running tool. Pressure test surface equipment w/ water & diesel 250 /1500 PSI. Test good. RIH w/ Quadco-TTS 4" (3.11" OD) x 1.625" ID Paragon 2 retrievable packer on AK E-line. At approximately 6000' was noted CCL not matching up to downhole equipment on depth. Troubleshoot counter issues and found inclement weather (heavy wet snow) had iced up in major counter wheel causing depth to be off. De-iced counter head. Made log pass to recalibrate depth. Counter now working properly. Continue down hole. Tie in to 10' pup joint between 2 gravel pack screens between 8030' and 8040'. Send tie in log to Engineer for approval. Tie in depths approved. Spot tools on depth for mid element of packer to be at 8035'. (16.7' from CCL to mid element - CCL depth 8018.3'). Fire setting tool. Good weight loss indicating set. Sat down lightly on packer and was solid. Pick up weight down from 1200# to 1000#. Pull out of hole. Out of hole. SI and bleed off. Break off and inspect tools. All good condition. Rig down wireline. Still weathered in from snow. Stand by overnight for travel to beach. 10/24/22 - Monday Complete JSA & PTW. Move SL from A-16 to A-14 PT lub to 250L/1500H psi, passed Pull SSSSV at 479ft. RIH with 3.72" GR and tag @ 7,049'KB RIH w/ 3" GR and tag at 8,060' KB POOH & RD Rig Start Date End Date CTU / SL / EL 10/24/22 11/19/22 Hilcorp Alaska, LLC Well Operations Summary API Number Well Permit NumberWell Name NCI A-14 50-883-20125-00-00 208-096 Daily Operations: 10/31/22 - Monday SLB coil hold TBT, approve hot work permit and PTW. Start and warm up equipment. Fuel equipment. Mix 6% KCl fluid in batch mixer. PU lubricator and MU Quadco BHA with stinger. Load coil with 6% KCl and PT lubricator out to choke skid to 250 psi low / 3000 psi high. Open swab and RIH w/ stinger seal assembly. Initial WHP = 1100 psi. BHA: 2.88" CTC, 2.88" DFCV, 2.88" Weight bar, 2.88" Bi-Di Jar, 2.88" Disco (7/8" ball), 3.125" centralizer, 2.70" seal assembly. OAL = 16.15' Wt check at 7900' = 25k. Sting into packer at 8021' ctmd. Overpull to 28k to ensure latched into packer. Injectivity rate with 6% KCl at 0.6 bpm @ 1900 psi. Add 9.6 bbls fresh water to batch mixer. pH = 7.0 Add 136 gallons of HZ30 (gel) and mix. Add 5.5 gallons of HZ20 (x-linker). Take samples Pump total of 7.5 bbls of H2 Zero down coil before losing prime. Pump at 0.6 bpm at ~ 2200 psi. Chase with 29 bbls of 6% KCl at 0.6 bpm. Shut down pump after displacing H2 zero. Pull out of snap latch at 38K. POOH with coil. Laydown seal assembly stinger BHA and MU nozzle. Stab back on well with swab closed. Blowdown coil reel and surface iron with N2. PT lubricator. Bleed off pressure. SDFN. 11/01/22- Tuesday SLB coil hold TBT and approve hot work permit and PTW. Start and warm up equipment. Fuel equipment. Open well and RIH to 7100' ctmd. Wt check = 15k. BHA: 1.75" coil, 2.88" CTC, 2.88" DFCV's, 2.88" wt bar, 2.88" bi-di jar, 2.88" disco, 2.88" nozzle. Start bleeding WHP down from 1550 psi. Handover to production to flow. Well pressure went to 0 psi and well died. Prep for N2. Cool down N2 unit. Start pumping N2 at 1000 scfm. Have coil reciprocate between 7100 - 7950' ctmd. Take returns to diffuser tank at surface. Recover 31 bbls of fluid at tank, POOH while shutting down N2 at 6000'. Coil at surface. Close swab with WHP = 200 psi. Hand well over to production to flow test. Bleed off pressure in lubricator. Laydown lubricator and nozzle BHA Rig down hardline and hoses. Prep coil equipment to be picked and loaded onto boat. Load coil equipment onto Titan. SDFN. Minimal additional flow. will need EL perfs. 11/02/22 - Wednesday SLB coil hold TBT and approve PTW. Drain water from return tank to platform tanks. Prep coil equipment to load onto boat. Load remaining coil equipment from platform to Titan. Rig Start Date End Date CTU / SL / EL 10/24/22 11/19/22 Hilcorp Alaska, LLC Well Operations Summary API Number Well Permit NumberWell Name NCI A-14 50-883-20125-00-00 208-096 Daily Operations: 11/04/22 - Friday AK E-line crew arrive on Tyonek Platform. Sign in and get rooms assigned. Have orientation for new employee. Hold TBT and approve hot work permit, crane operations and PTW. Start and warm equipment. Re-head cable head to 5-2. MU lubricator, wireline valves, and grease head with 20' gun. PT to 250 psi low / 1500 psi high. RIH with Gun #1 (2.5" HC x 20') Send correlation data to RE/GEO and confirm on depth. Perforate 7678-7698' (Beluga E Upper 2 sand) Initial pressure = 950 psi, remain unchanged. Bull plug on gun had small amount of fluid inside. RIH with Gun #2 (2.5" HC x 20') Send correlation data to RE/GEO and confirm on depth. Perforate 7639-7659' (Beluga E Upper 1 sand) Initial pressure = 950 psi, remain unchanged. Bull plug on gun had small amount of fluid inside. Laydown E-line lubricator and secure well with night cap on wireline valves. Handover well to Operations to flow test well. Rig Start Date End Date CTU / SL / EL 10/24/22 11/19/22 Hilcorp Alaska, LLC Well Operations Summary API Number Well Permit NumberWell Name NCI A-14 50-883-20125-00-00 208-096 Daily Operations: 11/05/22 - Saturday AK E-line hold TBT and approve hot work permit, crane operations and PTW. PU lubricator and perforating gun. RIH with Gun #3 (2.5" HC x 20'). GR/CCL to top shot = 8.8'. Send correlation data to RE/GEO. Add 1' to get on depth. Perforate 7573-7593' (Beluga D Lower sand) Initial pressure = 840 psi, pressure remain unchanged for 15 minute reading. Bull plug on gun had small amount of fluid inside. RIH with Gun #4 (2.5" HC x 20'). GR/CCL to top shot = 7.8'. Send correlation data to RE/GEO and confirm on depth. Perforate 7553-7573' (Beluga D Lower sand) Initial pressure = 840 psi, pressure remain unchanged for 15 minute reading. Bull plug on gun had small amount of fluid inside. RIH with Gun #5 (2.5" HC x 14'). GR/CCL to top shot = 8.8'. Send correlation data to RE/GEO and confirm on depth. Perforate 7471-7485' (Beluga D Mid) Initial pressure = 840 psi, pressure remain unchanged for 15 minute reading. Bull plug on gun had small amount of fluid inside. RIH with Gun #6 (2.5" HC x 5'). GR/CCL to top shot = 15.3'. Send correlation data to RE/GEO, add 1' to get on depth. Perforate 7313-7318' (Beluga C Lower) Initial pressure = 840 psi, pressure remain unchanged for 15 minute reading. Bull plug on gun had small amount of fluid inside. RIH with Gun #7 (2.5" HC x 6'). GR/CCL to top shot = 15.8'. Send correlation data to RE/GEO and confirm on depth. Perforate 7276-7282' (Beluga C Mid) Initial pressure = 840 psi, pressure remain unchanged for 15 minute reading. Bull plug on gun had small amount of fluid inside. MU & RIH with GPT toolstring with well shut-in. Tubing pressure = 830 psi. Find fluid level ~ 3950'. Run baseline pass across perf interval from 7950 - 7000'. Bring well online and let stabilize. Tubing pressure = 57 psi. Run up/down pass for pressure/temperature survey across perf interval from 7000-7950'. Log up and find FL ~ 1850' with well flowing. POOH and laydown GPT toolstring and lubricator. Secure well with night cap on wireline valve. SDFN. Rig Start Date End Date CTU / SL / EL 10/24/22 11/19/22 Hilcorp Alaska, LLC Well Operations Summary API Number Well Permit NumberWell Name NCI A-14 50-883-20125-00-00 208-096 Daily Operations: 11/06/22 - Sunday AK E-line hold TBT. Review and approve hot work permit, crane operations and PTW. Start and warm up equipment. Pick up lubricator and perf gun. RIH with Gun #8 (2.5" HC x 19'). GR/CCL to top shot = 8.7'. Send correlation data to RE/GEO and confirm on depth. Perforate 7240-7259' (Beluga C Upper) Well open to header pressure of 60 psi. Bull plug on gun had small amount of fluid inside. RIH with Gun #9 (2.5" HC x 20'). GR/CCL to top shot = 8.8'. Send correlation data to RE/GEO and confirm on depth. Perforate 7220-7240' (Beluga C Upper) Well open to header pressure of 60 psi. Bull plug on gun had small amount of fluid inside. RIH with Gun #10 (2.5" HC x 10'). GR/CCL to top shot = 7.8'. Send correlation data to RE/GEO and add 1' to get on depth. Perforate 7162-7172' (Beluga C Lower) Well open to header pressure of 60 psi. Bull plug on gun had small amount of fluid inside. Laydown lubricator and secure well with tree cap. Handover well to Production. RD E-line equipment. Attempt to flow, no luck. well is dead. Will need SL to install GLV's 11/13/22 - Sunday Arrive @ Tyonek Pre-job meeting- Perform JSA- Gain permit approval Begin R/U Begin PT to 1500#-Test good RIH W/ 3.74 Guage ring to 7040'KB RIH W/4 1/2 AD2 W/ 2.7 Swedge W/4 1/2 GS to 7040'KB- W/T- Set- POOH- Catcher set,RIH W/ OK-1 KOT to 6817'KB W/T- Trouble locating- W/T- Locate- Sit- W/T- Slip off- cannot locate- POOH RIH W/ OK-1 KOT to 6817'KB W/T- Locate- Sit- W/T- Latch- W/T- slip off- repeat multiple times- POOH- No valve Begin R/D- Secure well for the evening Rig Start Date End Date CTU / SL / EL 10/24/22 11/19/22 Hilcorp Alaska, LLC Well Operations Summary API Number Well Permit NumberWell Name NCI A-14 50-883-20125-00-00 208-096 Daily Operations: Morning meeting- Perform JSA- Gain permit approval Begin Standby for production to establish flow. Conclude standby for the day 11/16/2022 - Wednesday Morning meeting- Perform JSA- Gain permit approval Begin Standby RIH W/ 4 1/2 PR W/ 4 1/2 AD-2 Stop t 4000'KB- Receive new procedure- POOH RIH W/ 4 1/2 OK-1 KOT to 6003'WL/6031'KB- W/T- Locate- Cannot sit- W/T- No sit- POOH RIH W/ 4 1/2 Daniels KOT to 6003'WL/6031'KB- W/T- Locate- Sit- latch- W/T- Come free- POOH W/ Orifice Valve Begin Standby Secure Well & Equipment for the evening 11/14/22- Monday Begin Stand up on well RIH W/ 4 1/2 Daniels KOT W/ 1 1/4 JDS to 6003'WL/6031'KB- W/T- Trouble locating- W/T- Locate- Sit- Latch- W/T- come free- No pressure change noted on tubing or casing-POOH W/ Dummy valve- Conference with production RIH W/ 4 1/2 Daniels KOT W/ 1" valve & RT to 6003'WL/6013'KB- W/T- Locate- sit- W/T- Set- W/T- Come free- POOH- Valve set,Standby for flow attempt-Cannot establish flow RIH W/ 4 1/2 OK KOT W/ 1 1/4 JDS to 4927'KB- W/T- Locate- Sit- Latch- W/T- Come free- POOH W/ Dummy valve RIH W/ 4 1/2 Daniels W/ GLV W/ RT to 4927'WL/ 4955'KB- W/T- Locate- Sit- W/T- Come free- POOH- Valve still on running tool- scratch marks indicate partial set,RIH W/ Same to 4927'WL/4955'KB- W/T-Locat- Sit- W/T- Set- W/T- Come free- POOH RIH W/ 4 1/2 GS to 7012'WL/7040'KB - W/T- Latch- W/T come free- Gain overpull- POOH- No Catcher RIH W/ Same to 7020'KB- W/T- Latch- gain overpull- POOH Slowly- slip off and re-latch multiple times- continue OOH W/ Catcher sub Secure well & Equipment for the evening. 11/15/2022 - Tuesday Rig Start Date End Date CTU / SL / EL 10/24/22 11/19/22 Hilcorp Alaska, LLC Well Operations Summary API Number Well Permit NumberWell Name NCI A-14 50-883-20125-00-00 208-096 Daily Operations: Arrive @ PWL, gather tools, depart for OSK. Depart OSK for Tyonek Platform Arrive on tyonek Platform, talk w/ company rep, sign permits. TGSM. Rig up on well. PT 1500 PSI- pass. Rih w/ 4 1/2 PR-GS w/ 4 1/2 AD-2 stop to 6123' wl, set stop, pooh. Ooh no stop. Rih w/ 4 1/2 Daniels KOT w/ 1 1/4 JDS to 6031' wl, latch oriface, see change in tubing pressure. Pooh, ooh w/ oriface. Rih w/ 4 1/2 Daniels KOT w/ pocket brush to 6031' wl, w/t pooh, ooh w/ marks indicating brush was able to drop out bottom of mandrel pocket. Rih w/ 4 1/2 Daniels KOT w/ 5/8 Oriface (1" bk) to 6031' wl, set oriface, pooh, ooh no oriface Rih w/ 4 1/2 PR-GS to 6123' kb, latch AD-2 stop, pooh. Ooh w/ tools, flow well. Well is flowing off of oriface. Rih w/ 4 1/2 PRS to 479' kb, set SSSV, shear off pooh. Closure test SSV. Good. Depart Tyonek. 6 days of flow since well was returned to service on 11/14/22. 11/17/2022 - Thursday Morning meeting- Perform JSA- Gain permit approval Prep catcher Sub RIH W/ 4 1/2 AD-2 W/ 4 1/2 PR to 6182'KB- W/T RIH W/ 4 1/2 Daniels to 6031'KB- W/T- Locate- Sit- W/T- Come free- POOH- Valve set,RIH W/ 4 1/2 PR to 6182''KB- Tag- W/T- Latch- W/T- Come free- POOH W/ AD-2 Catcher sub. Prep SSSV- Standby for flow test Conference with production- still not lifting from orifice. Will RD and make a plan Standby for chopper Depart for shop 11/19/2022 - Saturday 1 Regg, James B (OGC) From:Brad Gathman - (C) <Brad.Gathman@hilcorp.com> Sent:Tuesday, November 1, 2022 6:59 AM To:Regg, James B (OGC); DOA AOGCC Prudhoe Bay; Brooks, Phoebe L (OGC) Cc:Donna Ambruz; Juanita Lovett Subject:BOPE Test Form SLB 1 CTU 10-30-22.xlsx Attachments:BOPE Test Form SLB 1 CTU 10-30-22.xlsx; [EXTERNAL] AOGCC Inspection Form Confirmation Email; [EXTERNAL] RE: AOGCC Test Witness Notification Request: BOPE, SLB Coiled Tubing Unit 1, Tyonek NCIU A-14 The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please immediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. North Cook Inlet A-14 PTD 2080960 STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION *All BOPE reports are due to the agency within 5 days of testing* Submit to:jim.regg@alaska.gov; AOGCC.Inspectors@alaska.gov; phoebe.brooks@alaska.gov Rig Owner:Rig No.:1 DATE:10/30/22 Rig Rep.:Rig Email: Operator: Operator Rep.:Op. Rep Email: Well Name:PTD #2080960 Sundry #322-569 Operation:Drilling:Workover:x Explor.: Test:Initial:x Weekly:Bi-Weekly:Other: Rams:250/3000 Annular:N/A Valves:250/3000 MASP:408 MISC. INSPECTIONS:TEST DATA FLOOR SAFETY VALVES: Test Result/Type Test Result Quantity Test Result Housekeeping P Well Sign P Upper Kelly 0 NA Permit On Location P Hazard Sec.NA Lower Kelly 0 NA Standing Order Posted P Misc.NA Ball Type 0 NA Test Fluid Water Inside BOP 0 NA FSV Misc 0 NA BOP STACK:Quantity Size/Type Test Result MUD SYSTEM:Visual Alarm Stripper 1 1.75"P Trip Tank NA NA Annular Preventer 0 NA NA Pit Level Indicators NA NA #1 Rams 1 blind/shear P Flow Indicator NA NA #2 Rams 1 pipe/slip P Meth Gas Detector NA NA #3 Rams 0 NA NA H2S Gas Detector NA NA #4 Rams 0 NA NA MS Misc 0 NA #5 Rams 0 NA NA #6 Rams 0 NA NA ACCUMULATOR SYSTEM: Choke Ln. Valves 2 2"P Time/Pressure Test Result HCR Valves 0 NA NA System Pressure (psi)2950 P Kill Line Valves 2 2"P Pressure After Closure (psi)2100 P Check Valve 1 2" 1502 P 200 psi Attained (sec)13 P BOP Misc 1 EQ Ports P Full Pressure Attained (sec)45 P Blind Switch Covers:All stations YES CHOKE MANIFOLD:Bottle Precharge:P Quantity Test Result Nitgn. Bottles # & psi (Avg.):NA NA No. Valves 5 P ACC Misc 0 NA Manual Chokes 2 P Hydraulic Chokes 0 NA Control System Response Time:Time (sec)Test Result CH Misc 0 NA Annular Preventer 0 NA #1 Rams 13 P Coiled Tubing Only:#2 Rams 8 P Inside Reel valves 1 P #3 Rams 0 NA #4 Rams 0 NA Test Results #5 Rams 0 NA #6 Rams 0 NA Number of Failures:0 Test Time:2.5 HCR Choke 0 NA Repair or replacement of equipment will be made within NA days. HCR Kill 0 NA Remarks: AOGCC Inspection 24 hr Notice YES Date/Time 10/27/22 12:09 Waived By Test Start Date/Time:10/30/2022 8:30 (date)(time)Witness Test Finish Date/Time:10/30/2022 11:00 BOPE Test Report Notify the AOGCC of repairs with written confirmation to: AOGCC.Inspectors@alaska.gov Jim Regg Schlumberger Albert Tietje Hilcorp Alaska Brad Gathman NCIU A-14 Test Pressure (psi): atietje@slb.com brad.gathman@hilcorp.com Form 10-424 (Revised 08/2022)2022-1030_BOP_SLB1_NCIU_A-14        jbr J. Regg; 11/28/2022 From:Regg, James B (OGC) To:AOGCC Records (CED sponsored) Subject:BOP SLB1 Service Coil Date:Monday, November 28, 2022 1:12:50 PM Attachments:2022-1030_BOP_SLB1_NCIU_A-14.pdf North Cook Inlet Unit A-14 (PTD 2080960) Jim Regg Supervisor, Inspections AOGCC 333 W. 7th Ave, Suite 100 Anchorage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aSVL 3 W V )RUP5HYLVHG$SSURYHGDSSOLFDWLRQLVYDOLGIRUPRQWKVIURPWKHGDWHRIDSSURYDO By Samantha Carlisle at 11:58 am, Sep 23, 2022 'LJLWDOO\VLJQHGE\'DQ0DUORZH '1FQ 'DQ0DUORZH RX 8VHUV 'DWH 'DQ0DUORZH '65 ; %23 WHVW WR SVL 7HUWLDU\6\VWHP*DV3RRO6)' %-0 6)'*&: Jessie L. 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Chmielowski Date: 2022.09.27 12:00:01 -08'00' RBDMS JSB 100322 tĞůůtŽƌŬWƌŽŐŶŽƐŝƐZĞǀϭ tĞůů͗E/hͲϭϰ ĂƚĞ͗ϵͬϮϯͬϮϬϮϮ tĞůůEĂŵĞ͗E/hͲϭϰ W/EƵŵďĞƌ͗ϱϬͲϴϴϯͲϮϬϭϮϱͲϬϬͲϬϬ ƵƌƌĞŶƚ^ƚĂƚƵƐ͗'ĂƐWƌŽĚƵĐĞƌ>ĞŐ͗>ĞŐηϮ ƐƚŝŵĂƚĞĚ^ƚĂƌƚĂƚĞ͗ϭϬͬϰͬϮϮZŝŐ͗Coil Tubing & E-line ZĞŐƵůĂƚŽƌǇŽŶƚĂĐƚ͗ŽŶŶĂŵďƌƵǌ;ϴϯϬϱͿWĞƌŵŝƚƚŽƌŝůůEƵŵďĞƌ͗ϮϬϴͲϬϵϲ &ŝƌƐƚĂůůŶŐŝŶĞĞƌ͗ŚĂĚ,ĞůŐĞƐŽŶ;ϵϬϳͿϳϳϳͲϴϰϬϱ;KͿ;ϵϬϳͿϮϮϵͲϰϴϮϰ;DͿ ^ĞĐŽŶĚĂůůŶŐŝŶĞĞƌ͗<ĂƚŚĞƌŝŶĞK͛ŽŶŶŽƌ;ϵϬϳͿϳϳϳͲϴϯϳϲ;KͿ;ϮϭϰͿϲϴϰͲϳϰϬϬ;DͿ Revisions to procedure in RED font Current Bottom Hole Pressure: 590 psi @ 4,821’ TVD Based on original SITP of A-04A on 11/2021 Maximum Expected BHP: 868 psi @ 4,595’ TVD Based on original SITP of A-01A on 11/2021 Maximum Potential Surface Pressure: ~408 psi @ 4,595’ TVD Using 0.1 psi/ft gradient 20 AAC 25.280(b)(4) ƌŝĞĨtĞůů^ƵŵŵĂƌǇ dŚĞE/hͲϭϰǁĞůůǁĂƐĚƌŝůůĞĚŝŶϮϬϬϴĂŶĚĐŽŵƉůĞƚĞĚŝŶϮϬϬϵǁŝƚŚĂŐƌĂǀĞůƉĂĐŬŝŶƚŚĞĞůƵŐĂƐĂŶĚƐ͘/Ŷ ϮϬϭϮĂƚŚƌƵƚƵďŝŶŐĞĞƉ'ĂƐ>ŝĨƚƐƚƌŝŶŐǁĂƐŝŶƐƚĂůůĞĚ͘/ƚǁĂƐƉƵůůĞĚĂŶĚƌĞŝŶƐƚĂůůĞĚŝŶϮϬϭϱ͘dŚĞǁĞůů͛Ɛ 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ď͘ZĞĐŽƌĚŝŶŝƚŝĂůĂŶĚϱͬϭϬͬϭϱŵŝŶƵƚĞƚƵďŝŶŐƉƌĞƐƐƵƌĞƐĂĨƚĞƌĨŝƌŝŶŐ Đ͘ŽŶƐƵůƚǁŝƚŚZͬ'ĞŽ;ŚƌŝƐ<ĂŶǇĞƌͬĂŶŝĞůzĂŶĐǇͿďĞƚǁĞĞŶĞĂĐŚƉĞƌĨŝŶƚĞƌǀĂů Ě͘ďŽǀĞƉĞƌĨƐǁŝůůďĞƐŚŽƚŝŶƚŚĞEŽƌƚŚŽŽŬ/ŶůĞƚ͕dĞƌƚŝĂƌǇ'ĂƐWŽŽů͘ Ϯϯ͘ZͲ>ŝŶĞhŶŝƚĂŶĚƚƵƌŶǁĞůůŽǀĞƌƚŽƉƌŽĚƵĐƚŝŽŶ Ϯϰ͘^ůŝĐŬůŝŶĞƚŽƌĞƐĞƚtZ^sĂƐƉĞƌϮϬϮϱ͘Ϯϲϱ ĂͿEŽƚŝĨǇK'ϰϴŚƌƐŝŶĂĚǀĂŶĐĞŽĨƚĞƐƚŝŶŐtZ^s ƚƚĂĐŚŵĞŶƚƐ͗ ϭ͘tĞůů^ĐŚĞŵĂƚŝĐƵƌƌĞŶƚ Ϯ͘tĞůů^ĐŚĞŵĂƚŝĐWƌŽƉŽƐĞĚ;ƌĞǀŝƐĞĚͿ ϯ͘dKW^ĐŚĞŵĂƚŝĐ $JUHH6)' ďŽǀĞƉĞƌĨƐǁŝůůďĞƐŚŽƚŝŶƚŚĞEŽƌƚŚŽŽŬ/ŶůĞƚ͕dĞƌƚŝĂƌǇ'ĂƐ WŽŽů͘ 7HUWLDU\6\VWHP*DV3RRO BBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBB hƉĚĂƚĞĚďǇ,ϬϵͲϭϰͲϮϮ ^,Dd/ EŽƌƚŚŽŽŬ/ŶůĞƚ tĞůů͗E/Ͳϭϰ >ĂƐƚŽŵƉůĞƚĞĚ͗ϬϰͬϮϯͬϮϬϬϵ Wd͗ϮϬϴͲϬϵϲ W/͗ϱϬͲϴϴϯͲϮϬϭϮϱͲϬϬͲϬϬ ^/E'd/> ^ŝǌĞtƚ'ƌĂĚĞŽŶŶ/dŽƉƚŵ ϯϬ͟ϭϮϬ͘ϬϬyͲϱϲϮϳ͘ϬϬϬ^ƵƌĨϰϬϬ͛ ϵͲϱͬϴ͟ϰϬ͘ϬϬ>ͲϴϬdDϴ͘ϴϯϱ^ƵƌĨϰ͕ϳϰϳ͛ ϳ͟Ϯϲ͘ϬϬ>ͲϴϬdDϲ͘Ϯϳϱ^ƵƌĨϵ͕ϵϴϮ͛ dh/E'd/> ϰͲϭͬϮ͟ϭϮ͘ϲϬ>ͲϴϬ/dDϯ͘ϵϱϴ^ƵƌĨϳ͕ϬϱϮ͛ :t>Zzd/> EŽĞƉƚŚ ;DͿ ĞƉƚŚ ;dsͿ/ K /ƚĞŵ ϮϯΖϮϯΖϯ͘ϵϬϬdƵďŝŶŐ,ĂŶŐĞƌͲsĞƚĐŽ ϭϰϳϮΖϰϳϮΖϯ͘ϴϭϯ^>Wϲŝ>ĂŶĚŝŶŐEŝƉƉůĞ ϭĂϰϳϵ͛ϰϳϵ͛^^^sϬϱͬϯϭͬϮϮ Ϯ ϭ͕ϳϴϵΖϭ͕ϳϱϰΖϭ͘ϬϬϬĂŵĐŽ<'ͲϮͲϭZ'>s;ƵŵŵǇͿ ϯ͕ϰϴϱΖϮ͕ϳϵϴΖϭ͘ϬϬϬĂŵĐŽ<'ͲϮͲϭZ'>s;ƵŵŵǇͿ ϰ͕ϵϰϵΖϯ͕ϱϵϵΖϭ͘ϬϬϬĂŵĐŽ<'ͲϮͲϭZ'>s;ƵŵŵǇͿ ϲ͕ϬϮϰΖϰ͕ϭϵϮΖϭ͘ϬϬϬĂŵĐŽ<'ͲϮͲϭZ'>s;ƵŵŵǇͿ ϲ͕ϳϱϮΖϰ͕ϱϵϮΖϭ͘ϬϬϬĂŵĐŽ<'ͲϮͲϭZ'>s;ƵŵŵǇͿ ϲ͕ϴϯϵΖϰ͕ϲϰϬΖϮ͘ϯϳϱϭ͘ϬϬϬĂŵĐŽ<'ͲϮͲϭZ'>s;ƵŵŵǇͿ ϯϲ͕ϵϮϲΖϰ͕ϲϴϳΖϯ͘ϴϭϯyEŝƉƉůĞ ϰ ϳ͕ϬϬϴΖϰ͕ϳϯϮΖϯ͘ϴϴϬ>ŽĐĂƚŽƌ ϳ͕ϬϭϭΖϰ͕ϳϯϰΖϰ͘ϳϱϬŶĐŚŽƌWZ ϳ͕ϬϯϵΖϰ͕ϳϱϬΖϰ͘ϬϬϬϯ͘ϰϯϬ'ƌĂǀĞůWĂĐŬĞƌ;ĂŬĞƌ^ͲϮͿ ϳ͕ϬϰϬΖϰ͕ϳϱϬΖϯ͘ϮϲϬ^ĞĂůƐƐǇ;^ĞĂůhŶŝƚϴϮͲϰϬͿ ϳ͕ϬϰϳΖϰ͕ϳϱϰΖϰ͘ϬϬϬ^ĞĂůŽƌĞǆƚĞŶƐŝŽŶ ϳ͕ϬϱϭΖϰ͕ϳϱϲΖϯ͘ϮϲϬt>' ϳ͕ϬϳϳΖϰ͕ϳϳϭΖϯ͘ϰϯϬ^ŚĞĂƌKƵƚ^ĂĨĞƚǇ:ƚ ϳϳ͕ϭϱϯΖϰ͕ϴϭϯΖϯ͘ϰϯϬǆĐůƵĚĞƌ^ĐƌĞĞŶϮϬϬϬ ϴϳ͕ϰϭϵΖϰ͕ϵϲϬΖϯ͘ϰϯϬǆĐůƵĚĞƌ^ĐƌĞĞŶϮϬϬϬ ϵϳ͕ϳϰϰΖϱ͕ϭϯϳΖϯ͘ϰϯϬǆĐůƵĚĞƌ^ĐƌĞĞŶϮϬϬϬ ϭϬϳ͕ϴϵϮΖϱ͕ϮϭϴΖϯ͘ϰϯϬǆĐůƵĚĞƌ^ĐƌĞĞŶϮϬϬϬ ϭϭϴ͕ϬϰϬΖϱ͕ϮϵϴΖϯ͘ϰϯϬǆĐůƵĚĞƌ^ĐƌĞĞŶϮϬϬϬ ϭϮ ϴ͕ϮϯϳΖϱ͕ϰϬϵΖϯ͘ϮϲϬ^ŶĂƉ>ĂƚĐŚϴϮͲϰϬ^ϮϮ ϴ͕ϮϯϴΖϱ͕ϰϬϵΖϯ͘ϮϲϬ^ĞĂůhŶŝƚ;ϴϮͲϰϬϵϬ,Ϳ ϴ͕ϮϯϴΖϱ͕ϰϬϵΖϰ͘ϬϬϬϮ͘ϵϵϮWĂĐŬĞƌ;^ƵŵƉDŽĚĞů&^Ϳ ϴ͕ϮϰϭΖϱ͕ϰϭϭΖϯ͘ϮϲϬϭͬϮDƵůĞ^ŚŽĞ ϴ͕ϮϰϰΖϱ͕ϰϭϯΖϯ͘ϬϬϬƌŽƐƐŽǀĞƌϱ͘ϱΗǆϯ͘ϱΗ ϭϯϴ͕ϱϲϯΖϱ͕ϲϬϰΖϯ͘ϬϭϬt>' ϭϰϴ͕ϵϰϰ͛ϲ͕ϭϲϳΖϬ͘ϬϬϬ/W ϭϱϵ͕ϴϬϭΖϲ͕ϯϵϭΖϬ͘ϬϬϬ^ĂŶĚWůƵŐ &/^,d/>ΛΕϴ͕Ϭϵϱ͛ϱͬϯϭͬϮϮ &ŝƐŚŝŶ,ŽůĞ͗ϭΖǆϭϳͬϭϲΗ'KĂďůĞ,ĞĂĚǁͬϭΗ&ŝƐŚEĞĐŬ͕ϱΖǆϯͲϭͬϴΗ 'ƵŶ'ĂŵŵĂ͕ϯΖǆϮͲϯͬϰΗ^ŚŽĐŬ^Ƶď͕ϮϰΖǆϮͲϳͬϴΗWĞƌĨŽƌĂƚŝŶŐ'ƵŶƐ͘ K>ϯϯ͘ϭΖ BBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBB hƉĚĂƚĞĚďǇDϬϲͲϭϯͲϮϮ EŽƌƚŚŽŽŬ/ŶůĞƚ tĞůů͗E/Ͳϭϰ >ĂƐƚŽŵƉůĞƚĞĚ͗ϬϰͬϮϯͬϮϬϬϵ Wd͗ϮϬϴͲϬϵϲ W/͗ϱϬͲϴϴϯͲϮϬϭϮϱͲϬϬͲϬϬ ^,Dd/ WĞƌĨŽƌĂƚŝŽŶĂƚĂ ŽŶĞdŽƉ;DͿƚŵ;DͿdŽƉ;dsͿƚŵ;dsͿ&dĂƚĞ^ƚĂƚƵƐ ĞůƵŐĂhƉƉĞƌϲ͕ϳϱϬ͛ϲ͕ϳϲϯ͛ϰ͕ϱϵϭ͛ϰ͕ϱϵϴ͛ϭϯ͛ϱͬϮϯͬϮϬϮϮKƉĞŶ ĞůƵŐĂ>ŽǁĞƌϲ͕ϴϯϵ͛ϲ͕ϴϲϵ͛ϰ͕ϲϰϬ͛ϰ͕ϲϱϲ͛ϯϬ͛ϱͬϮϯͬϮϬϮϮKƉĞŶ ĞůƵŐĂhƉƉĞƌϭϲ͕ϵϬϵ͛ϲ͕ϵϭϴ͛ϰ͕ϲϳϴ͛ϰ͕ϲϴϯ͛ϵ͛ϱͬϮϮͬϮϬϮϮKƉĞŶ ĞůƵŐĂhƉƉĞƌϮϲ͕ϵϯϴ͛ϲ͕ϵϱϰ͛ϰ͕ϲϵϰ͛ϰϲϰϴ͛ϭϲ͛ϱͬϮϮͬϮϬϮϮKƉĞŶ ĞůƵŐĂhƉƉĞƌϯϲ͕ϵϲϵ͛ϲ͕ϵϴϵ͛ϰ͕ϳϭϭ͛ϰ͕ϳϮϮ͛ϮϬ͛ϱͬϮϮͬϮϬϮϮKƉĞŶ ĞůƵŐĂϳ͕ϭϲϭΖϳ͕ϭϳϯΖϰ͕ϴϭϳΖϰ͕ϴϮϰΖϭϮΖϰͬϭϱͬϮϬϬϵKƉĞŶ ĞůƵŐĂϳ͕ϮϮϬΖϳ͕ϮϱϵΖϰ͕ϴϱϬΖϰ͕ϴϳϮΖϯϵΖϰͬϭϱͬϮϬϬϵKƉĞŶ ĞůƵŐĂϳ͕ϮϳϲΖϳ͕ϮϴϯΖϰ͕ϴϴϭΖϰ͕ϴϴϱΖϳΖϰͬϭϱͬϮϬϬϵKƉĞŶ ĞůƵŐĂϳ͕ϱϱϯΖϳ͕ϲϬϴΖϱ͕ϬϯϯΖϱ͕ϬϲϯΖϱϱΖϰͬϭϱͬϮϬϬϵKƉĞŶ ĞůƵŐĂϳ͕ϲϯϵΖϳ͕ϲϲϰΖϱ͕ϬϴϬΖϱ͕ϬϵϯΖϮϱΖϰͬϭϱͬϮϬϬϵKƉĞŶ ĞůƵŐĂDŝĚϳ͕ϳϱϴ͛ϳ͕ϳϲϱ͛ϱ͕ϭϰϱ͛ϱϭϰϴ͛ϳ͛ϱͬϮϮͬϮϮKƉĞŶ ĞůƵŐĂϳ͕ϴϬϳΖϳ͕ϴϮϳΖϱ͕ϭϳϭΖϱ͕ϭϴϮΖϮϬΖϰͬϭϱͬϮϬϬϵKƉĞŶ ĞůƵŐĂ>ŽǁĞƌϳ͕ϴϬϳ͛ϳ͕ϴϮϳ͛ϱ͕ϭϳϭΖϱ͕ϭϴϮΖϮϬ͛ϱͬϮϮͬϮϮKƉĞŶ ĞůƵŐĂ&ϳ͕ϵϯϳΖϳ͕ϵϰϱΖϱ͕ϮϰϮΖϱ͕ϮϰϳΖϴΖϰͬϭϱͬϮϬϬϵKƉĞŶ ĞůƵŐĂ&hƉƉĞƌϳ͕ϵϯϳ͛ϳ͕ϵϰϱ͛ϱ͕ϮϰϮΖϱ͕ϮϰϳΖϴ͛ϱͬϮϭͬϮϮKƉĞŶ ĞůƵŐĂ&ϳ͕ϵϵϱΖϴ͕ϬϬϱΖϱ͕ϮϳϰΖϱ͕ϮϳϵΖϭϬΖϰͬϭϱͬϮϬϬϵKƉĞŶ ĞůƵŐĂ&DŝĚϳ͕ϵϵϱ͛ϴ͕ϬϬϱ͛ϱ͕ϮϳϰΖϱ͕ϮϳϵΖϭϬ͛ϱͬϮϭͬϮϮKƉĞŶ ĞůƵŐĂ'ϴ͕ϬϲϴΖϴ͕ϬϴϯΖϱ͕ϯϭϰΖϱ͕ϯϮϮΖϭϱΖϰͬϭϱͬϮϬϬϵKƉĞŶ ĞůƵŐĂ'ϴ͕ϭϵϴΖϴ͕ϮϮϴΖϱ͕ϯϴϲΖϱ͕ϰϬϰΖϯϬΖϰͬϭϱͬϮϬϬϵKƉĞŶ ĞůƵŐĂ'ϴ͕ϮϭϰΖϴ͕ϮϰϲΖϱ͕ϯϵϱΖϱ͕ϰϭϰΖϯϮΖϰͬϵͬϮϬϬϵKƉĞŶ ĞůƵŐĂDϵ͕ϬϮϯΖϵ͕ϬϰϬΖϱ͕ϵϬϮΖϱ͕ϵϭϯΖϭϳΖϰͬϴͬϮϬϬϵKƉĞŶ ĞůƵŐĂYϵ͕ϲϬϰΖϵ͕ϲϮϰΖϲ͕ϮϳϬΖϲ͕ϮϴϮΖϮϬΖϰͬϴͬϮϬϬϵKƉĞŶ BBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBB hƉĚĂƚĞĚďǇ,ϬϵͲϮϯͲϮϮ WZKWK^ZĞǀϭ EŽƌƚŚŽŽŬ/ŶůĞƚ tĞůů͗E/Ͳϭϰ >ĂƐƚŽŵƉůĞƚĞĚ͗ϬϰͬϮϯͬϮϬϬϵ Wd͗ϮϬϴͲϬϵϲ W/͗ϱϬͲϴϴϯͲϮϬϭϮϱͲϬϬͲϬϬ ^/E'd/> ^ŝǌĞtƚ'ƌĂĚĞŽŶŶ/dŽƉƚŵ ϯϬ͟ϭϮϬ͘ϬϬyͲϱϲϮϳ͘ϬϬϬ^ƵƌĨϰϬϬ͛ ϵͲϱͬϴ͟ϰϬ͘ϬϬ>ͲϴϬdDϴ͘ϴϯϱ^ƵƌĨϰ͕ϳϰϳ͛ ϳ͟Ϯϲ͘ϬϬ>ͲϴϬdDϲ͘Ϯϳϱ^ƵƌĨϵ͕ϵϴϮ͛ dh/E'd/> ϰͲϭͬϮ͟ϭϮ͘ϲϬ>ͲϴϬ/dDϯ͘ϵϱϴ^ƵƌĨϳ͕ϬϱϮ͛ :t>Zzd/> EŽĞƉƚŚ ;DͿ ĞƉƚŚ ;dsͿ/ K /ƚĞŵ ϮϯΖϮϯΖϯ͘ϵϬϬdƵďŝŶŐ,ĂŶŐĞƌͲsĞƚĐŽ ϭϰϳϮΖϰϳϮΖϯ͘ϴϭϯ^>Wϲŝ>ĂŶĚŝŶŐEŝƉƉůĞ ϭĂϰϳϵ͛ϰϳϵ͛^^^sϬϱͬϯϭͬϮϮ Ϯ ϭ͕ϳϴϵΖϭ͕ϳϱϰΖϭ͘ϬϬϬĂŵĐŽ<'ͲϮͲϭZ'>s;ƵŵŵǇͿ ϯ͕ϰϴϱΖϮ͕ϳϵϴΖϭ͘ϬϬϬĂŵĐŽ<'ͲϮͲϭZ'>s;ƵŵŵǇͿ ϰ͕ϵϰϵΖϯ͕ϱϵϵΖϭ͘ϬϬϬĂŵĐŽ<'ͲϮͲϭZ'>s;ƵŵŵǇͿ 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BBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBB hƉĚĂƚĞĚďǇ,ϬϵͲϮϯͲϮϮ EŽƌƚŚŽŽŬ/ŶůĞƚ tĞůů͗E/Ͳϭϰ >ĂƐƚŽŵƉůĞƚĞĚ͗ϬϰͬϮϯͬϮϬϬϵ Wd͗ϮϬϴͲϬϵϲ W/͗ϱϬͲϴϴϯͲϮϬϭϮϱͲϬϬͲϬϬ WZKWK^ WĞƌĨŽƌĂƚŝŽŶĂƚĂ ŽŶĞdŽƉ;DͿƚŵ;DͿdŽƉ;dsͿƚŵ;dsͿ&dĂƚĞ^ƚĂƚƵƐ ĞůƵŐĂhƉƉĞƌϲ͕ϳϱϬ͛ϲ͕ϳϲϯ͛ϰ͕ϱϵϭ͛ϰ͕ϱϵϴ͛ϭϯ͛ϱͬϮϯͬϮϬϮϮKƉĞŶ ĞůƵŐĂ>ŽǁĞƌϲ͕ϴϯϵ͛ϲ͕ϴϲϵ͛ϰ͕ϲϰϬ͛ϰ͕ϲϱϲ͛ϯϬ͛ϱͬϮϯͬϮϬϮϮKƉĞŶ ĞůƵŐĂhƉƉĞƌϭϲ͕ϵϬϵ͛ϲ͕ϵϭϴ͛ϰ͕ϲϳϴ͛ϰ͕ϲϴϯ͛ϵ͛ϱͬϮϮͬϮϬϮϮKƉĞŶ ĞůƵŐĂhƉƉĞƌϮϲ͕ϵϯϴ͛ϲ͕ϵϱϰ͛ϰ͕ϲϵϰ͛ϰϲϰϴ͛ϭϲ͛ϱͬϮϮͬϮϬϮϮKƉĞŶ ĞůƵŐĂhƉƉĞƌϯϲ͕ϵϲϵ͛ϲ͕ϵϴϵ͛ϰ͕ϳϭϭ͛ϰ͕ϳϮϮ͛ϮϬ͛ϱͬϮϮͬϮϬϮϮKƉĞŶ ĞůƵŐĂϳ͕ϭϲϭΖϳ͕ϭϳϯΖϰ͕ϴϭϳΖϰ͕ϴϮϰΖϭϮΖϰͬϭϱͬϮϬϬϵKƉĞŶ ĞůƵŐĂ>ŽǁĞƌцϳ͕ϭϲϭ͛цϳ͕ϭϳϯ͛цϰ͕ϴϭϳΖцϰ͕ϴϮϰΖϭϮ͛WƌŽƉŽƐĞĚd ĞůƵŐĂϳ͕ϮϮϬΖϳ͕ϮϱϵΖϰ͕ϴϱϬΖϰ͕ϴϳϮΖϯϵΖϰͬϭϱͬϮϬϬϵKƉĞŶ ĞůƵŐĂhƉƉĞƌцϳ͕ϮϮϬ͛цϳ͕Ϯϱϵ͛цϰ͕ϴϱϬΖцϰ͕ϴϳϮΖϯϵ͛WƌŽƉŽƐĞĚd ĞůƵŐĂϳ͕ϮϳϲΖϳ͕ϮϴϯΖϰ͕ϴϴϭΖϰ͕ϴϴϱΖϳΖϰͬϭϱͬϮϬϬϵKƉĞŶ ĞůƵŐĂDŝĚцϳ͕Ϯϳϲ͛цϳ͕Ϯϴϯ͛цϰ͕ϴϴϭΖцϰ͕ϴϴϱΖϳ͛WƌŽƉŽƐĞĚd ĞůƵŐĂ>ŽǁĞƌцϳ͕ϯϭϯ͛цϳ͕ϯϭϴ͛цϰ͕ϵϬϮ͛ц͕ϰϵϬϰ͛ϱ͛WƌŽƉŽƐĞĚd ĞůƵŐĂDŝĚцϳ͕ϰϳϭ͛цϳ͕ϰϴϱ͛цϰ͕ϵϴϵ͛цϰ͕ϵϵϲ͛ϭϰ͛WƌŽƉŽƐĞĚd ĞůƵŐĂϳ͕ϱϱϯΖϳ͕ϲϬϴΖϱ͕ϬϯϯΖϱ͕ϬϲϯΖϱϱΖϰͬϭϱͬϮϬϬϵKƉĞŶ ĞůƵŐĂ>ŽǁĞƌцϳ͕ϱϱϯ͛цϳ͕ϱϵϯ͛цϱ͕ϬϯϯΖцϱ͕Ϭϱϱ͛ϰϬ͛WƌŽƉŽƐĞĚd 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ĂͿEŽƚŝĨǇK'ϰϴŚƌƐŝŶĂĚǀĂŶĐĞŽĨƚĞƐƚŝŶŐtZ^s ƚƚĂĐŚŵĞŶƚƐ͗ ϭ͘tĞůů^ĐŚĞŵĂƚŝĐƵƌƌĞŶƚ Ϯ͘tĞůů^ĐŚĞŵĂƚŝĐWƌŽƉŽƐĞĚ BBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBB hƉĚĂƚĞĚďǇDϬϲͲϭϯͲϮϮ ^,Dd/ EŽƌƚŚŽŽŬ/ŶůĞƚ tĞůů͗E/Ͳϭϰ >ĂƐƚŽŵƉůĞƚĞĚ͗ϬϰͬϮϯͬϮϬϬϵ Wd͗ϮϬϴͲϬϵϲ W/͗ϱϬͲϴϴϯͲϮϬϭϮϱͲϬϬͲϬϬ ^/E'd/> ^ŝǌĞtƚ'ƌĂĚĞŽŶŶ/dŽƉƚŵ ϯϬ͟ϭϮϬ͘ϬϬyͲϱϲϮϳ͘ϬϬϬ^ƵƌĨϰϬϬ͛ ϵͲϱͬϴ͟ϰϬ͘ϬϬ>ͲϴϬdDϴ͘ϴϯϱ^ƵƌĨϰ͕ϳϰϳ͛ ϳ͟Ϯϲ͘ϬϬ>ͲϴϬdDϲ͘Ϯϳϱ^ƵƌĨϵ͕ϵϴϮ͛ dh/E'd/> ϰͲϭͬϮ͟ϭϮ͘ϲϬ>ͲϴϬ/dDϯ͘ϵϱϴ^ƵƌĨϳ͕ϬϱϮ͛ :t>Zzd/> EŽĞƉƚŚ ;DͿ ĞƉƚŚ ;dsͿ/ K /ƚĞŵ ϮϯΖϮϯΖϯ͘ϵϬϬdƵďŝŶŐ,ĂŶŐĞƌͲsĞƚĐŽ ϭϰϳϮΖϰϳϮΖϯ͘ϴϭϯ^>Wϲŝ>ĂŶĚŝŶŐEŝƉƉůĞ ϭĂϰϳϵ͛ϰϳϵ͛^^^sϬϱͬϯϭͬϮϮ Ϯ ϭ͕ϳϴϵΖϭ͕ϳϱϰΖϭ͘ϬϬϬĂŵĐŽ<'ͲϮͲϭZ'>s;ƵŵŵǇͿ ϯ͕ϰϴϱΖϮ͕ϳϵϴΖϭ͘ϬϬϬĂŵĐŽ<'ͲϮͲϭZ'>s;ƵŵŵǇͿ ϰ͕ϵϰϵΖϯ͕ϱϵϵΖϭ͘ϬϬϬĂŵĐŽ<'ͲϮͲϭZ'>s;ƵŵŵǇͿ ϲ͕ϬϮϰΖϰ͕ϭϵϮΖϭ͘ϬϬϬĂŵĐŽ<'ͲϮͲϭZ'>s;ƵŵŵǇͿ ϲ͕ϳϱϮΖϰ͕ϱϵϮΖϭ͘ϬϬϬĂŵĐŽ<'ͲϮͲϭZ'>s;ƵŵŵǇͿ ϲ͕ϴϯϵΖϰ͕ϲϰϬΖϮ͘ϯϳϱϭ͘ϬϬϬĂŵĐŽ<'ͲϮͲϭZ'>s;ƵŵŵǇͿ ϯϲ͕ϵϮϲΖϰ͕ϲϴϳΖϯ͘ϴϭϯyEŝƉƉůĞ ϰ ϳ͕ϬϬϴΖϰ͕ϳϯϮΖϯ͘ϴϴϬ>ŽĐĂƚŽƌ ϳ͕ϬϭϭΖϰ͕ϳϯϰΖϰ͘ϳϱϬŶĐŚŽƌWZ ϳ͕ϬϯϵΖϰ͕ϳϱϬΖϰ͘ϬϬϬϯ͘ϰϯϬ'ƌĂǀĞůWĂĐŬĞƌ;ĂŬĞƌ^ͲϮͿ ϳ͕ϬϰϬΖϰ͕ϳϱϬΖϯ͘ϮϲϬ^ĞĂůƐƐǇ;^ĞĂůhŶŝƚϴϮͲϰϬͿ ϳ͕ϬϰϳΖϰ͕ϳϱϰΖϰ͘ϬϬϬ^ĞĂůŽƌĞǆƚĞŶƐŝŽŶ ϳ͕ϬϱϭΖϰ͕ϳϱϲΖϯ͘ϮϲϬt>' ϳ͕ϬϲϮΖϰ͕ϳϲϮΖϭ͘ϯϬϬǆƚĞŶƐŝŽŶ^Ƶď ϳ͕ϬϲϲΖϰ͕ϳϲϰΖϰ͘ϯϮϬǆƚĞŶƐŝŽŶ^Ƶď ϳ͕ϬϳϳΖϰ͕ϳϳϭΖϯ͘ϰϯϬ^ŚĞĂƌKƵƚ^ĂĨĞƚǇ:ƚ ϳϳ͕ϭϱϯΖϰ͕ϴϭϯΖϯ͘ϰϯϬǆĐůƵĚĞƌ^ĐƌĞĞŶϮϬϬϬ ϴϳ͕ϰϭϵΖϰ͕ϵϲϬΖϯ͘ϰϯϬǆĐůƵĚĞƌ^ĐƌĞĞŶϮϬϬϬ ϵϳ͕ϳϰϰΖϱ͕ϭϯϳΖϯ͘ϰϯϬǆĐůƵĚĞƌ^ĐƌĞĞŶϮϬϬϬ ϭϬϳ͕ϴϵϮΖϱ͕ϮϭϴΖϯ͘ϰϯϬǆĐůƵĚĞƌ^ĐƌĞĞŶϮϬϬϬ ϭϭϴ͕ϬϰϬΖϱ͕ϮϵϴΖϯ͘ϰϯϬǆĐůƵĚĞƌ^ĐƌĞĞŶϮϬϬϬ ϭϮ ϴ͕ϮϯϳΖϱ͕ϰϬϵΖϯ͘ϮϲϬ^ŶĂƉ>ĂƚĐŚϴϮͲϰϬ^ϮϮ ϴ͕ϮϯϴΖϱ͕ϰϬϵΖϯ͘ϮϲϬ^ĞĂůhŶŝƚ;ϴϮͲϰϬϵϬ,Ϳ ϴ͕ϮϯϴΖϱ͕ϰϬϵΖϰ͘ϬϬϬϮ͘ϵϵϮWĂĐŬĞƌ;^ƵŵƉDŽĚĞů&^Ϳ ϴ͕ϮϰϭΖϱ͕ϰϭϭΖϯ͘ϮϲϬϭͬϮDƵůĞ^ŚŽĞ ϴ͕ϮϰϰΖϱ͕ϰϭϯΖϯ͘ϬϬϬƌŽƐƐŽǀĞƌϱ͘ϱΗǆϯ͘ϱΗ ϭϯϴ͕ϱϲϯΖϱ͕ϲϬϰΖϯ͘ϬϭϬt>' ϭϰϵ͕ϰϰϭΖϲ͕ϭϲϳΖϬ͘ϬϬϬ/W ϭϱϵ͕ϴϬϭΖϲ͕ϯϵϭΖϬ͘ϬϬϬ^ĂŶĚWůƵŐ;͍ĂƚĞ^ĞƚͿ &/^,d/>ΛΕϳ͕ϬϱϬ͛ϱͬϮϭͬϮϮ &ŝƐŚŝŶ,ŽůĞ͗ϭΖǆϭϳͬϭϲΗ'KĂďůĞ,ĞĂĚǁͬϭΗ&ŝƐŚEĞĐŬ͕ϱΖǆϯͲϭͬϴΗ 'ƵŶ'ĂŵŵĂ͕ϯΖǆϮͲϯͬϰΗ^ŚŽĐŬ^Ƶď͕ϮϰΖǆϮͲϳͬϴΗWĞƌĨŽƌĂƚŝŶŐ'ƵŶƐ͘ K>ϯϯ͘ϭΖ BBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBB hƉĚĂƚĞĚďǇDϬϲͲϭϯͲϮϮ EŽƌƚŚŽŽŬ/ŶůĞƚ tĞůů͗E/Ͳϭϰ >ĂƐƚŽŵƉůĞƚĞĚ͗ϬϰͬϮϯͬϮϬϬϵ Wd͗ϮϬϴͲϬϵϲ W/͗ϱϬͲϴϴϯͲϮϬϭϮϱͲϬϬͲϬϬ ^,Dd/ WĞƌĨŽƌĂƚŝŽŶĂƚĂ ŽŶĞdŽƉ;DͿƚŵ;DͿdŽƉ;dsͿƚŵ;dsͿ&dĂƚĞ^ƚĂƚƵƐ ĞůƵŐĂhƉƉĞƌϲ͕ϳϱϬ͛ϲ͕ϳϲϯ͛ϰ͕ϱϵϭ͛ϰ͕ϱϵϴ͛ϭϯ͛ϱͬϮϯͬϮϬϮϮKƉĞŶ ĞůƵŐĂ>ŽǁĞƌϲ͕ϴϯϵ͛ϲ͕ϴϲϵ͛ϰ͕ϲϰϬ͛ϰ͕ϲϱϲ͛ϯϬ͛ϱͬϮϯͬϮϬϮϮKƉĞŶ ĞůƵŐĂhƉƉĞƌϭϲ͕ϵϬϵ͛ϲ͕ϵϭϴ͛ϰ͕ϲϳϴ͛ϰ͕ϲϴϯ͛ϵ͛ϱͬϮϮͬϮϬϮϮKƉĞŶ ĞůƵŐĂhƉƉĞƌϮϲ͕ϵϯϴ͛ϲ͕ϵϱϰ͛ϰ͕ϲϵϰ͛ϰϲϰϴ͛ϭϲ͛ϱͬϮϮͬϮϬϮϮKƉĞŶ ĞůƵŐĂhƉƉĞƌϯϲ͕ϵϲϵ͛ϲ͕ϵϴϵ͛ϰ͕ϳϭϭ͛ϰ͕ϳϮϮ͛ϮϬ͛ϱͬϮϮͬϮϬϮϮKƉĞŶ ĞůƵŐĂϳ͕ϭϲϭΖϳ͕ϭϳϯΖϰ͕ϴϭϳΖϰ͕ϴϮϰΖϭϮΖϰͬϭϱͬϮϬϬϵKƉĞŶ ĞůƵŐĂϳ͕ϮϮϬΖϳ͕ϮϱϵΖϰ͕ϴϱϬΖϰ͕ϴϳϮΖϯϵΖϰͬϭϱͬϮϬϬϵKƉĞŶ ĞůƵŐĂϳ͕ϮϳϲΖϳ͕ϮϴϯΖϰ͕ϴϴϭΖϰ͕ϴϴϱΖϳΖϰͬϭϱͬϮϬϬϵKƉĞŶ ĞůƵŐĂϳ͕ϱϱϯΖϳ͕ϲϬϴΖϱ͕ϬϯϯΖϱ͕ϬϲϯΖϱϱΖϰͬϭϱͬϮϬϬϵKƉĞŶ ĞůƵŐĂϳ͕ϲϯϵΖϳ͕ϲϲϰΖϱ͕ϬϴϬΖϱ͕ϬϵϯΖϮϱΖϰͬϭϱͬϮϬϬϵKƉĞŶ ĞůƵŐĂDŝĚϳ͕ϳϱϴ͛ϳ͕ϳϲϱ͛ϱ͕ϭϰϱ͛ϱϭϰϴ͛ϳ͛ϱͬϮϮͬϮϮKƉĞŶ ĞůƵŐĂϳ͕ϴϬϳΖϳ͕ϴϮϳΖϱ͕ϭϳϭΖϱ͕ϭϴϮΖϮϬΖϰͬϭϱͬϮϬϬϵKƉĞŶ ĞůƵŐĂ>ŽǁĞƌϳ͕ϴϬϳ͛ϳ͕ϴϮϳ͛ϱ͕ϭϳϭΖϱ͕ϭϴϮΖϮϬ͛ϱͬϮϮͬϮϮKƉĞŶ ĞůƵŐĂ&ϳ͕ϵϯϳΖϳ͕ϵϰϱΖϱ͕ϮϰϮΖϱ͕ϮϰϳΖϴΖϰͬϭϱͬϮϬϬϵKƉĞŶ ĞůƵŐĂ&hƉƉĞƌϳ͕ϵϯϳ͛ϳ͕ϵϰϱ͛ϱ͕ϮϰϮΖϱ͕ϮϰϳΖϴ͛ϱͬϮϭͬϮϮKƉĞŶ ĞůƵŐĂ&ϳ͕ϵϵϱΖϴ͕ϬϬϱΖϱ͕ϮϳϰΖϱ͕ϮϳϵΖϭϬΖϰͬϭϱͬϮϬϬϵKƉĞŶ ĞůƵŐĂ&DŝĚϳ͕ϵϵϱ͛ϴ͕ϬϬϱ͛ϱ͕ϮϳϰΖϱ͕ϮϳϵΖϭϬ͛ϱͬϮϭͬϮϮKƉĞŶ ĞůƵŐĂ'ϴ͕ϬϲϴΖϴ͕ϬϴϯΖϱ͕ϯϭϰΖϱ͕ϯϮϮΖϭϱΖϰͬϭϱͬϮϬϬϵKƉĞŶ ĞůƵŐĂ'ϴ͕ϭϵϴΖϴ͕ϮϮϴΖϱ͕ϯϴϲΖϱ͕ϰϬϰΖϯϬΖϰͬϭϱͬϮϬϬϵKƉĞŶ ĞůƵŐĂ'ϴ͕ϮϭϰΖϴ͕ϮϰϲΖϱ͕ϯϵϱΖϱ͕ϰϭϰΖϯϮΖϰͬϵͬϮϬϬϵKƉĞŶ ĞůƵŐĂDϵ͕ϬϮϯΖϵ͕ϬϰϬΖϱ͕ϵϬϮΖϱ͕ϵϭϯΖϭϳΖϰͬϴͬϮϬϬϵKƉĞŶ ĞůƵŐĂYϵ͕ϲϬϰΖϵ͕ϲϮϰΖϲ͕ϮϳϬΖϲ͕ϮϴϮΖϮϬΖϰͬϴͬϮϬϬϵKƉĞŶ BBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBB hƉĚĂƚĞĚďǇ,ϬϵͲϬϭͲϮϮ WZKWK^ EŽƌƚŚŽŽŬ/ŶůĞƚ tĞůů͗E/Ͳϭϰ >ĂƐƚŽŵƉůĞƚĞĚ͗ϬϰͬϮϯͬϮϬϬϵ Wd͗ϮϬϴͲϬϵϲ W/͗ϱϬͲϴϴϯͲϮϬϭϮϱͲϬϬͲϬϬ ^/E'd/> ^ŝǌĞtƚ'ƌĂĚĞŽŶŶ/dŽƉƚŵ ϯϬ͟ϭϮϬ͘ϬϬyͲϱϲϮϳ͘ϬϬϬ^ƵƌĨϰϬϬ͛ ϵͲϱͬϴ͟ϰϬ͘ϬϬ>ͲϴϬdDϴ͘ϴϯϱ^ƵƌĨϰ͕ϳϰϳ͛ ϳ͟Ϯϲ͘ϬϬ>ͲϴϬdDϲ͘Ϯϳϱ^ƵƌĨϵ͕ϵϴϮ͛ dh/E'd/> ϰͲϭͬϮ͟ϭϮ͘ϲϬ>ͲϴϬ/dDϯ͘ϵϱϴ^ƵƌĨϳ͕ϬϱϮ͛ :t>Zzd/> EŽĞƉƚŚ ;DͿ ĞƉƚŚ ;dsͿ/ K /ƚĞŵ ϮϯΖϮϯΖϯ͘ϵϬϬdƵďŝŶŐ,ĂŶŐĞƌͲsĞƚĐŽ ϭϰϳϮΖϰϳϮΖϯ͘ϴϭϯ^>Wϲŝ>ĂŶĚŝŶŐEŝƉƉůĞ ϭĂϰϳϵ͛ϰϳϵ͛^^^sϬϱͬϯϭͬϮϮ Ϯ ϭ͕ϳϴϵΖϭ͕ϳϱϰΖϭ͘ϬϬϬĂŵĐŽ<'ͲϮͲϭZ'>s;ƵŵŵǇͿ ϯ͕ϰϴϱΖϮ͕ϳϵϴΖϭ͘ϬϬϬĂŵĐŽ<'ͲϮͲϭZ'>s;ƵŵŵǇͿ ϰ͕ϵϰϵΖϯ͕ϱϵϵΖϭ͘ϬϬϬĂŵĐŽ<'ͲϮͲϭZ'>s;ƵŵŵǇͿ ϲ͕ϬϮϰΖϰ͕ϭϵϮΖϭ͘ϬϬϬĂŵĐŽ<'ͲϮͲϭZ'>s;ƵŵŵǇͿ ϲ͕ϳϱϮΖϰ͕ϱϵϮΖϭ͘ϬϬϬĂŵĐŽ<'ͲϮͲϭZ'>s;ƵŵŵǇͿ ϲ͕ϴϯϵΖϰ͕ϲϰϬΖϮ͘ϯϳϱϭ͘ϬϬϬĂŵĐŽ<'ͲϮͲϭZ'>s;ƵŵŵǇͿ ϯϲ͕ϵϮϲΖϰ͕ϲϴϳΖϯ͘ϴϭϯyEŝƉƉůĞ ϰ ϳ͕ϬϬϴΖϰ͕ϳϯϮΖϯ͘ϴϴϬ>ŽĐĂƚŽƌ ϳ͕ϬϭϭΖϰ͕ϳϯϰΖϰ͘ϳϱϬŶĐŚŽƌWZ ϳ͕ϬϯϵΖϰ͕ϳϱϬΖϰ͘ϬϬϬϯ͘ϰϯϬ'ƌĂǀĞůWĂĐŬĞƌ;ĂŬĞƌ^ͲϮͿ ϳ͕ϬϰϬΖϰ͕ϳϱϬΖϯ͘ϮϲϬ^ĞĂůƐƐǇ;^ĞĂůhŶŝƚϴϮͲϰϬͿ ϳ͕ϬϰϳΖϰ͕ϳϱϰΖϰ͘ϬϬϬ^ĞĂůŽƌĞǆƚĞŶƐŝŽŶ ϳ͕ϬϱϭΖϰ͕ϳϱϲΖϯ͘ϮϲϬt>' ϳ͕ϬϳϳΖϰ͕ϳϳϭΖϯ͘ϰϯϬ^ŚĞĂƌKƵƚ^ĂĨĞƚǇ:ƚ ϳϳ͕ϭϱϯΖϰ͕ϴϭϯΖϯ͘ϰϯϬǆĐůƵĚĞƌ^ĐƌĞĞŶϮϬϬϬ ϴϳ͕ϰϭϵΖϰ͕ϵϲϬΖϯ͘ϰϯϬǆĐůƵĚĞƌ^ĐƌĞĞŶϮϬϬϬ ϵϳ͕ϳϰϰΖϱ͕ϭϯϳΖϯ͘ϰϯϬǆĐůƵĚĞƌ^ĐƌĞĞŶϮϬϬϬ ϭϬϳ͕ϴϵϮΖϱ͕ϮϭϴΖϯ͘ϰϯϬǆĐůƵĚĞƌ^ĐƌĞĞŶϮϬϬϬ ϭϭϴ͕ϬϰϬΖϱ͕ϮϵϴΖϯ͘ϰϯϬǆĐůƵĚĞƌ^ĐƌĞĞŶϮϬϬϬ ϭϮ ϴ͕ϮϯϳΖϱ͕ϰϬϵΖϯ͘ϮϲϬ^ŶĂƉ>ĂƚĐŚϴϮͲϰϬ^ϮϮ ϴ͕ϮϯϴΖϱ͕ϰϬϵΖϯ͘ϮϲϬ^ĞĂůhŶŝƚ;ϴϮͲϰϬϵϬ,Ϳ ϴ͕ϮϯϴΖϱ͕ϰϬϵΖϰ͘ϬϬϬϮ͘ϵϵϮWĂĐŬĞƌ;^ƵŵƉDŽĚĞů&^Ϳ ϴ͕ϮϰϭΖϱ͕ϰϭϭΖϯ͘ϮϲϬϭͬϮDƵůĞ^ŚŽĞ ϴ͕ϮϰϰΖϱ͕ϰϭϯΖϯ͘ϬϬϬƌŽƐƐŽǀĞƌϱ͘ϱΗǆϯ͘ϱΗ ϭϯϴ͕ϱϲϯΖϱ͕ϲϬϰΖϯ͘ϬϭϬt>' ϭϰϵ͕ϰϰϭΖϲ͕ϭϲϳΖϬ͘ϬϬϬ/W ϭϱϵ͕ϴϬϭΖϲ͕ϯϵϭΖϬ͘ϬϬϬ^ĂŶĚWůƵŐ &/^,d/>ΛΕϴ͕Ϭϵϱ͛ϱͬϯϭͬϮϮ &ŝƐŚŝŶ,ŽůĞ͗ϭΖǆϭϳͬϭϲΗ'KĂďůĞ,ĞĂĚǁͬϭΗ&ŝƐŚEĞĐŬ͕ϱΖǆϯͲϭͬϴΗ 'ƵŶ'ĂŵŵĂ͕ϯΖǆϮͲϯͬϰΗ^ŚŽĐŬ^Ƶď͕ϮϰΖǆϮͲϳͬϴΗWĞƌĨŽƌĂƚŝŶŐ'ƵŶƐ͘ K>ϯϯ͘ϭΖ BBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBB hƉĚĂƚĞĚďǇ,ϬϵͲϬϭͲϮϮ EŽƌƚŚŽŽŬ/ŶůĞƚ tĞůů͗E/Ͳϭϰ >ĂƐƚŽŵƉůĞƚĞĚ͗ϬϰͬϮϯͬϮϬϬϵ Wd͗ϮϬϴͲϬϵϲ W/͗ϱϬͲϴϴϯͲϮϬϭϮϱͲϬϬͲϬϬ WZKWK^ WĞƌĨŽƌĂƚŝŽŶĂƚĂ ŽŶĞdŽƉ;DͿƚŵ;DͿdŽƉ;dsͿƚŵ;dsͿ&dĂƚĞ^ƚĂƚƵƐ ĞůƵŐĂhƉƉĞƌϲ͕ϳϱϬ͛ϲ͕ϳϲϯ͛ϰ͕ϱϵϭ͛ϰ͕ϱϵϴ͛ϭϯ͛ϱͬϮϯͬϮϬϮϮKƉĞŶ ĞůƵŐĂ>ŽǁĞƌϲ͕ϴϯϵ͛ϲ͕ϴϲϵ͛ϰ͕ϲϰϬ͛ϰ͕ϲϱϲ͛ϯϬ͛ϱͬϮϯͬϮϬϮϮKƉĞŶ ĞůƵŐĂhƉƉĞƌϭϲ͕ϵϬϵ͛ϲ͕ϵϭϴ͛ϰ͕ϲϳϴ͛ϰ͕ϲϴϯ͛ϵ͛ϱͬϮϮͬϮϬϮϮKƉĞŶ ĞůƵŐĂhƉƉĞƌϮϲ͕ϵϯϴ͛ϲ͕ϵϱϰ͛ϰ͕ϲϵϰ͛ϰϲϰϴ͛ϭϲ͛ϱͬϮϮͬϮϬϮϮKƉĞŶ ĞůƵŐĂhƉƉĞƌϯϲ͕ϵϲϵ͛ϲ͕ϵϴϵ͛ϰ͕ϳϭϭ͛ϰ͕ϳϮϮ͛ϮϬ͛ϱͬϮϮͬϮϬϮϮKƉĞŶ ĞůƵŐĂϳ͕ϭϲϭΖϳ͕ϭϳϯΖϰ͕ϴϭϳΖϰ͕ϴϮϰΖϭϮΖϰͬϭϱͬϮϬϬϵKƉĞŶ ĞůƵŐĂ>ŽǁĞƌцϳ͕ϭϲϭ͛цϳ͕ϭϳϯ͛цϰ͕ϴϭϳΖцϰ͕ϴϮϰΖϭϮ͛WƌŽƉŽƐĞĚd ĞůƵŐĂϳ͕ϮϮϬΖϳ͕ϮϱϵΖϰ͕ϴϱϬΖϰ͕ϴϳϮΖϯϵΖϰͬϭϱͬϮϬϬϵKƉĞŶ ĞůƵŐĂhƉƉĞƌцϳ͕ϮϮϬ͛цϳ͕Ϯϱϵ͛цϰ͕ϴϱϬΖцϰ͕ϴϳϮΖϯϵ͛WƌŽƉŽƐĞĚd ĞůƵŐĂϳ͕ϮϳϲΖϳ͕ϮϴϯΖϰ͕ϴϴϭΖϰ͕ϴϴϱΖϳΖϰͬϭϱͬϮϬϬϵKƉĞŶ ĞůƵŐĂDŝĚцϳ͕Ϯϳϲ͛цϳ͕Ϯϴϯ͛цϰ͕ϴϴϭΖцϰ͕ϴϴϱΖϳ͛WƌŽƉŽƐĞĚd ĞůƵŐĂ>ŽǁĞƌцϳ͕ϯϭϯ͛цϳ͕ϯϭϴ͛цϰ͕ϵϬϮ͛ц͕ϰϵϬϰ͛ϱ͛WƌŽƉŽƐĞĚd ĞůƵŐĂDŝĚцϳ͕ϰϳϭ͛цϳ͕ϰϴϱ͛цϰ͕ϵϴϵ͛цϰ͕ϵϵϲ͛ϭϰ͛WƌŽƉŽƐĞĚd ĞůƵŐĂϳ͕ϱϱϯΖϳ͕ϲϬϴΖϱ͕ϬϯϯΖϱ͕ϬϲϯΖϱϱΖϰͬϭϱͬϮϬϬϵKƉĞŶ ĞůƵŐĂ>ŽǁĞƌцϳ͕ϱϱϯ͛цϳ͕ϱϵϯ͛цϱ͕ϬϯϯΖцϱ͕Ϭϱϱ͛ϰϬ͛WƌŽƉŽƐĞĚd ĞůƵŐĂϳ͕ϲϯϵΖϳ͕ϲϲϰΖϱ͕ϬϴϬΖϱ͕ϬϵϯΖϮϱΖϰͬϭϱͬϮϬϬϵKƉĞŶ ĞůƵŐĂhƉƉĞƌϭцϳ͕ϲϯϵ͛цϳ͕ϲϱϵ͛цϱ͕ϬϴϬΖцϱ͕Ϭϵϭ͛ϮϬ͛WƌŽƉŽƐĞĚd ĞůƵŐĂhƉƉĞƌϮцϳ͕ϲϳϴ͛цϳ͕ϲϵϴ͛цϱ͕ϭϬϭ͛цϱ͕ϭϭϮ͛ϮϬ͛WƌŽƉŽƐĞĚd ĞůƵŐĂDŝĚϳ͕ϳϱϴ͛ϳ͕ϳϲϱ͛ϱ͕ϭϰϱ͛ϱϭϰϴ͛ϳ͛ϱͬϮϮͬϮϮKƉĞŶ ĞůƵŐĂϳ͕ϴϬϳΖϳ͕ϴϮϳΖϱ͕ϭϳϭΖϱ͕ϭϴϮΖϮϬΖϰͬϭϱͬϮϬϬϵKƉĞŶ ĞůƵŐĂ>ŽǁĞƌϳ͕ϴϬϳ͛ϳ͕ϴϮϳ͛ϱ͕ϭϳϭΖϱ͕ϭϴϮΖϮϬ͛ϱͬϮϮͬϮϮKƉĞŶ ĞůƵŐĂ&ϳ͕ϵϯϳΖϳ͕ϵϰϱΖϱ͕ϮϰϮΖϱ͕ϮϰϳΖϴΖϰͬϭϱͬϮϬϬϵKƉĞŶ ĞůƵŐĂ&hƉƉĞƌϳ͕ϵϯϳ͛ϳ͕ϵϰϱ͛ϱ͕ϮϰϮΖϱ͕ϮϰϳΖϴ͛ϱͬϮϭͬϮϮKƉĞŶ ĞůƵŐĂ&ϳ͕ϵϵϱΖϴ͕ϬϬϱΖϱ͕ϮϳϰΖϱ͕ϮϳϵΖϭϬΖϰͬϭϱͬϮϬϬϵKƉĞŶ ĞůƵŐĂ&DŝĚϳ͕ϵϵϱ͛ϴ͕ϬϬϱ͛ϱ͕ϮϳϰΖϱ͕ϮϳϵΖϭϬ͛ϱͬϮϭͬϮϮKƉĞŶ ĞůƵŐĂ'ϴ͕ϬϲϴΖϴ͕ϬϴϯΖϱ͕ϯϭϰΖϱ͕ϯϮϮΖϭϱΖϰͬϭϱͬϮϬϬϵKƉĞŶ ĞůƵŐĂ'ϴ͕ϭϵϴΖϴ͕ϮϮϴΖϱ͕ϯϴϲΖϱ͕ϰϬϰΖϯϬΖϰͬϭϱͬϮϬϬϵKƉĞŶ ĞůƵŐĂ'ϴ͕ϮϭϰΖϴ͕ϮϰϲΖϱ͕ϯϵϱΖϱ͕ϰϭϰΖϯϮΖϰͬϵͬϮϬϬϵKƉĞŶ ĞůƵŐĂDϵ͕ϬϮϯΖϵ͕ϬϰϬΖϱ͕ϵϬϮΖϱ͕ϵϭϯΖϭϳΖϰͬϴͬϮϬϬϵKƉĞŶ ĞůƵŐĂYϵ͕ϲϬϰΖϵ͕ϲϮϰΖϲ͕ϮϳϬΖϲ͕ϮϴϮΖϮϬΖϰͬϴͬϮϬϬϵKƉĞŶ Kaitlyn Barcelona Hilcorp North Slope, LLC GeoTechnician 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: 907 564-4389 E-mail: kaitlyn.barcelona@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal Received By: Date: DATE: 06/14/2022 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 DATA TRANSMITTAL NCI A-14 (PTD 208-096) PERF 05/23/2022 Please include current contact information if different from above. PTD:208-096 T36705 Kayla Junke Digitally signed by Kayla Junke Date: 2022.06.17 10:14:51 -08'00' Kaitlyn Barcelona Hilcorp North Slope, LLC GeoTechnician 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: 907 564-4389 E-mail: kaitlyn.barcelona@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal Received By: Date: DATE: 06/06/2022 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 DATA TRANSMITTAL NCI A-14 (PTD 208-096) PLUG/PUNCH 05/16/2022 CBL 05/18/2022 Please include current contact information if different from above. PTD: 208-096 T36688 T36689 Kayla Junke Digitally signed by Kayla Junke Date: 2022.06.08 13:44:07 -08'00' CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:Donna Ambruz To:AOGCC Permitting (CED sponsored) Cc:Chad Helgeson Subject:Sundry NCIU A-14 #321-286 PTD 208-096 / Withdrawal Date:Friday, April 29, 2022 2:47:26 PM Attachments:Sundry_321-286_061621.pdf Please withdraw/cancel the above-referenced sundry. Thank you. Donna Ambruz Operations/Regulatory Tech KEN Asset Team Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 907.777.8305 - Direct dambruz@hilcorp.com From: Carlisle, Samantha J (CED) <samantha.carlisle@alaska.gov> Sent: Wednesday, June 16, 2021 5:31 PM To: Abbie Barker <Abbie.Barker@hilcorp.com>; Carrie Janowski <Carrie.Janowski@hilcorp.com>; Cody Dinger <cdinger@hilcorp.com>; Darci Horner - (C) <dhorner@hilcorp.com>; Donna Ambruz <dambruz@hilcorp.com>; Jerimiah Galloway <Jerimiah.Galloway@hilcorp.com>; Joseph Lastufka <Joseph.Lastufka@hilcorp.com>; Juanita Lovett <jlovett@hilcorp.com>; Julie Wellman - (C) <Julie.Wellman@hilcorp.com>; Tom Fouts <tfouts@hilcorp.com> Subject: [EXTERNAL] Sundry_NCIU A-14 Samantha Carlisle Executive Secretary III Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Anchorage, AK 99501 (907) 793-1223 The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please immediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently delete this message. 5HJJ-DPHV%2*& )URP7RGG6LGRWL&7RGG6LGRWL#KLOFRUSFRP! 6HQW6XQGD\0D\30 7R5HJJ-DPHV%2*&'2$$2*&&3UXGKRH%D\%URRNV3KRHEH/2*& 6XEMHFW1&,8$37'&7%23(7HVW5HSRUW $WWDFKPHQWV%23(7HVW5HSRUW1&,8$[OV[ ,ĞůůŽ͕ WůĞĂƐĞƐĞĞĂƚƚĂĐŚĞĚĐŽŝůĞĚƚƵďŝŶŐKWƚĞƐƚƌĞƉŽƌƚ͘ ZĞŐĂƌĚƐ͕ dŽĚĚ dŽĚĚ^ŝĚŽƚŝͮ<ĞŶĂŝ&ŝĞůĚŶŐŝŶĞĞƌͮ,ŝůĐŽƌƉůĂƐŬĂͮϵϬϳͲϲϯϮͲϰϭϭϯ 7KHLQIRUPDWLRQFRQWDLQHGLQWKLVHPDLOPHVVDJHLVFRQILGHQWLDODQGPD\EHOHJDOO\SULYLOHJHGDQGLVLQWHQGHGRQO\IRUWKHXVHRIWKHLQGLYLGXDORUHQWLW\QDPHG DERYH,I\RXDUHQRWDQLQWHQGHGUHFLSLHQWRULI\RXKDYHUHFHLYHGWKLVPHVVDJHLQHUURU\RXDUHKHUHE\QRWLILHGWKDWDQ\GLVVHPLQDWLRQGLVWULEXWLRQRUFRS\RIWKLV HPDLOLVVWULFWO\SURKLELWHG,I\RXKDYHUHFHLYHGWKLVHPDLOLQHUURUSOHDVHLPPHGLDWHO\QRWLI\XVE\UHWXUQHPDLORUWHOHSKRQHLIWKHVHQGHU VSKRQHQXPEHULVOLVWHG DERYHWKHQSURPSWO\DQGSHUPDQHQWO\GHOHWHWKLVPHVVDJH :KLOHDOOUHDVRQDEOHFDUHKDVEHHQWDNHQWRDYRLGWKHWUDQVPLVVLRQRIYLUXVHVLWLVWKHUHVSRQVLELOLW\RIWKHUHFLSLHQWWRHQVXUHWKDWWKHRQZDUGWUDQVPLVVLRQ RSHQLQJRUXVHRIWKLVPHVVDJHDQGDQ\DWWDFKPHQWVZLOOQRWDGYHUVHO\DIIHFWLWVV\VWHPVRUGDWD1RUHVSRQVLELOLW\LVDFFHSWHGE\WKHFRPSDQ\LQWKLVUHJDUGDQG WKHUHFLSLHQWVKRXOGFDUU\RXWVXFKYLUXVDQGRWKHUFKHFNVDVLWFRQVLGHUVDSSURSULDWH &$87,217KLVHPDLORULJLQDWHGIURPRXWVLGHWKH6WDWHRI$ODVNDPDLOV\VWHP'RQRWFOLFNOLQNVRURSHQ DWWDFKPHQWVXQOHVV\RXUHFRJQL]HWKHVHQGHUDQGNQRZWKHFRQWHQWLVVDIH 1&,8$ 37' STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION *All BOPE reports are due to the agency within 5 days of testing* SSu b m i t t o :jim.regg@alaska.gov; AOGCC.Inspectors@alaska.gov; phoebe.brooks@alaska.gov Owner/Contractor: Rig No.:1 DATE: 5/15/22 Rig Rep.: Rig Phone: 907-659-2434 Operator: Op. Phone:907-777-8300 Rep.: E-Mail Well Name: PTD #22080960 Sundry #322-211 Operation: Drilling: Workover: X Explor.: Test: Initial: Weekly: X Bi-Weekly: Other: Rams:250/2500 Annular:NA Valves:250/2500 MASP:408 MISC. INSPECTIONS: TEST DATA FLOOR SAFETY VALVES: Test Result Test Result Quantity Test Result Location Gen.P Well Sign P Upper Kelly 0NA Housekeeping P Rig NA Lower Kelly 0NA PTD On Location P Hazard Sec.NA Ball Type 0NA Standing Order Posted NA Misc.NA Inside BOP 0NA FSV Misc 0NA BOP STACK:Quantity Size/Type Test Result MUD SYSTEM:Visual Alarm Stripper 1 1.75" top load P Trip Tank NA NA Annular Preventer 0 NA NA Pit Level Indicators NA NA #1 Rams 1 1.75 B/S P Flow Indicator NA NA #2 Rams 1 1.75 B/S P Meth Gas Detector NA NA #3 Rams 1 1.75 Slips P H2S Gas Detector NA NA #4 Rams 1 1.75 Pipes P MS Misc 0NA #5 Rams 0 NA NA #6 Rams 0 NA NA Quantity Test Result Choke Ln. Valves 1 2x2 FMC P Inside Reel valves 1P HCR Valves 0 NA NA Kill Line Valves 2 2x2 FMC P Check Valve 1 2" 1502 P ACCUMULATOR SYSTEM: BOP Misc 3 EQ PORTS P Time/Pressure Test Result System Pressure (psi)3000 P CHOKE MANIFOLD:Pressure After Closure (psi)1550 P Quantity Test Result 200 psi Attained (sec)21 P No. Valves 5P Full Pressure Attained (sec)78 P Manual Chokes 2P Blind Switch Covers: All stations Yes Hydraulic Chokes 0NA Nitgn. Bottles # & psi (Avg.): NA NA CH Misc 0NA ACC Misc 0NA Test Results Number of Failures:0 Test Time:4.5 Hours Repair or replacement of equipment will be made within NA days. Remarks: AOGCC Inspection 24 hr Notice Yes Date/Time 5-13-22 / 20:51 Waived By Test Start Date/Time:5/15/2022 10:00 (date) (time)Witness Test Finish Date/Time:5/15/2022 14:30 BOPE Test Report Notify the AOGCC of repairs with written confirmation to: AOGCC.Inspectors@alaska.gov Jim Regg Schlumberger A push/pull test was conducted on the SLB coil slip rams. Daniel Perry Hilcorp Todd Sidoti NCIU A-14 Test Pressure (psi): todd.sidoti@hilcorp.com Form 10-424 (Revised 02/2022) 2022-0515_BOP_Schlumberger1_NCIU_A-14 9 9 9 9 9 9 9 9 9 9 9 9 MEU -5HJJ CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:McLellan, Bryan J (OGC) To:Chad Helgeson Cc:Donna Ambruz Subject:RE: NCIU A-14 (PTD# 208-096) Sundry # 322-211 Date:Thursday, May 19, 2022 4:32:00 PM Chad, Approval granted to proceed with perfs. Bryan McLellan Senior Petroleum Engineer Alaska Oil & Gas Conservation Commission 333 W 7th Ave Anchorage, AK 99501 Bryan.mclellan@alaska.gov +1 (907) 250-9193 From: Chad Helgeson <chelgeson@hilcorp.com> Sent: Thursday, May 19, 2022 11:24 AM To: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov> Cc: Donna Ambruz <dambruz@hilcorp.com> Subject: NCIU A-14 (PTD# 208-096) Sundry # 322-211 Bryan, Please find attached CBL from the cement annulus that was pumped on the Tyonek A-14 well Tuesday. The top of good set up cement is 6,590’. The calculated cement top is 6,100’, and the log shows cement stringers (assuming not hardened yet, because log was run 18hrs after wet cement) up to ~6,230’. The good cement top is 160ft above the top proposed perfs (6,750’). Let me know if you want to discuss these results at all. We plan to perforate the well this weekend, so if you can review today or tomorrow, it would be greatly appreciated. Thanks Chad Helgeson KEN Operations Engineer Hilcorp Alaska LLC chelgeson@hilcorp.com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ll BOPE reports are due to the agency within 5 days of testing* SSu b m i t t o :jim.regg@alaska.gov; AOGCC.Inspectors@alaska.gov; phoebe.brooks@alaska.gov Owner/Contractor: Rig No.:1 DATE: 5/8/22 Rig Rep.: Rig Phone: 907-659-2434 Operator: Op. Phone:907-777-8300 Rep.: E-Mail Well Name: PTD #22080960 Sundry #322-211 Operation: Drilling: Workover: X Explor.: Test: Initial: X Weekly: Bi-Weekly: Other: Rams:250/2500 Annular:250/2500 Valves:250/2500 MASP:408 MISC. INSPECTIONS: TEST DATA FLOOR SAFETY VALVES: Test Result Test Result Quantity Test Result Location Gen.P Well Sign P Upper Kelly 0NA Housekeeping P Rig NA Lower Kelly 0NA PTD On Location P Hazard Sec.NA Ball Type 0NA Standing Order Posted NA Misc.NA Inside BOP 1P FSV Misc 1P BOP STACK:Quantity Size/Type Test Result MUD SYSTEM:Visual Alarm Stripper 1 1.75" top load P Trip Tank NA NA Annular Preventer 1 7-1/16"P Pit Level Indicators NA NA #1 Rams 1 1.90" rams P Flow Indicator NA NA #2 Rams 1 7-1/16" Blinds P Meth Gas Detector NA NA #3 Rams 1 1.75 B/S P H2S Gas Detector NA NA #4 Rams 1 1.75 B/S P MS Misc 0NA #5 Rams 1 1.75 Slips P #6 Rams 1 1.75 Pipes P Quantity Test Result Choke Ln. Valves 1 2x2 FMC P Inside Reel valves 1P HCR Valves 0 NA NA Kill Line Valves 2 2x2 FMC P Check Valve 1 2" 1502 P ACCUMULATOR SYSTEM: BOP Misc 3 EQ PORTS P Time/Pressure Test Result System Pressure (psi)3000 P CHOKE MANIFOLD:Pressure After Closure (psi)2700 P Quantity Test Result 200 psi Attained (sec)28 P No. Valves 5P Full Pressure Attained (sec)61 P Manual Chokes 2P Blind Switch Covers: All stations Yes Hydraulic Chokes 0NA Nitgn. Bottles # & psi (Avg.): 20 1050 P CH Misc 0NA ACC Misc 0NA Test Results Number of Failures:0 Test Time:6.0 Hours Repair or replacement of equipment will be made within NA days. Remarks: AOGCC Inspection 24 hr Notice Yes Date/Time 5/6/22 15:51 Waived By Test Start Date/Time:5/8/2022 15:00 (date) (time)Witness Test Finish Date/Time:5/8/2022 21:00 BOPE Test Report Notify the AOGCC of repairs with written confirmation to: AOGCC.Inspectors@alaska.gov Jim Regg Schlumberger A push/pull test was conducted on the SLB coil slip rams. A separate accumulator system was used for YellowJacket pipe BOPs placed above the SLB coiled Tubing BOPs. Bryson Lowe Hilcorp Brad Gathman NCIU A-14 Test Pressure (psi): brad.gathman@hilcorp.com Form 10-424 (Revised 02/2022) 2022-0508_BOP_Schlumberger1_NCIU_A-14 9 9 99 9 9 9 9 9 9 9 9 9 9 CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:Brad Gathman - (C) To:Regg, James B (OGC) Subject:Re: [EXTERNAL] RE: BOPE Test Report NCIU A-14 4-29-22 Date:Friday, May 6, 2022 1:09:31 PM Jim, Test pressure on the annular was 250/2500 psi. Sorry, missed that input box. Thanks, Brad Gathman WSM, Hilcorp AK +1 907-297-8412 On May 6, 2022, at 12:52 PM, Regg, James B (OGC) <jim.regg@alaska.gov> wrote: What was the test pressure for Annular? Jim Regg Supervisor, Inspections AOGCC 333 W. 7th Ave, Suite 100 Anchorage, AK 99501 907-793-1236 From: Brad Gathman - (C) <Brad.Gathman@hilcorp.com> Sent: Monday, May 2, 2022 7:01 AM To: Regg, James B (OGC) <jim.regg@alaska.gov>; DOA AOGCC Prudhoe Bay <doa.aogcc.prudhoe.bay@alaska.gov>; Brooks, Phoebe L (OGC) <phoebe.brooks@alaska.gov> Cc: Juanita Lovett <jlovett@hilcorp.com> Subject: BOPE Test Report NCIU A-14 4-29-22 The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please immediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently delete this message. 1&,8$ 37' STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION *All BOPE reports are due to the agency within 5 days of testing* SSu b m i tt t o :jim.regg@alaska.gov; AOGCC.Inspectors@alaska.gov; phoebe.brooks@alaska.gov Owner/Contractor: Rig No.:1 DATE: 4/30/22 Rig Rep.: Rig Phone: 907-659-2434 Operator: Op. Phone:907-777-8300 Rep.: E-Mail Well Name: PTD #22080960 Sundry #322-211 Operation: Drilling: Workover: X Explor.: Test: Initial: X Weekly: Bi-Weekly: Other: Rams:250/2500 Annular:250/2500 Valves:250/2500 MASP:408 MISC. INSPECTIONS: TEST DATA FLOOR SAFETY VALVES: Test Result Test Result Quantity Test Result Location Gen.P Well Sign P Upper Kelly 0NA Housekeeping P Rig NA Lower Kelly 0NA PTD On Location P Hazard Sec.NA Ball Type 0NA Standing Order Posted NA Misc.NA Inside BOP 0NA FSV Misc 0NA BOP STACK:Quantity Size/Type Test Result MUD SYSTEM:Visual Alarm Stripper 1 1.75" top load P Trip Tank NA NA Annular Preventer 1 7-1/16"P Pit Level Indicators NA NA #1 Rams 1 1.90" rams P Flow Indicator NA NA #2 Rams 1 7-1/16" Blinds P Meth Gas Detector NA NA #3 Rams 1 1.75 B/S P H2S Gas Detector NA NA #4 Rams 1 1.75 B/S P MS Misc 0NA #5 Rams 1 1.75 Slips P #6 Rams 1 1.75 Pipes P Quantity Test Result Choke Ln. Valves 1 2x2 FMC P Inside Reel valves 1P HCR Valves 0 NA NA Kill Line Valves 2 2x2 FMC P Check Valve 1 2" 1502 P ACCUMULATOR SYSTEM: BOP Misc 3 EQ PORTS P Time/Pressure Test Result System Pressure (psi)3150 P CHOKE MANIFOLD:Pressure After Closure (psi)2700 P Quantity Test Result 200 psi Attained (sec)22 P No. Valves 5P Full Pressure Attained (sec)83 P Manual Chokes 2P Blind Switch Covers: All stations Yes Hydraulic Chokes 0NA Nitgn. Bottles # & psi (Avg.): 20 at 1060 P CH Misc 0NA ACC Misc 0NA Test Results Number of Failures:0 Test Time:4.5 Hours Repair or replacement of equipment will be made within NA days. Remarks: AOGCC Inspection 24 hr Notice Yes Date/Time 4/26/22 08:05 Waived By Test Start Date/Time:4/29/2022 17:30 (date) (time)Witness Test Finish Date/Time:4/30/2022 15:00 BOPE Test Report Notify the AOGCC of repairs with written confirmation to: AOGCC.Inspectors@alaska.gov Jim Regg Schlumberger A separate accumulator system was used for YellowJacket pipe BOPs placed above the SLB coiled Tubing BOPs. A push/pull test was conducted on the SLB coil slip rams. Testing of SLB coil BOP's was done from 17:30 to 19:30 on 4/29/22 Testing of YellowJacket pipe BOP's was done from 12:30 to 15:00 on 4/30/22 Bryson Lowe Hilcorp Brad Gathman NCIU A-14 Test Pressure (psi): brad.gathman@hilcorp.com Form 10-424 (Revised 02/2022) 2022-0429_BOP_Schlumberger1_NCIU_A-14 9 9 9 9 9 9 9 9 9 9 9 9 9 9 99 0$63RQ6XQGU\IRUPLV SVLZRUNSURFHGXUH VKRZVSVLMEU -5HJJ 408 A separate accumulator system was used for YellowJacket pipe BOPs placed above the SLB coiled Tubing BOPs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DŽŶŝƚŽƌǁĞůůƚŽĞŶƐƵƌĞŝƚŝƐƐƚĂƚŝĐ͘ZĞƐĞƌǀŽŝƌƉƌĞƐƐƵƌĞŝƐĂƉƉƌŽǆŝŵĂƚĞůǇϳϱϬƉƐŝ͕ ĞǆƉĞĐƚǁĞůůƚŽĚƌŝŶŬĨůƵŝĚ ϭϭ͘ ZhΘZ/,ǁŝƚŚϯ͟WZ^tĞĂƚŚĞƌĨŽƌĚ>WdƉĂĐŬĞƌƌĞƚƌŝĞǀĂůƚŽŽů ϭϮ͘ >ĂƚĐŚĚĞĞƉŐĂƐůŝĨƚůŽǁĞƌƉĂĐŬĞƌĂŶĚϭ͘ϵϬϬ͟ƉŝƉĞǁͬũĞǁĞůƌǇ͕WKK, Ă͘ ^ƵƉƉŽƌƚϭ͘ϵϬϬ͟ƉŝƉĞǁŝƚŚƐůŝƉƐĂŶĚůĂǇĚŽǁŶůŽǁĞƌƉĂĐŬĞƌ ď͘ >ĂƚĐŚƚŚĞϭ͘ϵϬϬ͟ƉŝƉĞǁŝƚŚƚŚĞĐƌĂŶĞĂŶĚ>ͬĂůůϰϰũŽŝŶƚƐǁͬũĞǁĞůƌǇ ƉĞƌĨŽƌĂƚĞĂĚĚŝƚŝŽŶĂůďǇƉĂƐƐĞĚĞůƵŐĂƐĂŶĚƐ͘ dĞƌƚŝĂƌǇ'ĂƐWŽŽů͘ 6DIHW\ MRLQW ZLWK )269 DQG FURVVRYHU WR SLSH WKUHDG PXVW EH UHDGLO\ DFFHVVLEOH RQ VFDIIROGLQJ 3HUIRUP GULOO WR SLFN XS DQG GHSOR\ VDIHW\ MRLQW 5HFRUG GULOO RQ GDLO\ UHSRUW LQ EMP tĞůůtŽƌŬWƌŽŐŶŽƐŝƐ tĞůů͗E/hͲϭϰ ĂƚĞ͗ϰͬϭϭͬϮϬϮϮ ϭϯ͘ ZWŝƉĞKW;ƌĞƚĞƐƚĐŽŝůKWďƌĞĂŬƐďĞĨŽƌĞƌĞƐƵŵŝŶŐĂŶǇĐŽŝůǁŽƌŬͿ ϭϰ͘ ZhůŝŶĞΘƉƌĞƐƐƵƌĞƚĞƐƚůƵďƌŝĐĂƚŽƌϮϱϬ>ͬϭϱϬϬ,ƉƐŝ ϭϱ͘ Z/,ĂŶĚƐĞƚĐŽŵƉŽƐŝƚĞƉůƵŐΕϳ͕ϬϬϬ͛;ĂďŽǀĞWĂĐŬĞƌƐĞĂůĂƐƐĞŵďůǇůŽĐĂƚŽƌŶŝƉƉůĞͿ ϭϲ͘ Z/,ǁŝƚŚƚƵďŝŶŐƉƵŶĐŚ͕ƚĂŐƚŽƉŽĨƉůƵŐ͕WhĂŶĚƉƵŶĐŚŚŽůĞƐΕϲ͕ϵϵϳ͛ŶĞĂƌĐŽůůĂƌ ϭϳ͘ ƐƚĂďůŝƐŚĐŝƌĐƵůĂƚŝŽŶĨƌŽŵƚƵďŝŶŐƚŽ/͕ĐŝƌĐƵůĂƚĞǁĞůů ϭϴ͘ Whd͕Z/,ǁͬƐŝŶŐůĞƚƌŝƉĐĞŵĞŶƚƌĞƚĂŝŶĞƌĂŶĚƐĞƚĂƚΕϲ͕ϵϴϱ͛ ϭϵ͘ WƵŵƉϭϳďďůƐŽĨϭϱ͘ϯƉƉŐĐĞŵĞŶƚ;ƐƚdKΕϲ͕Ϭϴϯ͛ͿƚĂŬŝŶŐƌĞƚƵƌŶƐƚŚƌŽƵŐŚ/͘ Ă͘ ŶŶƵůƵƐǀŽůƵŵĞĨŽƌϵϭϰ͛сϭϳďďůƐΛϬ͘ϬϭϴϲďďůͬĨƚ ϮϬ͘ WƵůůŽƵƚŽĨƌĞƚĂŝŶĞƌ͕ĐŝƌĐƵůĂƚĞǁĞůů Ϯϭ͘ WKK, ϮϮ͘ tĂŝƚŽŶĐĞŵĞŶƚ Ϯϯ͘ D/dͲ/ΘdƵďŝŶŐƚŽϮϬϬϬƉƐŝĨŽƌϯϬĐŚĂƌƚĞĚŵŝŶƵƚĞƐ Ϯϰ͘ Z/,ĂŶĚĐŽŵƉůĞƚĞ>ŽŶŶĞǁĐĞŵĞŶƚ Ϯϱ͘ DhdŵŽƚŽƌͬŵŝůůĂƐƐĞŵďůǇ Ϯϲ͘ Z/,ĂŶĚŽďƚĂŝŶĚƌǇƚĂŐƚŽƉŽĨƌĞƚĂŝŶĞƌ Ϯϳ͘ DŝůůƵƉƌĞƚĂŝŶĞƌĂŶĚĐĞŵĞŶƚƚŚƌŽƵŐŚĐŽŵƉŽƐŝƚĞƉůƵŐΛϳ͕ϬϬϬ͛ Ϯϴ͘ WƌĞƉĂƌĞĨŽƌŶŝƚƌŽŐĞŶďůŽǁĚŽǁŶŽƉĞƌĂƚŝŽŶƐ Ϯϵ͘ Z/,ĂŶĚEϮůŝĨƚĂůůĨůƵŝĚĨƌŽŵǁĞůůďŽƌĞ͕ƵƐŝŶŐĨŽĂŵĂƐŶĞĐĞƐƐĂƌǇƚŽƵŶůŽĂĚǁĞůů ϯϬ͘ ZĞƚƵƌŶǁĞůůƚŽƉƌŽĚƵĐƚŝŽŶ ϯϭ͘ ZDKd WĞƌĨWƌŽĐĞĚƵƌĞ͗ ϯϮ͘ D/ZhͲůŝŶĞĂŶĚƉƌĞƐƐƵƌĞĐŽŶƚƌŽůĞƋƵŝƉŵĞŶƚ ϯϯ͘ WdůƵďƌŝĐĂƚŽƌƚŽϮϱϬ>ͬϮ͕ϱϬϬ,ƉƐŝ ϯϰ͘ ZŝŐƵƉ,ƉĞƌĨŐƵŶƐ ϯϱ͘ Z/,ĂŶĚƉĞƌĨŽƌĂƚĞƚŚĞƐĂŶĚůŝƐƚĞĚŝŶƚŚĞƚĂďůĞďĞůŽǁ͕ƉĞƌ'ĞŽͬZ ^ĂŶĚ WĞƌĨŽƌĂƚŝŽŶdŽƉ ;DͿ WĞƌĨŽƌĂƚŝŽŶŽƚƚŽŵ ;DͿ dŽƚĂů&ŽŽƚĂŐĞ ;DͿ ĞůƵŐĂhƉƉĞƌ цϲ͕ϳϱϬ͛ цϲ͕ϳϲϯ͛ ϭϯ͛ ĞůƵŐĂ>ŽǁĞƌ цϲ͕ϴϯϵ͛ цϲ͕ϴϲϵ͛ ϯϬ͛ ĞůƵŐĂhƉƉĞƌϭ цϲ͕ϵϬϵ͛ цϲ͕ϵϭϴ͛ ϵ͛ ĞůƵŐĂhƉƉĞƌϮ цϲ͕ϵϯϴ͛ цϲ͕ϵϱϰ͛ ϭϲ͛ ĞůƵŐĂhƉƉĞƌϯ цϲ͕ϵϲϵ͛ цϲ͕ϵϴϵ͛ ϮϬ͛ ĞůƵŐĂ>ŽǁĞƌ цϳ͕ϭϲϭ͛ цϳ͕ϭϳϯ͛ ϭϮ͛ ĞůƵŐĂhƉƉĞƌ цϳ͕ϮϮϬ͛ цϳ͕Ϯϱϵ͛ ϯϵ͛ ĞůƵŐĂDŝĚ цϳ͕Ϯϳϲ͛ цϳ͕Ϯϴϯ͛ ϳ͛ ĞůƵŐĂ>ŽǁĞƌ цϳ͕ϯϭϯ͛ цϳ͕ϯϭϴ͛ ϱ͛ ĞůƵŐĂDŝĚ цϳ͕ϰϳϭ͛ цϳ͕ϰϴϱ͛ ϭϰ͛ ĞůƵŐĂ>ŽǁĞƌ цϳ͕ϱϱϯ͛ цϳ͕ϱϵϯ͛ ϰϬ͛ ĞůƵŐĂhƉƉĞƌϭ цϳ͕ϲϯϵ͛ цϳ͕ϲϱϵ͛ ϮϬ͛ 6HQG &%/ WR $2*&& IRU DSSURYDO EHIRUH SHUIRUDWLQJ EMP tĞůůtŽƌŬWƌŽŐŶŽƐŝƐ tĞůů͗E/hͲϭϰ ĂƚĞ͗ϰͬϭϭͬϮϬϮϮ ĞůƵŐĂhƉƉĞƌϮ цϳ͕ϲϳϴ͛ цϳ͕ϲϵϴ͛ ϮϬ͛ ĞůƵŐĂDŝĚ цϳ͕ϳϱϴ͛ цϳ͕ϳϲϱ͛ ϳ͛ ĞůƵŐĂ>ŽǁĞƌ цϳ͕ϴϬϳ͛ цϳ͕ϴϮϳ͛ ϮϬ͛ ĞůƵŐĂ&hƉƉĞƌ цϳ͕ϵϯϳ͛ цϳ͕ϵϰϱ͛ ϴ͛ ĞůƵŐĂ&DŝĚ цϳ͕ϵϵϱ͛ цϴ͕ϬϬϱ͛ ϭϬ͛ DĂŬĞĐŽƌƌĞůĂƚŝŽŶƉĂƐƐĂŶĚƐĞŶĚůŽŐŝŶƚŽKƉĞƌĂƚŝŽŶƐŶŐŝŶĞĞƌ͕ZĞƐĞƌǀŽŝƌŶŐŝŶĞĞƌĂŶĚƚŚĞ'ĞŽůŽŐŝƐƚ͘ Ă͘hƐĞ'ĂŵŵĂͬ>ƚŽĐŽƌƌĞůĂƚĞŽŶƚŚĞĨŝŶĂůƐŝŐŶĞĚƉĞƌĨƐŚĞĞƚ͘ ď͘ ZĞĐŽƌĚŝŶŝƚŝĂůĂŶĚϱͬϭϬͬϭϱŵŝŶƵƚĞƚƵďŝŶŐƉƌĞƐƐƵƌĞƐĂĨƚĞƌĨŝƌŝŶŐ Đ͘ ŽŶƐƵůƚǁŝƚŚZͬ'ĞŽ;ŚƌŝƐ<ĂŶǇĞƌͬĂŶŝĞůzĂŶĐǇͿďĞƚǁĞĞŶĞĂĐŚƉĞƌĨŝŶƚĞƌǀĂů Ě͘ ďŽǀĞƉĞƌĨƐǁŝůůďĞƐŚŽƚŝŶƚŚĞEŽƌƚŚŽŽŬ/ŶůĞƚ͕dĞƌƚŝĂƌǇ'ĂƐWŽŽů͘ ϯϲ͘ ZͲ>ŝŶĞhŶŝƚĂŶĚƚƵƌŶǁĞůůŽǀĞƌƚŽƉƌŽĚƵĐƚŝŽŶ ϯϳ͘ ^ůŝĐŬůŝŶĞƚŽƌĞƐĞƚtZ^sĂƐƉĞƌϮϬϮϱ͘Ϯϲϱ ĂͿ EŽƚŝĨǇK'ϰϴŚƌƐŝŶĂĚǀĂŶĐĞŽĨƚĞƐƚŝŶŐtZ^s ƚƚĂĐŚŵĞŶƚƐ͗ ϭ͘ tĞůů^ĐŚĞŵĂƚŝĐƵƌƌĞŶƚ Ϯ͘ tĞůů^ĐŚĞŵĂƚŝĐWƌŽƉŽƐĞĚ ϯ͘ tĞůůŚĞĂĚ^ĐŚĞŵĂƚŝĐ ϰ͘ EϮWƌŽĐĞĚƵƌĞ ϱ͘ ϳ͟KWĚƌĂǁŝŶŐ ϲ͘ ŽŝůKWƌĂǁŝŶŐ ϳ͘ Žŝů&ůƵŝĚ&ůŽǁŝĂŐƌĂŵƐ ϴ͘ ^ƵŶĚƌǇZĞǀŝƐŝŽŶŚĂŶŐĞ&Žƌŵ ďŽǀĞƉĞƌĨƐǁŝůůďĞƐŚŽƚŝŶƚŚĞEŽƌƚŚŽŽŬ/ŶůĞƚ͕dĞƌƚŝĂƌǇ'ĂƐWŽŽů͘ 3HUIRUP 0,7,$ DIWHU UHWXUQLQJ WR SURGXFWLRQ ZLWKLQ GD\V EMP $JUHH6)' BBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBB hƉĚĂƚĞĚďǇDϬϰͲϭϭͲϮϮ ^,Dd/ EŽƌƚŚŽŽŬ/ŶůĞƚ tĞůů͗E/Ͳϭϰ >ĂƐƚŽŵƉůĞƚĞĚ͗ϬϰͬϮϯͬϮϬϬϵ Wd͗ϮϬϴͲϬϵϲ W/͗ϱϬͲϴϴϯͲϮϬϭϮϱͲϬϬͲϬϬ ^/E'd/> ^ŝǌĞ tƚ 'ƌĂĚĞ ŽŶŶ /dŽƉ ƚŵ ϯϬ͟ϭϮϬ͘ϬϬ yͲϱϲ Ϯϳ͘ϬϬϬ ^ƵƌĨ ϰϬϬ͛ ϵͲϱͬϴ͟ϰϬ͘ϬϬ >ͲϴϬ dD ϴ͘ϴϯϱ ^ƵƌĨ ϰ͕ϳϰϳ͛ ϳ͟Ϯϲ͘ϬϬ >ͲϴϬ dD ϲ͘Ϯϳϱ ^ƵƌĨ ϵ͕ϵϴϮ͛ dh/E'd/> ϰͲϭͬϮ͟ϭϮ͘ϲϬ >ͲϴϬ /dD ϯ͘ϵϱϴ ^ƵƌĨ ϳ͕ϬϱϮ͛ :t>Zzd/> EŽ ĞƉƚŚ ;DͿ ĞƉƚŚ ;dsͿ / K /ƚĞŵ ϮϯΖ ϮϯΖ ϯ͘ϵϬϬ dƵďŝŶŐ,ĂŶŐĞƌͲ sĞƚĐŽ ϭ ϰϳϮΖ ϰϳϮΖ ϯ͘ϴϭϯ ^>Wϲŝ>ĂŶĚŝŶŐEŝƉƉůĞ Ϯ ϭ͕ϳϴϵΖ ϭ͕ϳϱϰΖ ϭ͘ϬϬϬ ĂŵĐŽ<'ͲϮͲϭZ'>s ;ƵŵŵǇͿ ϯ͕ϰϴϱΖ Ϯ͕ϳϵϴΖ ϭ͘ϬϬϬ ĂŵĐŽ<'ͲϮͲϭZ'>s ;ƵŵŵǇͿ ϰ͕ϵϰϵΖ ϯ͕ϱϵϵΖ ϭ͘ϬϬϬ ĂŵĐŽ<'ͲϮͲϭZ'>s ;ƵŵŵǇͿ ϲ͕ϬϮϰΖ ϰ͕ϭϵϮΖ ϭ͘ϬϬϬ ĂŵĐŽ<'ͲϮͲϭZ'>s ;ƵŵŵǇͿ ϲ͕ϳϱϮΖ ϰ͕ϱϵϮΖ ϭ͘ϬϬϬ ĂŵĐŽ<'ͲϮͲϭZ'>s ;ƵŵŵǇͿ ϲ͕ϴϯϵΖ ϰ͕ϲϰϬΖ Ϯ͘ϯϳϱ ϭ͘ϬϬϬ ĂŵĐŽ<'ͲϮͲϭZ'>s ;KƌŝĨŝĐĞͿ ϯ ϲ͕ϵϮϲΖ ϰ͕ϲϴϳΖ ϯ͘ϴϭϯ yEŝƉƉůĞ ϰ ϳ͕ϬϬϴΖ ϰ͕ϳϯϮΖ ϯ͘ϴϴϬ >ŽĐĂƚŽƌ ϳ͕ϬϭϭΖ ϰ͕ϳϯϰΖ ϰ͘ϳϱϬ ŶĐŚŽƌWZ ϳ͕ϬϯϵΖ ϰ͕ϳϱϬΖ ϰ͘ϬϬϬ ϯ͘ϰϯϬ 'ƌĂǀĞůWĂĐŬĞƌ;ĂŬĞƌ^ͲϮͿ ϳ͕ϬϰϬΖ ϰ͕ϳϱϬΖ ϯ͘ϮϲϬ ^ĞĂůƐƐǇ;^ĞĂůhŶŝƚϴϮͲϰϬͿ ϳ͕ϬϰϳΖ ϰ͕ϳϱϰΖ ϰ͘ϬϬϬ ^ĞĂůŽƌĞǆƚĞŶƐŝŽŶ ϳ͕ϬϱϭΖ ϰ͕ϳϱϲΖ ϯ͘ϮϲϬ t>' ϳ͕ϬϲϮΖ ϰ͕ϳϲϮΖ ϭ͘ϯϬϬ ǆƚĞŶƐŝŽŶ^Ƶď ϳ͕ϬϲϲΖ ϰ͕ϳϲϰΖ ϰ͘ϯϮϬ ǆƚĞŶƐŝŽŶ^Ƶď ϱ ϳ͕ϬϳϭΖ ϰ͕ϳϲϳΖ ϯ͘ϯϰϬ <K/s ϲ ϳ͕ϬϳϰΖ ϰ͕ϳϲϵΖ ϯ͘ϯϭϬ <K/s ϳ͕ϬϳϳΖ ϰ͕ϳϳϭΖ ϯ͘ϰϯϬ ^ŚĞĂƌKƵƚ^ĂĨĞƚǇ:ƚ ϳ ϳ͕ϭϱϯΖ ϰ͕ϴϭϯΖ ϯ͘ϰϯϬ ǆĐůƵĚĞƌ^ĐƌĞĞŶϮϬϬϬ ϴ ϳ͕ϰϭϵΖ ϰ͕ϵϲϬΖ ϯ͘ϰϯϬ ǆĐůƵĚĞƌ^ĐƌĞĞŶϮϬϬϬ ϵ ϳ͕ϳϰϰΖ ϱ͕ϭϯϳΖ ϯ͘ϰϯϬ ǆĐůƵĚĞƌ^ĐƌĞĞŶϮϬϬϬ ϭϬ ϳ͕ϴϵϮΖ ϱ͕ϮϭϴΖ ϯ͘ϰϯϬ ǆĐůƵĚĞƌ^ĐƌĞĞŶϮϬϬϬ ϭϭ ϴ͕ϬϰϬΖ ϱ͕ϮϵϴΖ ϯ͘ϰϯϬ ǆĐůƵĚĞƌ^ĐƌĞĞŶϮϬϬϬ ϭϮ ϴ͕ϮϯϳΖ ϱ͕ϰϬϵΖ ϯ͘ϮϲϬ ^ŶĂƉ>ĂƚĐŚϴϮͲϰϬ^ϮϮ ϴ͕ϮϯϴΖ ϱ͕ϰϬϵΖ ϯ͘ϮϲϬ ^ĞĂůhŶŝƚ;ϴϮͲϰϬϵϬ,Ϳ ϴ͕ϮϯϴΖ ϱ͕ϰϬϵΖ ϰ͘ϬϬϬ Ϯ͘ϵϵϮ WĂĐŬĞƌ;^ƵŵƉDŽĚĞů&^Ϳ ϴ͕ϮϰϭΖ ϱ͕ϰϭϭΖ ϯ͘ϮϲϬ ϭͬϮDƵůĞ^ŚŽĞ ϴ͕ϮϰϰΖ ϱ͕ϰϭϯΖ ϯ͘ϬϬϬ ƌŽƐƐŽǀĞƌϱ͘ϱΗǆϯ͘ϱΗ ϭϯ ϴ͕ϱϲϯΖ ϱ͕ϲϬϰΖ ϯ͘ϬϭϬ t>' ϭϰ ϵ͕ϰϰϭΖ ϲ͕ϭϲϳΖ Ϭ͘ϬϬϬ /W ϭϱ ϵ͕ϴϬϭΖ ϲ͕ϯϵϭΖ Ϭ͘ϬϬϬ ^ĂŶĚWůƵŐ;͍ĂƚĞ^ĞƚͿ '*/3DFNHU$VVHPEO\ 1R 'HSWK 0' 'HSWK 79',' 2' ,WHP $ ϲ͕ϴϬϵΖ ϰ͕ϲϮϯΖ Ϯ͘ϯϳϱ ϯϳϰtĞĂƚŚĞƌĨŽƌĚtŝĚĞƉĂĐŬhƉƉĞƌWĂĐŬĞƌ ϲ͕ϴϭϱΖ ϰ͕ϲϮϳΖ Ϯ͘ϵϵϮ ϯ͘ϱϬΗ͕ϵ͘ϮηWƵƉ:ƚ;ϮͿͲ ϯ͘ϱηsD&:>ŽǆyWŝŶ ϲ͕ϴϯϰΖ ϰ͕ϲϯϳΖ Ϯ͘ϮϰϬ tWŶĐŚŽƌ^ĞĂů>ĂƚĐŚ ϲ͕ϴϯϴΖ ϰ͕ϲϯϵΖ Ϭ͘ϳϵϬ ƵĂů&ůĂƉƉĞƌŚĞĐŬsĂůǀĞ ϲ͕ϴϯϴΖ ϰ͕ϲϯϵΖ Ϭ͘ϴϳϱ ^ƚŝŶŐĞƌZŽĚǁͬ&s ϲ͕ϴϰϱΖ ϰ͕ϲϰϯΖ Ϯ͘ϯϳϱ ϯϳϰtĞĂƚŚĞƌĨŽƌĚtŝĚĞƉĂĐŬhƉƉĞƌWĂĐŬĞƌ ϲ͕ϴϱϮΖ ϰ͕ϲϰϳΖ ϭ͘ϳϱϬ WZͲ ^ĞĂůďŽƌĞ ϲ͕ϴϱϯΖ ϰ͕ϲϰϴΖ ϭ͘ϳϭϬ ZEŝƉƉůĞ ϲ͕ϴϱϰΖ ϰ͕ϲϴϭΖ ϭ͘ϯϳϱ dŽƌƋͲdŚƌƵYƵŝĐŬŽŶŶĞĐƚ ϲ͕ϴϱϳΖ ϰ͕ϲϱϬΖ ϭ͘ϱϬϬ ϭ͘ϵϬϬ͕ϯ͘ϲϰη^Ͳ,ǇĚƌŝůũŽŝŶƚĞĚƉŝƉĞ ;ϮϬũƚƐͿϭ͘ϱΗ td^ͲϴŽǆyWŝŶ ϳ͕ϰϴϳ͛ ϰ͕ϵϵϴ͛ ϭ͘ϰϭϬ ϭ͘ϵϬϬ/:͕Ϯ͘ϳϱηũŽŝŶƚĞĚƉŝƉĞ;ϮϰũƚƐͿϭ͘ϵϬϬ/:ďŽǆy ƉŝŶ ϴ͕Ϯϲϰ͛ϱ͕ϰϮϰ͛/ŶũĞĐƚŝŽŶƐƵď BBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBB hƉĚĂƚĞĚďǇDϬϰͲϭϭͲϮϮ EŽƌƚŚŽŽŬ/ŶůĞƚ tĞůů͗E/Ͳϭϰ >ĂƐƚŽŵƉůĞƚĞĚ͗ϬϰͬϮϯͬϮϬϬϵ Wd͗ϮϬϴͲϬϵϲ W/͗ϱϬͲϴϴϯͲϮϬϭϮϱͲϬϬͲϬϬ ^,Dd/ WĞƌĨŽƌĂƚŝŽŶĂƚĂ ŽŶĞdŽƉ;DͿƚŵ;DͿdŽƉ;dsͿƚŵ;dsͿ&dĂƚĞ^ƚĂƚƵƐ ĞůƵŐĂϳ͕ϭϲϭΖϳ͕ϭϳϯΖϰ͕ϴϭϳΖϰ͕ϴϮϰΖϭϮΖϰͬϭϱͬϮϬϬϵKƉĞŶ ĞůƵŐĂϳ͕ϮϮϬΖϳ͕ϮϱϵΖϰ͕ϴϱϬΖϰ͕ϴϳϮΖϯϵΖϰͬϭϱͬϮϬϬϵKƉĞŶ ĞůƵŐĂϳ͕ϮϳϲΖϳ͕ϮϴϯΖϰ͕ϴϴϭΖϰ͕ϴϴϱΖϳΖϰͬϭϱͬϮϬϬϵKƉĞŶ ĞůƵŐĂϳ͕ϱϱϯΖϳ͕ϲϬϴΖϱ͕ϬϯϯΖϱ͕ϬϲϯΖϱϱΖϰͬϭϱͬϮϬϬϵKƉĞŶ ĞůƵŐĂϳ͕ϲϯϵΖϳ͕ϲϲϰΖϱ͕ϬϴϬΖϱ͕ϬϵϯΖϮϱΖϰͬϭϱͬϮϬϬϵKƉĞŶ ĞůƵŐĂϳ͕ϴϬϳΖϳ͕ϴϮϳΖϱ͕ϭϳϭΖϱ͕ϭϴϮΖϮϬΖϰͬϭϱͬϮϬϬϵKƉĞŶ ĞůƵŐĂ&ϳ͕ϵϯϳΖϳ͕ϵϰϱΖϱ͕ϮϰϮΖϱ͕ϮϰϳΖϴΖϰͬϭϱͬϮϬϬϵKƉĞŶ ĞůƵŐĂ&ϳ͕ϵϵϱΖϴ͕ϬϬϱΖϱ͕ϮϳϰΖϱ͕ϮϳϵΖϭϬΖϰͬϭϱͬϮϬϬϵKƉĞŶ ĞůƵŐĂ'ϴ͕ϬϲϴΖϴ͕ϬϴϯΖϱ͕ϯϭϰΖϱ͕ϯϮϮΖϭϱΖϰͬϭϱͬϮϬϬϵKƉĞŶ ĞůƵŐĂ'ϴ͕ϭϵϴΖϴ͕ϮϮϴΖϱ͕ϯϴϲΖϱ͕ϰϬϰΖϯϬΖϰͬϭϱͬϮϬϬϵKƉĞŶ ĞůƵŐĂ'ϴ͕ϮϭϰΖϴ͕ϮϰϲΖϱ͕ϯϵϱΖϱ͕ϰϭϰΖϯϮΖϰͬϵͬϮϬϬϵKƉĞŶ ĞůƵŐĂDϵ͕ϬϮϯΖϵ͕ϬϰϬΖϱ͕ϵϬϮΖϱ͕ϵϭϯΖϭϳΖϰͬϴͬϮϬϬϵKƉĞŶ ĞůƵŐĂYϵ͕ϲϬϰΖϵ͕ϲϮϰΖϲ͕ϮϳϬΖϲ͕ϮϴϮΖϮϬΖϰͬϴͬϮϬϬϵKƉĞŶ BBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBB hƉĚĂƚĞĚǇ͗DϰͬϭϭͬϮϮ WZKWK^ EŽƌƚŚŽŽŬ/ŶůĞƚ tĞůů͗E/Ͳϭϰ >ĂƐƚŽŵƉůĞƚĞĚ͗ϬϰͬϮϯͬϮϬϬϵ Wd͗ϮϬϴͲϬϵϲ W/͗ϱϬͲϴϴϯͲϮϬϭϮϱͲϬϬͲϬϬ Wd͗ϵ͕ϰϰϭ͛ d͗ ϭϭ͕ϱϬϭ͛ ´ ĞůƵŐĂ ´ ´ dKΛϰ͕ϳϰϳ͛ h^/dϮϬϬϴ ĞůƵŐĂ ĞůƵŐĂ ĞůƵŐĂ ĞůƵŐĂ& ĞůƵŐĂ' ĞůƵŐĂD ĞůƵŐĂY ĞůƵŐĂ ; ^/E'd/> ^ŝǌĞ tƚ 'ƌĂĚĞ ŽŶŶ / dŽƉ ƚŵ ϯϬ͟ ϭϮϬ͘ϬϬ yͲϱϲ Ϯϳ͘ϬϬϬ ^ƵƌĨ ϰϬϬ͛ ϵͲϱͬϴ͟ ϰϬ͘ϬϬ >ͲϴϬ dD ϴ͘ϴϯϱ ^ƵƌĨ ϰ͕ϳϰϳ͛ ϳ͟ Ϯϲ͘ϬϬ >ͲϴϬ dD ϲ͘Ϯϳϱ ^ƵƌĨ ϵ͕ϵϴϮ͛ dh/E'd/> ϰͲϭͬϮ͟ ϭϮ͘ϲϬ >ͲϴϬ /dD ϯ͘ϵϱϴ ^ƵƌĨ ϳ͕ϬϱϮ͛ :t>Zzd/> EŽ ĞƉƚŚ ;DͿ ĞƉƚŚ ;dsͿ / K /ƚĞŵ ϮϯΖ ϮϯΖ ϯ͘ϵϬϬ dƵďŝŶŐ,ĂŶŐĞƌͲsĞƚĐŽ ϭ ϰϳϮΖ ϰϳϮΖ ϯ͘ϴϭϯ ^>Wϲŝ>ĂŶĚŝŶŐEŝƉƉůĞ Ϯ ϭ͕ϳϴϵΖ ϭ͕ϳϱϰΖ ϭ͘ϬϬϬ ĂŵĐŽ<'ͲϮͲϭZ'>s;ƵŵŵǇͿ ϯ͕ϰϴϱΖ Ϯ͕ϳϵϴΖ ϭ͘ϬϬϬ ĂŵĐŽ<'ͲϮͲϭZ'>s;ƵŵŵǇͿ ϰ͕ϵϰϵΖ ϯ͕ϱϵϵΖ ϭ͘ϬϬϬ ĂŵĐŽ<'ͲϮͲϭZ'>s ;ƵŵŵǇͿ ϲ͕ϬϮϰΖ ϰ͕ϭϵϮΖ ϭ͘ϬϬϬ ĂŵĐŽ<'ͲϮͲϭZ'>s;ƵŵŵǇͿ ϲ͕ϳϱϮΖ ϰ͕ϱϵϮΖ ϭ͘ϬϬϬ ĂŵĐŽ<'ͲϮͲϭZ'>s;ƵŵŵǇͿ ϲ͕ϴϯϵΖ ϰ͕ϲϰϬΖ Ϯ͘ϯϳϱ ϭ͘ϬϬϬ ĂŵĐŽ<'ͲϮͲϭZ'>s ;ƵŵŵǇͿ ϯ ϲ͕ϵϮϲΖ ϰ͕ϲϴϳΖ ϯ͘ϴϭϯ yEŝƉƉůĞ ϰ ϳ͕ϬϬϴΖ ϰ͕ϳϯϮΖ ϯ͘ϴϴϬ >ŽĐĂƚŽƌ ϳ͕ϬϭϭΖ ϰ͕ϳϯϰΖ ϰ͘ϳϱϬ ŶĐŚŽƌWZ ϳ͕ϬϯϵΖ ϰ͕ϳϱϬΖ ϰ͘ϬϬϬ ϯ͘ϰϯϬ 'ƌĂǀĞůWĂĐŬĞƌ;ĂŬĞƌ^ͲϮͿ ϳ͕ϬϰϬΖ ϰ͕ϳϱϬΖ ϯ͘ϮϲϬ ^ĞĂůƐƐǇ;^ĞĂůhŶŝƚϴϮͲϰϬͿ ϳ͕ϬϰϳΖ ϰ͕ϳϱϰΖ ϰ͘ϬϬϬ ^ĞĂůŽƌĞǆƚĞŶƐŝŽŶ ϳ͕ϬϱϭΖ ϰ͕ϳϱϲΖ ϯ͘ϮϲϬ t>' ϳ͕ϬϲϮΖ ϰ͕ϳϲϮΖ ϭ͘ϯϬϬ ǆƚĞŶƐŝŽŶ^Ƶď ϳ͕ϬϲϲΖ ϰ͕ϳϲϰΖ ϰ͘ϯϮϬ ǆƚĞŶƐŝŽŶ^Ƶď ϳ͕ϬϳϳΖ ϰ͕ϳϳϭΖ ϯ͘ϰϯϬ ^ŚĞĂƌKƵƚ^ĂĨĞƚǇ:ƚ ϳ ϳ͕ϭϱϯΖ ϰ͕ϴϭϯΖ ϯ͘ϰϯϬ ǆĐůƵĚĞƌ^ĐƌĞĞŶϮϬϬϬ ϴ ϳ͕ϰϭϵΖ ϰ͕ϵϲϬΖ ϯ͘ϰϯϬ ǆĐůƵĚĞƌ^ĐƌĞĞŶϮϬϬϬ ϵ ϳ͕ϳϰϰΖ ϱ͕ϭϯϳΖ ϯ͘ϰϯϬ ǆĐůƵĚĞƌ^ĐƌĞĞŶϮϬϬϬ ϭϬ ϳ͕ϴϵϮΖ ϱ͕ϮϭϴΖ ϯ͘ϰϯϬ ǆĐůƵĚĞƌ^ĐƌĞĞŶϮϬϬϬ ϭϭ ϴ͕ϬϰϬΖ ϱ͕ϮϵϴΖ ϯ͘ϰϯϬ ǆĐůƵĚĞƌ^ĐƌĞĞŶϮϬϬϬ ϭϮ ϴ͕ϮϯϳΖ ϱ͕ϰϬϵΖ ϯ͘ϮϲϬ ^ŶĂƉ>ĂƚĐŚϴϮͲϰϬ^ϮϮ ϴ͕ϮϯϴΖ ϱ͕ϰϬϵΖ ϯ͘ϮϲϬ ^ĞĂůhŶŝƚ;ϴϮͲϰϬϵϬ,Ϳ ϴ͕ϮϯϴΖ ϱ͕ϰϬϵΖ ϰ͘ϬϬϬ Ϯ͘ϵϵϮ WĂĐŬĞƌ;^ƵŵƉDŽĚĞů&^Ϳ ϴ͕ϮϰϭΖ ϱ͕ϰϭϭΖ ϯ͘ϮϲϬ ϭͬϮDƵůĞ^ŚŽĞ ϴ͕ϮϰϰΖ ϱ͕ϰϭϯΖ ϯ͘ϬϬϬ ƌŽƐƐŽǀĞƌϱ͘ϱΗǆϯ͘ϱΗ ϭϯ ϴ͕ϱϲϯΖ ϱ͕ϲϬϰΖ ϯ͘ϬϭϬ t>' ϭϰ ϵ͕ϰϰϭΖ ϲ͕ϭϲϳΖ Ϭ͘ϬϬϬ /W ϭϱ ϵ͕ϴϬϭΖ ϲ͕ϯϵϭΖ Ϭ͘ϬϬϬ ^ĂŶĚWůƵŐ;͍ĂƚĞ^ĞƚͿ BBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBB hƉĚĂƚĞĚďǇDϬϰͲϭϭͲϮϮ EŽƌƚŚŽŽŬ/ŶůĞƚ tĞůů͗E/Ͳϭϰ >ĂƐƚŽŵƉůĞƚĞĚ͗ϬϰͬϮϯͬϮϬϬϵ Wd͗ϮϬϴͲϬϵϲ W/͗ϱϬͲϴϴϯͲϮϬϭϮϱͲϬϬͲϬϬ ^,Dd/ WĞƌĨŽƌĂƚŝŽŶĂƚĂ ŽŶĞ dŽƉ;DͿ ƚŵ;DͿ dŽƉ;dsͿ ƚŵ;dsͿ &d ĂƚĞ ^ƚĂƚƵƐ ĞůƵŐĂhƉƉĞƌ цϲ͕ϳϱϬ͛цϲ͕ϳϲϯ͛цϰ͕ϱϵϭ͛цϰ͕ϱϵϴ͛ϭϯ͛WƌŽƉŽƐĞĚ d ĞůƵŐĂ>ŽǁĞƌ цϲ͕ϴϯϵ͛цϲ͕ϴϲϵ͛цϰ͕ϲϰϬ͛цϰ͕ϲϱϲ͛ϯϬ͛WƌŽƉŽƐĞĚ d ĞůƵŐĂhƉƉĞƌϭ цϲ͕ϵϬϵ͛цϲ͕ϵϭϴ͛цϰ͕ϲϳϴ͛цϰ͕ϲϴϯ͛ϵ͛WƌŽƉŽƐĞĚ d ĞůƵŐĂhƉƉĞƌϮ цϲ͕ϵϯϴ͛цϲ͕ϵϱϰ͛цϰ͕ϲϵϰ͛цϰϲϰϴ͛ϭϲ͛WƌŽƉŽƐĞĚ d ĞůƵŐĂhƉƉĞƌϯ цϲ͕ϵϲϵ͛цϲ͕ϵϴϵ͛цϰ͕ϳϭϭ͛цϰ͕ϳϮϮ͛ϮϬ͛WƌŽƉŽƐĞĚ d ĞůƵŐĂ ϳ͕ϭϲϭΖ ϳ͕ϭϳϯΖ ϰ͕ϴϭϳΖ ϰ͕ϴϮϰΖ ϭϮΖ ϰͬϭϱͬϮϬϬϵ KƉĞŶ ĞůƵŐĂ>ŽǁĞƌ цϳ͕ϭϲϭ͛цϳ͕ϭϳϯ͛цϰ͕ϴϭϳΖ цϰ͕ϴϮϰΖ ϭϮ͛WƌŽƉŽƐĞĚ d ĞůƵŐĂ ϳ͕ϮϮϬΖ ϳ͕ϮϱϵΖ ϰ͕ϴϱϬΖ ϰ͕ϴϳϮΖ ϯϵΖ ϰͬϭϱͬϮϬϬϵ KƉĞŶ ĞůƵŐĂhƉƉĞƌ цϳ͕ϮϮϬ͛цϳ͕Ϯϱϵ͛цϰ͕ϴϱϬΖ цϰ͕ϴϳϮΖ ϯϵ͛WƌŽƉŽƐĞĚ d ĞůƵŐĂ ϳ͕ϮϳϲΖ ϳ͕ϮϴϯΖ ϰ͕ϴϴϭΖ ϰ͕ϴϴϱΖ ϳΖ ϰͬϭϱͬϮϬϬϵ KƉĞŶ ĞůƵŐĂDŝĚ цϳ͕Ϯϳϲ͛цϳ͕Ϯϴϯ͛цϰ͕ϴϴϭΖ цϰ͕ϴϴϱΖ ϳ͛WƌŽƉŽƐĞĚ d ĞůƵŐĂ>ŽǁĞƌ цϳ͕ϯϭϯ͛цϳ͕ϯϭϴ͛цϰ͕ϵϬϮ͛ц͕ϰϵϬϰ͛ϱ͛WƌŽƉŽƐĞĚ d ĞůƵŐĂDŝĚ цϳ͕ϰϳϭ͛цϳ͕ϰϴϱ͛цϰ͕ϵϴϵ͛цϰ͕ϵϵϲ͛ϭϰ͛WƌŽƉŽƐĞĚ d ĞůƵŐĂ ϳ͕ϱϱϯΖ ϳ͕ϲϬϴΖ ϱ͕ϬϯϯΖ ϱ͕ϬϲϯΖ ϱϱΖ ϰͬϭϱͬϮϬϬϵ KƉĞŶ 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Type of Request: Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown Suspend Perforate Other Stimulate Pull Tubing Change Approved Program Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing 2.Operator Name:4.Current Well Class:5.Permit to Drill Number: Exploratory Development 3.Address: 3800 Centerpoint Drive, Suite 1400 Stratigraphic Service 6.API Number: 7. If perforating:8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require a spacing exception?Yes No 9.Property Designation (Lease Number):10.Field/Pool(s): North Cook Inlet Field / Tertiary Gas Pool 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi):Plugs (MD):Junk (MD): 11,501'N/A Casing Collapse Structural Conductor Surface 3,090 psi Intermediate Production 5,410 psi Liner Packers and SSSV Type:Packers and SSSV MD (ft) and TVD (ft): 12. Attachments: Proposal Summary Wellbore schematic 13.Well Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations:OIL WINJ WDSPL Suspended 16.Verbal Approval:Date:GAS WAG GSTOR SPLUG Commission Representative: GINJ Op Shutdown Abandoned Contact Name: Contact Email:Katherine.oconnor@hilcorp.com Contact Phone: (907) 777-8376 Date: Conditions of approval: Notify Commission so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other: Post Initial Injection MIT Req'd? Yes No Spacing Exception Required? Yes No Subsequent Form Required: APPROVED BY Approved by:COMMISSIONER THE COMMISSION Date: Comm.Comm.Sr Pet Eng Sr Pet Geo Sr Res Eng 7,482'9,441'6,167'977 psi 6,505'7" Authorized Title: 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. 7/10/2021 4-1/2" Daniel E. Marlowe See Schematic 7,161 - 9,624 9,982' See Schematic Tubing Grade:Tubing MD (ft): 4,817 - 6,282 Perforation Depth TVD (ft): 4,747' 9,982' Perforation Depth MD (ft): 400' 4,747' 30" 9-5/8" 400' CO 68A 12.6 / L-80 TVD Burst 7,052' 7,240 psi Tubing Size: MD STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0017589 / ADL0037831 208-096 50-883-20125-00-00Anchorage, AK 99503 Hilcorp Alaska, LLC N Cook Inlet Unit A-14 COMMISSION USE ONLY Authorized Name: 5,750 psi 400' 3,486' Other: Pull DGL Authorized Signature: Operations Manager Katherine O'Connor PRESENT WELL CONDITION SUMMARY Length Size 9,441 & 9,801 Form 10-403 Revised 3/2020 Approved application is valid for 12 months from the date of approval. By Samantha Carlisle at 2:23 pm, Jun 10, 2021 321-286 Digitally signed by Dan Marlowe (1267) DN: cn=Dan Marlowe (1267), ou=Users Date: 2021.06.10 13:16:42 -08'00' Dan Marlowe (1267) 10-404 DSR-6/10/21 Perform kick while tripping drill for making up Safety joint and shutting in the well prior to pulling the tubing. The drill should simulate the crews ability to BJM 6/16/21 Standing orders must be posted on location and the roles and responsibilities for shutting in the well must be understood by the crews. AOGCC inspectors will test crew's understanding during BOP test. BOP test to 2500 psi. recognize that the well is flowing, pick up the safety joint and shut in the well. X SFD 6/15/2021 dts 6/16/2021 JLC 6/16/2021 Jeremy Price Digitally signed by Jeremy Price Date: 2021.06.16 15:43:17 -08'00' RBDMS HEW 6/17/2021 Well Work Prognosis Well Name:NCIU A-14 API Number: 50-883-20125-00-00 Current Status:SI Producer Leg:Leg #2 Estimated Start Date:7/10/2021 Rig: Reg. Approval Req’d?403 Date Reg. Approval Rec’vd: Regulatory Contact:Juanita Lovett (8332)Permit to Drill Number:208-096 First Call Engineer:Katherine O’Connor (907) 777-8376 (O) (214) 684-7400 (M) Second Call Engineer:Karson Kozub (907) 777-8434 (O) (907) 570-1801 (M) Current Bottom Hole Pressure: 751 psi @ 5549’TVD Maximum Expected BHP:1085 psi @ 4720’ TVD 0.433 psi/ft gradient to surface Maximum Potential Surface Pressure: 977 psi Using 0.1 psi/ft gradient 20 AAC 25.280(b)(4) Brief Well Summary The NCIU A-14 well was drilled and completed in 1969 as a Beluga and Cook Inlet sands producer. In 2012 a Deep Gas Lift string was installed. It was pulled and reinstalled in 2015. The well’s productivity has declined significantly. It is proposed to pull the Deep Gas Lift string and add perforations into the Beluga C/D/E/F sands. Plan is to leave out the deep gas lift string as it is believed to be a choke point in the well currently. Wellbore Notes: x Slickline will pull SSSV ahead of time x Slickline will drift & bail as necessary prior to pulling DGL Procedure: 1. MIRU work platform 1. R/U accumulator, pumps, batch mixer, choke, etc 2. Bullhead to kill the well. 1. Monitor well to ensure it is static. 2. Fluid will be KCl 3. NU BOPE’s on top of tree 4. Test BOP’s to 250psi /2,500psi. (Note: Notify AOGCC 48 hours in advance of test to allow them to witness test). 5. R/U Slickline/Braided line P/T lubricator to 250 low/1500 psi high. 1. RIH lubricated and latch deep gas lift upper packer & spacer pipe/jewelry, POOH 2. LD upper packer & spacer pipe/jewelry. 3. RBIH and latch deep gas lift lower packer and 1.900” pipe w/ jewelry, POOH 4. Support 1.900” pipe with slips and lay down lower packer 5. Latch the 1.900” pipe with the crane and L/D all 44 joints w/ jewelry 6. MITU EL P/T lubricator to 250 low/1500 psi high 1. Add perfs per procedure 7. Turn over to production. 8. Schedule SVS testing with AOGCC as per regulations Attachments: 1. Well Schematic Current 2. Well Schematic Proposed 3. Wellhead Schematic Proposed 4. BOP Drawing 5. Fluid Flow Diagrams 6. Sundry Revision Change Form 5.1.a. and 5.3.a. Fill hole and ensure well is static before removing SL lubricator and laying down pipe. bjm ____________________________________________________________________________________ Updated By: JLL 04/19/21 SCHEMATIC North Cook Inlet Well:NCI A-14 Last Completed: 04/23/2009 PTD: 208-096 API: 50-883-20125-00 PBTD: 9,441’ TD:11,501’ A 7” 3 4 5 6 7 8 9 10 11 13 Beluga B 9-5/8” 30” 14 15 1 2 Beluga C Beluga D Beluga E Beluga F Beluga G Beluga M Beluga Q 12 X CASING DETAIL Size Wt Grade Conn ID Top Btm 30” 120.00 X-56 27.000 Surf 400’ 9-5/8” 40.00 L-80 BTCM 8.835 Surf 4,747’ 7” 26.00 L-80 BTCM 6.275 Surf 9,982’ TUBING DETAIL 4-1/2” 12.60 L-80 IBTM 3.958 Surf 7,052’ JEWELRY DETAIL No Depth (MD) Depth (TVD)ID OD Item 23' 23' 3.900 Tubing Hanger - Vetco 1 472' 472' 3.813 SLB BP6i Landing Nipple 2 1,789' 1,754' 1.000 Camco KBG-2-1R GLV (Dummy) 3,485' 2,798' 1.000 Camco KBG-2-1R GLV (Dummy) 4,949' 3,599' 1.000 Camco KBG-2-1R GLV (Dummy) 6,024' 4,192' 1.000 Camco KBG-2-1R GLV (Dummy) 6,752' 4,592' 1.000 Camco KBG-2-1R GLV (Dummy) 6,839' 4,640' 2.375 1.000 Camco KBG-2-1R GLV (Orifice) 3 6,926' 4,687' 3.813 X Nipple 4 7,008' 4,732' 3.880 Locator 7,011' 4,734' 4.750 Anchor PBR 7,039' 4,750' 4.000 3.430 Gravel Packer (Baker SC-2) 7,040' 4,750' 3.260 Seal Assy (Seal Unit 82-40) 7,047' 4,754' 4.000 Seal Bore Extension 7,051' 4,756' 3.260 WLEG 7,062' 4,762' 1.300 Extension Sub 7,066' 4,764' 4.320 Extension Sub 5 7,071' 4,767' 3.340 KOIV 6 7,074' 4,769' 3.310 KOIV 7,077' 4,771' 3.430 Shear Out Safety Jt 7 7,153' 4,813' 3.430 Excluder Screen 2000 8 7,419' 4,960' 3.430 Excluder Screen 2000 9 7,744' 5,137' 3.430 Excluder Screen 2000 10 7,892' 5,218' 3.430 Excluder Screen 2000 11 8,040' 5,298' 3.430 Excluder Screen 2000 12 8,237' 5,409' 3.260 Snap Latch 82-40 S22B 8,238' 5,409' 3.260 Seal Unit (82-40 90H) 8,238' 5,409' 4.000 2.992 Packer (Sump Model FS) 8,241' 5,411' 3.260 1/2 Mule Shoe 8,244' 5,413' 3.000 Crossover 5.5"x3.5" 13 8,563' 5,604' 3.010 WLEG 14 9,441' 6,167' 0.000 CIBP 15 9,801' 6,391' 0.000 Sand Plug (? Date Set) DGL Packer Assembly No Depth MD Depth TVD ID OD Item A 6,809' 4,623' 2.375 374 Weatherford Widepack Upper Packer 6,815' 4,627' 2.992 3.50", 9.2# Pup Jt (2) - 3.5# VAM FJL Box X Pin 6,834' 4,637' 2.240 WP Anchor Seal Latch 6,838' 4,639' 0.790 Dual Flapper Check Valve 6,838' 4,639' 0.875 Stinger Rod w/DFCV 6,845' 4,643' 2.375 374 Weatherford Widepack Upper Packer 6,852' 4,647' 1.750 PBR - Seal bore 6,853' 4,648' 1.710 R Nipple 6,854' 4,681' 1.375 Torq-Thru Quick Connect 6,857' 4,650' 1.500 1.900, 3.64# CS-Hydril jointed pipe (20 jts) 1.5" WTS-8 Box X Pin 7,487’ 4,998’ 1.410 1.900 IJ, 2.75# jointed pipe (24 jts) 1.900 IJ box X pin 8,264’ 5,424’ Injection sub ____________________________________________________________________________________ Updated By: JLL 04/19/21 North Cook Inlet Well:NCI A-14 Last Completed: 04/23/2009 PTD: 208-096 API: 50-883-20125-00 SCHEMATIC Perforation Data Zone Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT Date Status Beluga B 7,161' 7,173' 4,817' 4,824' 12' 4/15/2009 Open Beluga C 7,220' 7,259' 4,850' 4,872' 39' 4/15/2009 Open Beluga C 7,276' 7,283' 4,881' 4,885' 7' 4/15/2009 Open Beluga D 7,553' 7,608' 5,033' 5,063' 55' 4/15/2009 Open Beluga D 7,639' 7,664' 5,080' 5,093' 25' 4/15/2009 Open Beluga E 7,807' 7,827' 5,171' 5,182' 20' 4/15/2009 Open Beluga F 7,937' 7,945' 5,242' 5,247' 8' 4/15/2009 Open Beluga F 7,995' 8,005' 5,274' 5,279' 10' 4/15/2009 Open Beluga G 8,068' 8,083' 5,314' 5,322' 15' 4/15/2009 Open Beluga G 8,198' 8,228' 5,386' 5,404' 30' 4/15/2009 Open Beluga G 8,214' 8,246' 5,395' 5,414' 32' 4/9/2009 Open Beluga M 9,023' 9,040' 5,902' 5,913' 17' 4/8/2009 Open Beluga Q 9,604' 9,624' 6,270' 6,282' 20' 4/8/2009 Open ____________________________________________________________________________________ Updated By: JLL 04/20/21 PROPOSED North Cook Inlet Well:NCI A-14 Last Completed: 04/23/2009 PTD: 208-096 API: 50-883-20125-00 PBTD: 9,441’ TD:11,501’ A 7” 3 4 5 6 7 8 9 10 11 13 Beluga B 9-5/8” 30” 14 15 1 2 Beluga C Beluga D Beluga E Beluga F Beluga G Beluga M Beluga Q 12 X CASING DETAIL Size Wt Grade Conn ID Top Btm 30” 120.00 X-56 27.000 Surf 400’ 9-5/8” 40.00 L-80 BTCM 8.835 Surf 4,747’ 7” 26.00 L-80 BTCM 6.275 Surf 9,982’ TUBING DETAIL 4-1/2” 12.60 L-80 IBTM 3.958 Surf 7,052’ JEWELRY DETAIL No Depth (MD) Depth (TVD)ID OD Item 23' 23' 3.900 Tubing Hanger - Vetco 1 472' 472' 3.813 SLB BP6i Landing Nipple 2 1,789' 1,754' 1.000 Camco KBG-2-1R GLV (Dummy) 3,485' 2,798' 1.000 Camco KBG-2-1R GLV (Dummy) 4,949' 3,599' 1.000 Camco KBG-2-1R GLV (Dummy) 6,024' 4,192' 1.000 Camco KBG-2-1R GLV (Dummy) 6,752' 4,592' 1.000 Camco KBG-2-1R GLV (Dummy) 6,839' 4,640' 2.375 1.000 Camco KBG-2-1R GLV (Orifice) 3 6,926' 4,687' 3.813 X Nipple 4 7,008' 4,732' 3.880 Locator 7,011' 4,734' 4.750 Anchor PBR 7,039' 4,750' 4.000 3.430 Gravel Packer (Baker SC-2) 7,040' 4,750' 3.260 Seal Assy (Seal Unit 82-40) 7,047' 4,754' 4.000 Seal Bore Extension 7,051' 4,756' 3.260 WLEG 7,062' 4,762' 1.300 Extension Sub 7,066' 4,764' 4.320 Extension Sub 5 7,071' 4,767' 3.340 KOIV 6 7,074' 4,769' 3.310 KOIV 7,077' 4,771' 3.430 Shear Out Safety Jt 7 7,153' 4,813' 3.430 Excluder Screen 2000 8 7,419' 4,960' 3.430 Excluder Screen 2000 9 7,744' 5,137' 3.430 Excluder Screen 2000 10 7,892' 5,218' 3.430 Excluder Screen 2000 11 8,040' 5,298' 3.430 Excluder Screen 2000 12 8,237' 5,409' 3.260 Snap Latch 82-40 S22B 8,238' 5,409' 3.260 Seal Unit (82-40 90H) 8,238' 5,409' 4.000 2.992 Packer (Sump Model FS) 8,241' 5,411' 3.260 1/2 Mule Shoe 8,244' 5,413' 3.000 Crossover 5.5"x3.5" 13 8,563' 5,604' 3.010 WLEG 14 9,441' 6,167' 0.000 CIBP 15 9,801' 6,391' 0.000 Sand Plug (? Date Set) Perforation Data Zone Top (MD)Btm (MD) Top (TVD) Btm (TVD) FT Date Status Beluga B 7,161' 7,173' 4,817' 4,824' 12' 4/15/2009 Open Beluga C 7,220' 7,259' 4,850' 4,872' 39' 4/15/2009 Open Beluga C 7,276' 7,283' 4,881' 4,885' 7' 4/15/2009 Open Beluga C ±7,313’ ±7,318’ ±4,902’ ±4,904’ ±5 Future Proposed Beluga D ±7,471’ ±7,485’ ±4,989’ ±4,996’ ±14 Future Proposed Beluga D 7,553' 7,608' 5,033' 5,063' 55' 4/15/2009 Open Beluga D 7,639' 7,664' 5,080' 5,093' 25' 4/15/2009 Open Beluga E Upr ±7,675’ ±7,698’ ±5,099’ ±5,112’ ±23’ Future Proposed Beluga E Mid ±7,758’ ±7,765’ ±5,145’ ±5,148’ ±7’ Future Proposed Beluga E 7,807' 7,827' 5,171' 5,182' 20' 4/15/2009 Open Beluga F 7,937' 7,945' 5,242' 5,247' 8' 4/15/2009 Open Beluga F 7,995' 8,005' 5,274' 5,279' 10' 4/15/2009 Open Beluga F ±8,027’ ±8,036’ ±5,291’ ±5,296’ ±9 Future Proposed Beluga G 8,068' 8,083' 5,314' 5,322' 15' 4/15/2009 Open Beluga G 8,198' 8,228' 5,386' 5,404' 30' 4/15/2009 Open Beluga G 8,214' 8,246' 5,395' 5,414' 32' 4/9/2009 Open Beluga M 9,023' 9,040' 5,902' 5,913' 17' 4/8/2009 Open Beluga Q 9,604' 9,624' 6,270' 6,282' 20' 4/8/2009 Open Tyonek Platform A-14 Current 05/07/2021 Valve, Master, WKM-M, 4 1/16 5M FE, HWO, DD trim Valve, Swab, WKM-M 4 1/16 5M FE, HWO, DD trim BHTA, Otis, 4 1/16 5M FE x 9 1/2 Otis quick union top Valve, Wing, SSV, WKM-M, 4 1/16 5M FE, HWO, w/ 15'’ operator, DD trim Valve, Wing, WKM-M, 4 1/16 5M FE, HWO, DD trim Vetco Gray, MB-230 system, 11'’ 5M top 30'’ 9 5/8'’ 7'’ 4 ½’’ Tyonek Platform A-14 30 x 9 5/8 x 7 x 4 ½ Tubing hanger, Vetco-230, 11 x 4 ½ IBT susp x 4.909 MCA lift threads, 4'’ type H BPV profile, 2- CCL ports, flex neck Valve, Master, SSV, WKM-M, 4 1/16 5M FE, HWO, w/ 15'’ operator, DD trim BatchmixerFluid Pump7-1/16, 5MAnnular7-1/16, 5MTRBOPBlank1.900 PipeBlind7-1/16, 5mMud CrossFLOWBACKTANK2” 1502 pump iron line(2) 2-1/16”, 5M manual valves2-1/16”, 5M manual valve2-1/16”, 5M HCR2” 1502 Flow back lineCHOKE SKIDw/ (5) 2”, 1502 manual valves & manual chokes4-1/16”, 5M Swab valve Hilcorp Alaska, LLCHilcorp Alaska, LLCChanges to Approved Rig Work Over Sundry ProcedureSubject: Changes to Approved Sundry Procedure for Well: N Cook Inlet Unit A-14 (PTD 208-096)Sundry #: XXX-XXXAny modifications to an approved sundry will be documented and approved below. Changes to an approved sundry will be communicated to theAOGCC by the rig workover (RWO) “first call” engineer. AOGCC written approval of the change is required before implementing the change.Sec Page Date Procedure Change New 403Required?Y / NHAKPreparedBy(Initials)HAKApprovedBy(Initials)AOGCC WrittenApproval Received(Person and Date)Approval:Asset Team Operations Manager DatePrepared:First Call Operations Engineer Date 2 d °° 2_53g5 WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. February 3, 2015 Attn.: Makana Bender DATA LOGGED 333 West 7th Avenue, Suite 100 Dy,9 /2015 Anchorage, Alaska 99501 K BENDER FF B 0 6 1015 RE: Multi-Finger Caliper&Packer Setting Record: NCI A-14 Run Date: 1/7/15 & 1/9/15 a. G C The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Chris Gullett, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 NCI A-14 Digital Data (LAS), Digital Log file 1 CD Rom 50-883-20125-00 Multi-Finger Caliper&Packer Setting Record 1 Color Log, each 50-883-20125-00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE A'FIENTION OF: Halliburton Wireline & Perforating Attn: Chris Gullett SCANNED `' y t�' 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-273-3527 Fax: 907-273-3535 FRS_ANC@halliburton.com Date: Signed: li ,/ilzadza-ic./) 0 • Image Project Well History File Cover Page XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. aos - 0 g ‘:, Well History File Identifier Organizing (done) Two -sided III 11111111 III 11111 ❑ Rescan Needed 111 111111 U 11 III III R CAN DIGITAL DATA OVERSIZED (Scannable) Color Items: ❑ Diskettes, No. ❑ Maps: Ot ❑ Greyscale Items: her, No/Type: �V No. I ❑ Other Items Scannable by a Large Scanner ❑ Poor Quality Originals: OVERSIZED (Non - Scannable) ❑ Other: ❑ Logs of various kinds: NOTES: ❑ Other:: BY: AlgES Date: a /s/ F Project Proofing I BY: Maria) Date: a ii /s/ 1/ 11' `� 1 / f Scanning Preparation ((J x 30 = I d + / = TOTAL PAGES / 9 (Count does not include cover sheet) _ A - BY: d= Date: 31a1+ /s/ Production Scanning 1 Stage 1 Page Count from Scanned File: /q ! 3 (Count does include cover sheet) Page Count Matches Number in Scanning Pr paration: V YES NO BY: Date:3 f I I /s/ f'} P Stage 1 If NO in stage 1, page(s) discrepancies were found: YES NO BY: Maria Date: /s/ Scanning is complete at this point unless rescanning is required. 111111111 I!1II 11 III ReScanned 1111111111111111111 BY: Maria Date: /s/ Comments about this file: Quality Checked III 111111 III IIll III 10/6/2005 Well History File Cover Page.doc RECEIVED STATE OF ALASKA ALA. OIL AND GAS CONSERVATION COMMON JAN 2 5 2013 REPORT OF SUNDRY WELL OPERATIONS AOGCC 1. Operations Abandon U Repair Well ❑ Plug Perforations ❑ Perforate ❑ Other IA Deep Gas Lift Performed: Alter Casing ❑ Pull Tubing ❑ Stimulate - Frac ❑ Waiver ❑ Time Extension ❑ Change Approved Program ❑ Operat. Shutdown ❑ Stimulate - Other ❑ Re -enter Suspended Well ❑ 2. Operator ConocoPhillips Alaska, Inc. 4. Well Class Before Work: 5. Permit to Drill Number: Name: Development 1151 Exploratory ❑ 208 -096- 3. Address: P.O. Box 100360 Anchorage, Alaska 99510 Stratigraphic❑ Service ❑ 6. API Number: 50- 882 - 20125 -00 7. Property Designatipn (Lease Number): 8. Well Name and Number: ADL 17589 / ADL 37831 NCIU A - 14 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field /Pool(s): No new logs were obtained Tertiary em Gas Pool (564570) 11. Present Well Condition Summary: Total Depth measured 11501 feet Plugs measured 8944 feet true vertical 7482 feet Junk measured no fill on plug feet Effective Depth measured 8944 feet Packer measured 7039 feet true vertical 5850 feet true vertical 4748 feet I Casing Length Size MD TVD Burst Collapse Structural N/A N/A N/A N/A Conductor 295' 30" 341' 341' Surface 4701' 9 -5/8" 4747' 3484' Intermediate N/A N/A N/A N/A Production 9934' 7" 9980' 6503' (�� Liner N/A N/A N/A N/A MAR 1 8 2013, SCANNED depth Measured depth 7161 - 7945 feet True Vertical depth 4816' - 5247' feet MD TVD Tubing (size, grade, measured and true vertical depth) 1.900" L -80 6780' - 8239' _. ------ 461 1''5408' WFT Wide Pack LE Camco BP -6i Packers and SSSV (type, measured and true vertical depth) 6740' / 6769' 4587' / 4606' 472' 472' MD TVD MD TVD 12. Stimulation or cement squeeze summary: Set Deep Gas Lift Assembly across GLM # 5 extending below bottom perforation to Intervals treated (measured): assist in de- watering the well. Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas -Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 Bbls oil 2830 MCF /D 36.7 790 psi 75 psi flowing Subsequent to operation: 0 Bbls oil 3500 Mcf /D 22 800 psi 70 psi flowing 14. Attachments: d Copies of Logs and Surveys Run N/A Exploratory❑ Development © Service ❑ Stratigraphic ❑ Daily Report of Well Operations X 16. Well Status after work: Oil ❑ Gas SI WDSPL ❑ Well bore diagram X GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP ❑ SPLUG ❑ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: N/A Contact Marcus Barbee Email barbemgaconocoDhillips.com Printed Name Marcus Barbee Title Wells Engineer Signature Cc1L.4...e_ Phone Z- 0 .5 ----- 6/ 9Z Date 1/24/2013 po RB��pQ p IS JAN 2 8 201 Form 10-404 Revised 10/2012 � (-3/-/.5 Submit Original Only Q om — /77 3 • A -14 Deep Gas Lift Space Out Existing Production Tubing length top bottom Description top bottom . j 6740.32 6746.53 top of top packer 6,711.50 6,742.10 30.63 Tubing 6744.05 centerofslips 6,742.10 6,752.00 9.85 Pup - Tubing y� # in hole -rater of element 6,752.00 6,758.80 6.81 GLM # 5 54/55 . 66.36 3- 1 /2' spacer pipe 6,758.80 6,768.60 9.82 Pup - Tubing 53 s ,' a'6680 AVE sub h� nchor latch seal Internal 52 & }$ a sst' dual check center of slips 1.375 6772.53 67 to bottom Bottom GLM # 5 51 center element 5.1 6773.90 ,� � a ti ; <� Internal 50 f e u 8 `� spacer 49 Internal Seal Asst' 48 iYg e 47 jt order ft imperical" _ 46 49 32 7.625 32.64 6779.93 6812.57 45 47 32 6.75 32.56 6812.57 6845.13 44 46 32 7.25 32.60 6845.13 6877.73 43 45 ° - 32 7.5 32.63 6877.73 6910.36 42 42 32 8 32.67 6910.36 6943.02 41 41 32 6.25 32.52 6943.02 6975.54 40 40 32 6.625 32.55 6975.54 7008.10 39 39 32 7.25 32.60 7008.10 7040.70 38 36 32 7.75 32.65 7040.70 7073.35 37 34 32 7.75 32.65 7073.35 7105.99 36 33 32 7.75 32.65 7105.99 7138.64 35 22 32 7.75 32.65 7138.64 7171.28 34 21 32 8 32.67 7171.28 7203.95 33 20 32 7.75 32.65 7203.95 7236.60 32 9 32 7.75 32.65 7236.60 7269.24 31 3 32 7.75 32.65 7269.24 7301.89 30 Run GLM 3.00 7301.89 7304.89 920 # TRO 29 52 32 6.5 32.54 7304.89 7337.43 28 51 31 8.625 31.72 7337.43 7369.15 27 50 30 2.5 30.21 7369.15 7399.36 26 44 31 6.25 31.52 7399.36 7430.88 25 43 32 6.375 32.53 7430.88 7463.41 24 38 32 6.875 32.57 7463.41 7495.98 23 37 30 8.25 30.69 7495.98 7526.67 22 35 32 4.75 32.40 7526.67 7559.07 21 32 32 7.25 32.60 7559.07 7591.67 20 31 31 8.625 31.72 7591.67 7623.39 19 30 32 4.75 32.40 7623.39 7655.78 18 28 32 6.375 32.53 7655.78 7688.32 17 26 32 6.5 32.54 7688.32 7720.86 16 24 31 10.75 31.90 7720.86 7752.75 15 23 32 6.375 32.53 7752.75 7785.28 14 18 32 7 32.58 7785.28 7817.87 13 17 32 7 32.58 7817.87 7850.45 12 16 31 8.5 31.71 7850.45 7882.16 11 15 32 5.125 32.43 7882.16 7914.59 10 14 32 6.25 32.52 7914.59 7947.11 9 13 32 5 32.42 7947.11 7979.52 8 12 32 5.75 32.48 7979.52 8012.00 7 11 32 4.25 32.35 8012.00 8044.36 6 10 32 6.75 32.56 8044.36 8076.92 5 8 32 6.5 32.54 ' 8076.92 8109.46 4 7 32 5.5 32.46 8109.46 8141.92 3 4 32 5 32.42 8141.92 8174.34 2 2 32 4.375 32.36 8174.34 8206.70 1 1 31 7.75 31.65 8206.70 8238.35 first in the hole 0.78 8238.35 8239.13 shoe • • 10/10/2012 PULL SSSV DRIFT W/ DGL DUMMY TOOL 10/11/2012 1.75" DD BAILER TO 8917' KB SET XX PLUG @ 6911' KB SET CATCHER SUB @ 6910' KB PULL GLM 1 -5 INSTALL DUMMY GLM 1 &2 10/12/2012 HAZARD HUNT CRANE MOVES OF EQUIPMENT TO ELIMINATE IDENTIFIED HAZARDS SET GLM 3 &4 RIG UP HP IRON 10/13/2012 HAZARD HUNT LOAD IA & TUBING W/ 6% KCL PT =1000 SET GLM 5 PULL CATCHER SUB LOAD OUT FLUID PUMP TO BOAT & BACKLOAD 2ND FLUID PUMP PER SCHL REQUEST 10/14/2012 PRESSURE TEST TUBING = 1020 EQUALIZE & PULL XX PLUG 10/15/2012 RIG DOWN & SKID SLU OFF WELL SPOT ELINE ON WELL TALLY 1.900" TUBULARS NIPPLE UP RISER / BOP/WORK PLATFORM FUNCTION /PRESSURE TEST BOP /RISER ASSEMBLY 10/16/2012 BULL HEAD KILL AND LOAD HOLE THROUGH OPEN HOLE DEPLOYMENT OF LOWER DGL ASSEMBLY DEPLOY DGL ASSEMBLY USING 0.563" ELINE AND DPU 10/17/2012 FISH QUICK CONNECT SETTING SLEEVE EQUALIZE RX PLUG RUN CAT STANDING VALVE LOAD HOLE /PT LOWER DGL PACKER PULL CAT STANDING VALVE PULL DMY GLM 5 SET GLM 5 POCKET PROTECTOR RU SL, PULL RX PLUG FROM 6777'RKB, MU UPPER_PACKER ASSEMBLY, SET a 6775' RKB, SHUTDOWN 10/18/2012 FOR NIGHT, IN PROGRESS RU SL, SET TEST FIXTURE IN UPPER PACKER, TEST PACKER 1000PSI, PULL TEST TOOL, SET CATCHER, 10/19/2012 C/O #4 DUMMY TO GLV, PULL CATCHER, INSTALL SSSV, SHUTDOWN FOR NIGHT, IN PROGRESS WAIT ON WEATHER, RD SL, RD BOP/WORK BASKET,RETURN WELL TO PRODUCTION, RESPOT ELINE, 10/20/2012 SHUT DOWN FOR HIGH WINDS, JOB COMPLETE # ' • • DGL Schema 10 -19 -2012 lvorthCaoklnl�Unit Well: A -14 API: 50- 883 - 20125-00 4 1/2° 126# L 80 Production tubing PTD: 2 378 _. I t ADL 1 7589 1 37831 Ori g in al RK = 120. r,„151_ Terti em Gas Pod (5645 Tertiary System Current test rack openings 1789' GLM # 1 dummy GLM #2 dummy ( 3485' 341 A. GLM #3dummy i ��• GLV # 4 950 psi 4949' GLM # 5 (4) / ° sl o ts Vit G LM # 6 dummy GUM # 7 920 ps 24 ' Dual flapper shoe (1) 3!8" port 6740 77 t 9-516' 4747' wI De ment to surface L ' 1 6752' 6769' 1 1 � 1 1; 6839 X n ip f 1 1 'd039' p r ro� 7302' inline GLM 7161' top pert 920# TRO 20 port 13688 #'s 20/40 Gravel behind 4' screens c ry ' 8228 btm pert 8298 pkr 8239 shoe -..14:' 3-1/2 WLEG 8562 m Perf'd and 9023' —9040 immediately isolated ■ Frac'd and 9604' 9624' (6269 tvd top P ert) immediately isolat -. �... 98 I' • 3 7" 9980 stuck off balk'," This l ow er completion was never produced 8-314 - open hole 11501' • • ConocoPhifl s ;, TRANSMITTAL CONFIDENTIAL DATA FROM: Sandra D. Lemke, AT01808 TO: Christine Shartzen ConocoPhillips Alaska, Inc. State of Alaska-AOGCC 333 W. 7 Ave., P.O. Box 100360 Suite 100 Anchorage AK 99510 -0360 Anchorage, Alaska 99501 -3539 RE: NCI A -14, 15, 16 DATE: 5/10/2011 Transmitted: 1 North Cook Inlet Unit [6 NCI A -14 8" —o 36 f gt,31- • I pdsview deliverables to replace large scale log prints; FE /Sonic Scanner /Microresist/MDT I , NCI A -15 90 ic—ocyq 14.103 - i pds view as above; USIT /CBE Eval /MDT NCI I pdsview as above; MDT 00 ()e3 c,. /4-/&36-3 , I Sign, scan and return in ,pdf format if applicable to Sandra.D.Lemke)Conocophillips com CC: NCI A -14, 15, 16 w= II file Receipt: Al e Date: o5X ?j' // -- a , 4 , - GIB- Technical Data Management ! ConccePhillips l Anchorage, Alaska f Pb: 907,2656947 DATA SUBMITTAL COMPLIANCE REPORT 3/15/2011 Permit to Drill 2080960 Well Name /No. N COOK INLET UNIT A -14 Operator CONOCOPHILLIPS COMPANY API No. 50- 883 - 20125 -00 -00 MD 11501 TVD 7482 Completion Date 4/23/2009 Completion Status 1 -GAS Current Status 1 -GAS UIC N REQUIRED INFORMATION Mud Log No Samples No Directional Survey CYe \ DATA INFORMATION III Types Electric or Other Logs Run: GR/RES, USIT, DENS /Neu /MDT (data taken from Logs Portion of Master Well Data Maint Well Log Information: Log/ Electr Data Digital Dataset Log Log Run Interval OH / Type MedlFrmt Number Name Scale Media No Start Stop CH Received Comments EDD C Lis 17372 Formation Micro Ima 4594 9134 Open 12/31/2008 LIS Veri, MAS, FMI ---k og Formation Micro Ima 2 Blu 4738 9085 Open 12/31/2008 FMI, Sonic, GR 15 -Nov- 2008 .g Formation Micro Ima 5 Blu 4738 9085 Open 12/31/2008 FMI, Sonic, GR 15 -Nov- 2008 og Formation Tester 5 Col 5139 9612 Case 12/31/2008 Modular Formation Dynamic Tester, GR 18- CTvJ Nov -2008 og Formation Tester 25 Col 4791 9140 >e 12/31/2008 Formation Evaluation, Formation Micro Resistivity ) Imager, GR 15- Nov -2008 Log Formation Tester 5 Col 4738 9085 Case" 12/ 31/200 8 Formation Evaluation, Ilk Sonic Scanner, GR 15 -Nov- 2008 L Cement Evaluation 5 Col 2920 9795 Case 12/31/2008 CE, USIT, GR, CCL 29- Nov -2008 9I - C Asc Directional Survey 0 11501 Open 1/16/2009 RRpt Directional Survey 0 11501 Open 1/16/2009 pt LIS Verification 240 11496 Open 1/20/2009 LIS Veri, RPM, RPD, GR, RPS, RPX, FET, ROP, FCNT, NCNT, NPHI, DRHO, RHOB, PEF DATA SUBMITTAL COMPLIANCE REPORT 3/15/2011 Permit to Drill 2080960 Well Name /No. N COOK INLET UNIT A -14 Operator CONOCOPHILLIPS COMPANY API No. 50- 883 - 20125 -00 -00 MD 11501 TVD 7482 Completion Date 4/23/2009 Completion Status 1 -GAS Current Status 1 -GAS UIC N ED C Lis 17489 Induction /Resistivity 240 11496 Open 1/20/2009 LIS Veri, RPM, RPD, GR, ' RPS, RPX, FET, ROP, FCNT, NCNT, NPHI, j DRHO, RHOB, PEF ED C Pds 17490 Induction /Resistivity 420 11501 Open 1/20/2009 EWR logs in PDS, CGM and EMF graphics III f og Induction /Resistivity 25 Col 420 11501 Open 1/20/2009 MD ROP, DGR, EWR, CTN, ALD 13- Nov -2008 1 og Induction /Resistivity 25 Col 419 7482 Open 1/20/2009 TVD DGR, EWR, CTN, ALD 13- Nov -2008 ?46t Report: Final Well R 0 0 Open 2/19/2009 Final Well Report, Equip & Crew, Well Data, Geo Data, Pres /Form Data, Drilling Data, Daily Reports ED C 17579 Report: Final Well R 0 0 Open 2/19/2009 Final Well Report, Equip & Crew, Well Data, Geo Data, Pres /Form Data, Drilling Data, Daily Reports in Word and w /PDS Mud Logs CVLog Mud Log 2 Col 4757 11501 Open 2/19/2009 MD Mud Log ' w og Mud Log 2 Col 4757 11501 Open 2/19/2009 TVD Mud Log ''Cog Mud Log 2 Col 4757 11501 Open 2/19/2009 MD LWD Combo Log III Log Mud Log 2 Col 4757 11501 Open 2/19/2009 TVD LWD Combo Log og Mud Log 2 Col 4757 11501 Open 2/19/2009 MD Drilling Dynamic Log Mud Log 2 Col 4757 11501 Open 2/19/2009 TVD Drilling Dynamic o, Mud Log 2 Col 4757 11501 Open 2/19/2009 MD Gas Ratio Log Mud Log 2 Col 4757 11501 Open 2/19/2009 TVD Gas Ratio D C Pds 18090 Perforation 9023 9624 Case 6/3/2009 Perf 3.125" Frac, 6SPF, 60Deg, GR, CCL 8 -Apr- 2009 og Perforation 5 Blu 9023 9624 Case 6/3/2009 Perf 3.125" Frac, 6SPF, 60Deg, GR, CCL 8 -Apr- 2009 DATA SUBMITTAL COMPLIANCE REPORT 3/15/2011 Permit to Drill 2080960 Well Name /No. N COOK INLET UNIT A -14 Operator CONOCOPHILLIPS COMPANY API No. 50- 883 - 20125 -00 -00 MD 11501 TVD 7482 Completion Date 4/23/2009 Completion Status 1 -GAS Current Status 1 -GAS UIC N Well Cores /Samples Information: Sample Interval Set Name Start Stop Sent Received Number Comments • ADDITIONAL INFORMATION Well Cored? Y CN1 Daily History Received? / N Chips Received? .Y- i-N- -- Formation Tops Y N Analysis rt-N Received? Comments: Compliance Reviewed By: Date: L / • N. STATE OF ALASKA :-1.1- ' ‘ 1 ': - .,.: a 4 ; , ALASKAIL AND GAS CONSERVATION COMMISN .' , # ki GAS WELL OPEN FLOW POTENTIAL TEST REPORT U( kf 20r; 1a. Test: U Initial U Annual U Special lb. Type Test: U Stabilized I 4I Non S abilized U Multipoint ❑ Constant Time ❑ Isochronal ❑ Other ' � � •)' L. _ . 111 3# r` 2. Operator Name: 5. Date Completed: 11. Permit to Drill'Nurn Conocophillips Alaska, Inc. 7/12/2009 208 -096 3. Address: 6. Date TD Reached: 12. API Number: PO Box 10360. Anchorage, AK 99510 June 27, 1931 50- 883 - 20125 -00 4a. Location of Well (Governmental Section): 7. KB Elevation (ft): 13. Well Name and Number: Surface: 1302' FNL 1019' FWL SEC 6 T11N R9W 116 NCIU A -14 Top of Productive Horizon: 8. Plug Back Depth(MD +TVD): 14. Field /Pool(s): 4303' FNL 2661' FEL SEC 31 T12N R9W 8944/5850 North Cook Inlet Unit Total Depth: 9. Total Depth (MD + TVD): Tertiary Pool (564570) 4001' FNL 1045' FEL SEC 30 T12N R9W 8944/5850 4b. Location of Well (State Base Plane Coordinates): 10. Land Use Permit: 15. Property Designation: Surface: x- 332038 y- 2586677 Zone- 4 ALK 2916 ADL 17589 / ADL 37831 TPI: x- 334397 y- 2590623 Zone- 4 16. Type of Completion (Describe): Total Depth: x- 335027 y- 2593893 Zone- 4 Gravel Pack 17. Casing Size Weight per foot, Ib. I.D. in inches Set at ft. 19. Perforations: From To 7" 26 6.276 9980 7161 - ,7173, 7220 -7259, 7553 -7608, 18. Tubing Size Weight per foot, Ib. I.D. in inches Set at ft. 7639 -7664, 7807 -7827, 7937 -7945 4.5 12.6 3.89 7050 20. Packer set at ft: 21. GOR cf /bbl: 22. API Liquid Hydrocardbons: 23. Specific Gravity Flowing Fluid (G): 7039 0 1.02 24a. Producing through: 24b. Reservoir Temp: 24c. Reservoir Pressure: 24d. Barometric Pressure (Pa): El Tubing ❑ Casing 87 F° 637 psia @ Datum 4100 TVDSS psia 25. Length of Flow Channel (L): Vertical Depth (H): Gg: % CO2: % N % H Prover: Meter Run: Taps: 0.565 0.25 0.25 0 26. FLOW DATA TUBING DATA CASING DATA Prover Choke Pressure Diff. Temp. Pressure Temp. Pressure Temp. Duration of Flow No Line X Orifice psig Hw F psig F° psig F Hr. Size (in.) Size (in.) 1. X 243 243 4 2. X 295 295 3.5 3. X 427 427 3.9 4. X 488 488 3.9 5. X 637 637 4 Basic Coefficient Flow Temp. Super Comp. Pressure Gravity Factor Rate of Flow No. (24 -Hour) hw Pm Factor F Factor Q Mcfd Fb or Fp Ft g Fpv 1. 5850 2. 5070 3. 3420 4 2381 5. 0 Temperature for Separator for Flowing No. Pr T Tr z Gas Fluid Gg G 1. January 0, 1900 545 1.58 0.97 2. 545 1.58 0.97 3. 545 1.58 0.97 Critical Pressure 673 673 4. 545 1.58 0.97 Critical Temperature 345 345 5. Form 10 -421 Revised 1/2004 CONTINUED ON REVERS • , '� Submit in Duplicate • R AUG 1 0 2009 Pc 673 pct 452929 • 673 pf 452929 No. Pt Pt Pc z z -Pt 2 Pw Pw Pc Ps Ps Pf-Ps2 1. 243 59049 393880 2. 295 87025 365904 3 427 182329 270600 4 488 238144 214785 5. 25. AOF (Mcfd) 6980 n 1.21 Remarks: Test used a downhole pressure /temperature gauge. I hereby certify th- the foregoing is true and correct to the best of my knowledge. Signed 41Pr Title Date DEFINITIONS OF SYMBOLS AOF Absolute Open Flow Potential. Rate of Flow that would be obtained if the bottom hole pressure opposite the producing face were reduced to zero psia Fb Basic orifice factor Mcfd / 4 hwPm Fp Basic critical flow prover or positive choke factor Mcfd /psia Fg Specific gravity factor, dimensionless Fpv Super compressibility factor= dimensionless Ft Flowing temperature factor, dimensionless G Specific gravity of flowing fluid (air= 1.000), dimensionless Gg Specific gravity of separator gas (air= 1.00), dimensionless GOR Gas -oil ratio, cu. ft. of gas (14.65 psia and 60 degrees F) per barrel oil (60 degrees F) hw Meter differential pressure, inches of water H Vertical depth corresponding to L, feet (TVD) L Length of flow channel, feet (MD) n Exponent (slope) of back - pressure equation, dimensionless Pa Field barometric pressure, psia Pc Shut -in wellhead pressure, psia Pf Shut -in pressure at vertical depth H, psia Pm Static pressure at point of gas measurement, psia Pr Reduced pressure, dimensionless Ps Flowing pressure at vertical depth H, psia Pt Flowing wellhead pressure, psia Pw Static column wellhead pressure corresponding to Pt, psia Q Rate of flow, Mcfd (14.65 psia and 60 degrees F) Tr Reduced temperature, dimensionless T Absolute temperature, degrees Rankin Z Compressibility factor, dimensionless Recommended procedures for tests and calculations may be found in the Manual of Back- Pressure Testing of Gas Wells, Interstate Oil Compact Commission, Oklahoma City, Oklahoma. Form 10-421 Revised 1/2004 Side 2 NCIU A -14 Multi -point Test 7/12/09 1,000,000 n =1.21, AOF =6980 • • Test Data a- N a •Y- a ,. TD 100,000 1,000 10,000 Q, Mscf /D RECE tVEC- JUN 0 3 1009 05/26/09 Alaska O Gas s. Commission S h ber Anchorage NO. 5258 Schlumberger -DCS 2525 Gambell Street, Suite 400 Company: Alaska Oil & Gas Cons Comm Anchorage, AK 99503 -2838 Attn: Christine Mahnken ATTN: Beth 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: North Cook Inlet • Well Job # Log Description Date BL Color CD NCIU A -14 AXML -00021 PERFORATING RECORD (REVISED) 04/08/09 1 1 > bcF, h Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561 -8317. Thank you. • G. L. Alvord Alaska Drilling Manager Drilling & Wells i P. O. Box 100360 Anchorage, AK 99510 -0360 c:onocoP l • ps Phone: 907 - 265 -6120 May 21, 2009 Commissioner State of Alaska MAY 2 1 Alaska Oil & Gas Conservation Commission 333 West 7 Avenue Suite 100 Alaska Oil & Gas 0x 4r.; AILS O_ Anchorage, Alaska 99501 Anchorage Subject: Well Completion Report for NCIU A -14 (208 -096) Dear Commissioner: ConocoPhillips Alaska, Inc. submits the attached Well Completion Report for the recent drilling operations on the well NCIU A -14. If you have any questions regarding this matter, please contact me at 265 -6120 or David Reimer at 263 -4347. Sincerely, A . 6.C'.(__ G. L. Alvord Alaska Drilling Manager CPAI Drilling GLA/skad • STATE OF ALASKA 110 REC ALASKA OIL AND GAS CONSERVATION COMMISSION MAY 2 1 ?009 E WELL COMPLETION OR RECOMPLETION REPORT o � la. Well Status: Oil ❑ Gas U • Plugged Cl Abandoned El Suspended ❑ `A'8l 6 W e i ll Cl ss: c[ rage 20AAC 25.105 20AAC 25.110 Develop Exploratory ❑ GINJ ❑ WINJ ❑ WDSPL ❑ WAG ❑ Other ❑ No. of Completions: Service ❑ Stratigraphic Test ❑ 2. Operator Name: 5. Date Comp., Susp., VP t -41 1 Permit to Drill Number: r3 s ConocoPhillips Alaska, Inc. orAband.: ApriL28 2009 208 - 096 • 3. Address: 6. Date Spudded: 13. API Number: P. O. Box 100360, Anchorage, AK 99510 - 0360 August 18, 2008 ' 50 883 - 20125 - 00 • 4a. Location of Well (Governmental Section): 7. Date TD Reached: 14. Well Name and Number: Surface: 1302' FNL, 1019' FWL, Sec. 6, T11 N, R9W, SM • November 13, 2008 • NCIU A - 14 Top of Productive Horizon: 8. KB (ft above MSL): 120.6' RKB 15. Field /Pool(s): 1229' FNL, 1207 FEL, Sec. 31, T12N, R9W, SM Ground (ft MSL): not applicable North Cook Inlet Total Depth: 9. Plug Back Depth (MD + TVD): 676' FSL, 1103' FEL, Sec. 30, T12N, R9W, SM 8944' MD / 5851' TVD Tertiary System Gas Pool • 4b. Location of Well (State Base Plane Coordinates): 10. Total Depth (MD + ND): 16. Property Designation: • Surface: x 332038 ' y 2586677 • Zone 4 • 11501' MD / 7482' TVD • ADL 17589, 37831 • TPI: x - 334901 y - 2591990 Zone 4 11. SSSV Depth (MD + ND): 17. Land Use Permit: Total Depth: x 335027. y 2593893 • Zone 4 nipple @ 492' MD / 492' TVD n/a 18. Directional Survey: Yes 0 No ❑ 19. Water Depth, if Offshore: 20. Thickness of Permafrost (TVD): (Submit electronic and printed information per 20 AAC 25.050) 101' MD • (ft MSL) not applicable 21. Logs Obtained (List all logs here and submit electronic and printed information per 20 AAC 25.071): GR/RES, USIT, Dens /Neu /MDT 22. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD SETTING DEPTH ND HOLE AMOUNT CEMENTING RECORD CASING SIZE WT. PER FT. GRADE TOP BOTTOM TOP BOTTOM SIZE PULLED 30" na na 46' 341' 46' 341' n/a driven 9 -5/8" 40# L -80 46' 4747' / 46' 3484' 12.25" 1310 sx Type 1 7" 26# L -80 46' 9980' ! 46' 6503' 8.75" 476 sx Class G 23. Open to production or injection? Yes Q No ❑ If Yes, list each 24. TUBING RECORD Interval open (MD+TVD of Top & Bottom; Perforation Size and Number): SIZE DEPTH SET (MD) PACKER SET 4.5" 7050' 7039' 9023' - 9040' MD ' 5902' - 5914' TVD 6 spf 25. ACID, FRACTURE, CEMENT SQUEEZE, ETC. 9604' - 9624' MD / 6270' - 6282' ND 6 spf , DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED 9023' -9040' 25 bbls of KCI 9604' -9624' 150 bbls KCI plug @ 8944' DPM no cement CIBP © 9801' MD no cement 26. PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) April 24, 2009 Gas Production Date of Test Hours Tested Production for OIL -BBL GAS -MCF WATER -BBL CHOKE SIZE GAS - OIL RATIO 5/1/2009 Test Period -> not available not available Flow Tubing Casing Pressure Calculated OIL -BBL GAS -MCF , WATER -BBL OIL GRAVITY - API (corr) press. 242 psi 24 -Hour Rate -> 3.53 mmscf /d 98 not available 27. CORE DATA Conventional Core(s) Acquired? Yes ❑ No 0 • Sidewall Cores Acquired? Yes ❑ No 0 • If Yes to either question, list formations and intervals cored (MD+TVD of top and bottom of each), and summarize lithology and presence of oil, gas or water (Submit separate sheets with this form, if needed). Submit detailed descriptions, core chips, photographs and laboratory analytical results per 20 AAC 25.071. d :GOMPLETiON NONE it VER� IED Form 10-407 Revised 2/2007 CONTINUED ON REVERSE SIDE A S "1 ,JuN 1 0 Boas , l �1ie�� 28. GEOLOGIC MARKERS (List all formations and mark encountered): 29. • FORMATION TESTS NAME MD TVD Well tested? ❑ Yes Ei No If yes, list intervals and formations tested, Permafrost - Top not applicable not applicable briefly summarizing test results. Attach separate sheets to this form, if Permafrost - Bottom not applicable not applicable needed, and submit detailed test information per 20 AAC 25.071. see attached list N/A Formation at total depth: Beluga , 30. LIST OF ATTACHMENTS Summary of Daily Operations, Directional Survey, geologic markers, Mechanical Integrity Test 1- 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: David Reimer © 263 - 4347 Printed Name G. I Title: Alaska Drilling Manager Zt Signature Name / yl _ Phone 2‘o5 •- /D (LO Date b Sharon Allsup -Drake INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Submit a well schematic diagram with each 10 -407 well completion report and 10 -404 well sundry report when the downhole well design is changed. Item 1a: Classification of Service wells: Gas injection, water injection, Water - Alternating -Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 4b: TPI (Top of Producing Interval). Item 8: The Kelly Bushing and Ground level elevations in feet above mean sea level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 13: The API number reported to AOGCC must be 14 digits (ex: 50- 029 - 20123- 00 -00). Item 20: Report true vertical thickness of permafrost in Box 20. Provide MD and TVD for the top and base of permafrost in Box 28. Item 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut -in, or Other (explain). Item 27: Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Submit detailed description and analytical laboratory information required by 20 AAC 25.071. Item 29: Provide a list of intervals tested and the corresponding formation, and a brief summary of this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Form 10 -407 Revised 2/2007 • • WELL DEPTH ZONE FEET TOPS NCI_A -14 4959 Stray NCI_A -14 5104 C.I. A NCI_A -14 5164 C.I. B NCI_A-14 5569 C.I. 1 NCI_A-14 5678 C.I. 2 NCI_A -14 5808 C.I. 3 NCI_A -14 5938 C.I. 4 NCI_A -14 6006 C.I. 5 NCI_A -14 6132 C.I. 6 NCI_A -14 6204 C.I. 7 NCI_A -14 6392 C.I. 8 NCI_A -14 6514 C.I. 9 NCI_A -14 6584 C.I. 10 NCI_A -14 6682 C.I. 11 NCI_A -14 6742 Beluga A NCI_A -14 6890 Beluga B NCI_A -14 7211 Beluga C NCI_A -14 7495 Beluga D NCI_A-14 7711 Beluga E NCI_A-14 7903 Beluga F NCI_A -14 8066 Beluga G NCI_A -14 8347 Beluga H NCI_A -14 8598 Beluga I NCI_A -14 8740 Beluga J NCI_A -14 8799 Beluga K NCI_A-14 8900 Beluga L NCI_A-14 8938 Beluga M NCI_A -14 9097 Beluga N NCI_A -14 9236 Beluga 0 NCI_A-14 9309 Beluga P NCI_A -14 9481 Beluga Q NCI_A -14 9687 Beluga R NCI_A -14 9869 Beluga S NCI_A -14 10130 Beluga T NCI_A -14 10538 Beluga U NCI_A -14 11120 Beluga U base NCI_A-14 11501 TD • l v a ' e. 3 ConocoPhillips(Alaska) Inc. North Cook Inlet Unit North Cook Inlet Unit NCIU A -14 Permit to Drill 208 -096 API 50-883-20125-00 � � 4 4 Sperry Drilling Services Definitive Survey Report 24 November, 2008 g uk fV N tki :- HALLIBURTON Sperry Drilling Services • r ConocoPhillips or its affiliates Definitive Survey Report Company: ConocoPhillips(Alaska) Inc. Local Co-ordinate Reference: Well NCIU A -14 Project: North Cook Inlet Unit WD Reference: NCIU A -14 © 120.58ft (Kuukpik 5) • Site: North Cook Inlet Unit MD Reference: NCIU A -14 © 120.58ft (Kuukpik 5) Well: NCIU A -14 North Reference: " True Wellbore: NCIU A -14 Survey Calculation Method: Minimum Curvature • Design: NCIU A -14 Database: EDM Alaska Prod v16 Project North Cook Inlet Unit Map System: US State Plane 1927 (Exact solution) . System Datum: MLLW Geo Datum: NAD 1927 (NADCON CONUS) Using Well Reference Point Map Zone: Alaska Zone 04 • Using geodetic scale factor Well NCIU A -14 Well Position +NI-S 0.00 ft Northing: 2,586,678.02ft • Latitude: 61° 4' 35.872 N +E / -W 0.00ft Easting: 332,037.45 • Longitude: 150° 56' 54.745 W Position Uncertainty 0.00 ft Wellhead Elevation: 71.90ft Water Depth: 101.00:ft . Wellbore NCIU A -14 Magnetics Model Name Sample Date Declination Dip Angle Field Strength BGGM2007 10/27/2008 18.98 73.90 55,659 1 Design NCIU A -14 Audit Notes: Version: 1.0 Phase: ACTUAL Tie On Depth: 221.58 Vertical Section: Depth From (TVD) +N/-S +E/ -W Direction ` . 221.58 0.00 0.00 21.68 Survey Program Date From To' (ft) (ft) Survey (Wellbore) Tool Name Description Survey Crate 250.00 1,453.00 NCIU A -14 GYRO (NCIU A -14) GYD -GC-SS Gyrodata gyro single shots 8/18/2008 1 i 1,540.72 11,458.82 NCIU A -14 MWD (NCIU A -14) MWD +SCC +SAG MWD + Short Collar correction + BHA SAG Co 8/20/2008 1: Surrey . Map . . " Maps Vertical MD Inc. Azi TVD TVDSS +N /-S , +E/ -W Northing. Easting DLS Section , (ft) = . ( °) , ( °) .. (ft) (ft) (ft) (ft) ;- (ft). on ( °/100') (ft)_ Survey Tool Name .. . 221.58 0.18 324.83 221.58 101.00 0.00 0.00 2,586,678.02 332,037.45 0.00 0.00 UNDEFINED 250.00 0.29 318.75 250.00 129.42 0.09 -0.07 2,586,678.11 332„037.38 0.40 0.06 GYD -GC -SS (1) 300.00 0.45 322.22 300.00 179.42 0.34 -0.25 2,586,678.37 332,037.18 0.32 0.21 GYD -GC-SS (1) 358.00 1.04 313.19 357.99 237.41 0.88 -0.80 2,586,678.91 332036.67 1.03 0.52 GYD -GC -SS (1) 389.00 0.88 309.75 388.99 268.41 1.23 -1.19 2,586,679.26 332036.28 0.55 0.70 GYD -GC -SS (1) 449.00 0.29 336.02 448.98 328.40 1.66 -1.60 2,586,679.70 332035.87 1.06 0.95 GYD -GC -SS (1) 483.00 0.11 168.62 482.98 362.40 1.71 -1.63 2,586,679.75 332035.85 1.17 0.98 GYD -GC -SS (1) 509.00 0.09 160.40 508.98 388.40 1.66 -1.62 2,586,679.71 332,035.86 0.09 0.95 GYD -GC -SS (1) 543.00 0.11 26.29 542.98 422.40 1.67 -1.60 2,586,679.71 332,035.88 0.54 0.96 GYD -GC -SS (1) 630.00 0.79 83.98 629.98 509.40 1.80 -0.961 2,586,679.84 332,036.52 0.85 1.32 GYD -GC-SS (1) 691.00 1.18 113.26 690.97 570.39 1.60 0.03 2,586,679.62 332037.51 1.02 1.50 GYD -GC -SS (1) 754.00 1.69 123.92 753.95 633.37 0.83 1.40 2,586,678.83 332 038.86 0.91 1.28 GYD -GC-SS (1) 817.00 1.80 126.65 816.92 696.34 -0.28 2.96 2,586,677.69 332,040.41 0.22 0.83 GYD -GC -SS (1) 11/24/2008 10 :48 :09AM Page 2 COMPASS 2003.16 Build 42F • • ConocoPhillips or its affiliates Definitive Survey Report Company: ConocoPhillips(Alaska) Inc. Local Co- ordinate Reference: Well NCIU A -14 Project: North Cook Inlet Unit TVD Reference: NCIU A -14 @ 120.58ft (Kuukpik 5) Site: North Cook Inlet Unit MD Reference: NCIU A -14 © 120.58ft (Kuukpik 5) Well: NCIU A -14 North Reference: True Wellbore: NCIU A -14 Survey Calculation Method: , : Minimum Curvature Design: NCIU A -14 Database: EDM Alaska Prod v16 Survey 1 Map Map Vertical MD Inc, Azi 1VD TVDSS +N/-S +E!-W Northing Easting DLS Section (ft) (°) C) (ft) (ft) (ft) (ft) (ft) (ft) ` C1100') (ft) Survey Tool Name ' < 882.00 2.22 115.17 881.88 761.30 -1.43 4.92 2,586,676.52 332,042.35 0.89 0.49 GYD-GC-SS (1) 946.00 3.89 106.07 945.79 825.21 -2.56 8.13 2,586,675.35 332,045.54 2.71 0.63 GYD-GC-SS (1) 981.00 4.77 103.43 980.69 860.11 -3.22 10.69 2,586,674.64 332,048.09 2.58 0.95 GYD -GC -SS (1) 1,009.00 5.02 102.20 1,008.59 888.01 -3.75 13.02 2,586,674.08 332,050.41 0.97 1.32 GYD-GC-SS (1) 1,074.00 5.63 90.00 1,073.31 952.73 -4.35 18.98 2,586,673.39 332,056.37 1.97 2.97 GYD -GC -SS (1) 1,137.00 6.81 69.37 1,135.95 1,015.37 -3.04 25.57 2586,674.61 332,062.98 3.98 6.62 GYD-GC-SS (1) 1,200.00 8.79 46.73 1,198.37 1,077.79 1.58 32.57 2,586,679.13 332,070.04 5.74 13.50 GYD -GC -SS (1) 1,263.00 11.22 32.88 1,260.42 1,139.84 10.03 39.41 2,586,687.48 332,077.00 5.40 23.88 GYD -GC -SS (1) 1,326.00 13.31 17.69 1,322.00 1,201.42 22.09 44.94 2,586,699.46 332,082.71 6.08 37.13 GYD -GC -SS (1) 1,389.00 14.94 14.60 1,383.09 1,262.51 36.86 49.19 2,586,714.16 332,087.17 2.85 52.42 GYD -GC -SS (1) 1,453.00 17.22 15.93 1,444.58 1,324.00 53.95 53.87 2,586,731.18 332,092.10 3.61 70.04 GYD -GC-SS (1) 1,540.72 20.00 21.96 1,527.71 1,407.13 80.36 63.05 2,586,757.45 332,101.66 3.85 97.96 MWD +SCC +SAG (2) 1,604.07 21.89 23.88 1,586.88 1,466.30 101.21 71.88 2,586,778.17 332,110.79 3.17 120.60 MWD +SCC +SAG (2) 1,667.57 23.93 25.78 1,645.37 1,524.79 123.63 82.28 2,586,800.44 332,121.51 3.42 145.28 MWD +SCC +SAG (2) 1,731.07 26.69 25.80 1,702.76 1,582.18 148.07 94.09 2,586,824.70 332,133.67 4.35 172.35 MWD +SCC +SAG (2) 1,794.02 29.90 24.95 1,758.19 1,637.61 175.03 106.86 2,586,851.47 332,146.83 5.14 202.13 MWD +SCC+SAG (2) 1,857.27 32.95 2425 1,812.15 1,691.57 205.02 120.58 2,586,881.25 332,160.98 4.86 235.06 MWD +SCC+SAG (2) 1,920.77 34.11 23.64 1,865.09 1,744.51 237.07 134.81 2,586,913.10 332,175.613 1.90 270.10 MWD +SCC +SAG (2) I 1,984.27 36.01 23.20 1,917.06 1,796.48 270.55 149.31 2,586,946.36 332,190.65 3.02 306.56 MWD +SCC +SAG (2) 2,047.62 39.79 24.52 1,967.04 1,846.46 306.12 165.06 2,586,981.69 332,206.92 6.10 345.44 MWD +SCC +SAG (2) 1 1 2,112.02 41.61 23.16 2,015.86 1,895.28 344.53 182.02 2,587,019.85 332,224.44 3.14 387.40 MWD +SCC +SAG (2) 2,175.22 43.07 23.78 2,062.58 1,942.00 383.57 198.98 2,587,058.64 332,241.96 2.40 429.94 MWD +SCC +SAG (2) 2,239.27 46.43 22.16 2,108.06 1,987.48 425.09 216.56 2,587,099.90 332,260.13 5.54 475.02 MWD +SCC +SAG (2) 2,303.62 48.78 24.62 2,151.45 2,030.87 468.69 235.44 2,587,143.22 332,279.64 4.62 522.51 MWD +SCC +SAG (2) 2,368.47 52.14 26.75 2,192.73 2,072.15 513.74 257.13 2,587,187.94 332,301.93 5.77 572.38 MWD +SCC +SAG (2) 2,433.27 55.55 28.02 2,230.95 2,110.37 560.18 281.20 2,587,234.03 332,326.72 5.49 624.43 MWD +SCC +SAG (2) 2,486.68 53.18 27.59 2,262.07 2,141.49 598.57 301.45 2,587,272.12 332,347.52 4.49 667.59 MWD +SCC +SAG (2) 2,577.83 54.29 28.13 2,315.99 2,195.41 663.55 335.79 2,587,336.59 332,382.38 1.31 740.65 MWD +SCC +SAG (2) 2,641.28 55.66 28.50 2,352.40 2,231.82 709.29 360.44 2,587,381.96 332,408.11 2.21 792.26 MWD +SCC +SAG (2) 2,705.53 58.95 30.28 2,387.11 2,266.53 756.38 386.98 2,587,428.66 332,435.33 5.63 845.83 MWD +SCC +SAG (2) 2,769.63 59,75 31.69 2,419.78 2,299.20 803.65 415.37 2.587,475.52 332,464.40 2.27 900.25 MWD +SCC +SAG (2) 2,832.93 59.01 30.62 2,452.03 2,331.45 850.27 443.56 2,587,521.72 332,493.25 1.87 953.97 MWD +SCC +SAG (2) 2,896.83 58.37 31.05 2,485.23 2,364.65 897.15 471.54 2,587,568.18 332,521.91 1.15 1,007.87 MWD-'SCC +SAG (2) 2,960.78 57.73 30.96 2,519.07 2,398.49 943.65 499.49 2,587,614.27 332,550.53 1.01 1,061.42 MWD +SCC +SAG (2) 3,024.83 57.27 31.43 2,553.49 2,432.91 989.86 527.47 2,587,660.07 332,579.17 0.95 1,114.69 MWD +SCC +SAG (2) 3,087.43 56.88 31.97 2,587.51 2,466.93 1,034.57 555.08 2,587,704.37 332,607.43 0.96 1,166.43 MWD +SCC +SAG (2) 3,151.08 56.79 32.08 2,622.33 2,501.75 1,079.74 583.33 2,587,749.12 332,636.33 0.20 1,218.85 MWD +SCC +SAG (2) 3,214.88 58.69 31.67 2,656.39 2,535.81 1,125.56 611.82 2,587,794.52 332565.48 3.03 1,271.94 MWD +SCC +SAG (2) 3,279.03 58.71 31.82 2,689.71 2,569.13 1,172.17 640.66 2,587,840.70 332,694.99 0.20 1,325.91 MWD +SCC +SAG (2) 1 3,339.88 58.49 32.59 2,721.42 2,600.84 1,216.12 668.34 2,587,884.24 332,723.38 1.14 1,376.98 MWD +SCC +SAG (2) 11/24/2008 10:48:09AM Page 3 COMPASS 2003.16 Build 42F • • ConocoPhillips or its affiliates Definitive Survey Report Company: ConocoPhillips(Alaska) Inc. Local Co- ordinate Reference: Well NCIU A -14 Project :. North Cook Inlet Unit TVD Reference: NCIU A -14 @ 120.58ft (Kuukpik 5) Site: North Cook Inlet Unit MD Reference: = NCIU A -14 © 120.58ft (Kuukpik 5) Well: NCIU A -14 North Reference: True Welibore: NCIU A -14 Survey Calculation Method: Minimum Curvature Design: NCIU A -14 Database: EDM Alaska Prod v16 Survey Map Map Vertical MD Inc Azi TVD TVDSS +N(-S +EJ -W . ' Northing Easting DLS Section (ft) ( °) O (ft) (ft) (ft). (ft) (ft) (ft) " ( °i100') (ft) Survey Tool Name 3,404.93 58.19 32.69 2,755.56 2,634.98 1,262.74 698.20 2,587,930.43 332,753.83 0.48 1,431.34 MWD +SCC +SAG (2) 3,469.23 57.98 33.43 2,789.55 2,668.97 1,308.49 727.98 2,587,975.73 332,784.26 1.03 1,484.84 MWD +SCC +SAG (2) 3,531.53 58.23 32.45 2,822.47 2,701.89 1,352.88 756.74 2,588,019.70 332,813.66 1.39 1,536.71 MWD +SCC +SAG (2) I 3,593.88 58.59 31.72 2,855.13 2,734.55 1,397.87 784.95 2,588,064.28 332,842.52 1.15 1,588.95 MWD +SCC +SAG (2) 3,658.33 58.73 30.89 2,888.65 2,768.07 1,444.91 813.55 2,588,110.89 332,871.80 1.12 1,643.22 MWD +SCC +SAG (2) 3,721.68 58.52 30.91 2,921.64 2,801.06 1,491.32 841.33 2,588,156.89 332,900.24 0.33 1,696.61 MWD +SCC +SAG (2) 3,785.38 58.42 31.04 2,954.95 2,834.37 1,537.87 869.27 2,588,203.03 332,928.86 0.23 1,750.19 MWD +SCC +SAG (2) 3,849.58 58.36 31.01 2,988.60 2,868.02 1,584.72 897.45 2,588,249.46 332,957.71 0.10 1,804.14 MWD +SCC +SAG (2) 3,912.88 57.99 31.57 3,021.98 2,901.40 1,630.68 925.38 2,588,295.01 332,986.30 0.95 1,857.17 MWD +SCC +SAG (2) 3,977.18 57.50 31.85 3,056.29 2,935.71 1,676.94 953.96 2,588,340.85 333,015.55 0.85 1,910.71 MWD +SCC +SAG (2) 4,038.68 57.47 30.78 3,089.35 2,968.77 1,721.25 980.92 2,588,384.76 333,043.14 1.47 1,961.84 MWD +SCC +SAG (2) 4,102.53 57.34 30.68 3,123.75 3,003.17 1,767.49 1,008.41 2,588,430.59 333,071.29 0.24 2,014.96 MWD +SCC +SAG (2) 4,167.27 57.12 30.68 3,158.79 3,038.21 1,814.30 1,036.18 2,588,477.00 333,099.74 0.34 2,068.73 MWD +SCC +SAG (2) 4,230.37 56.39 29.44 3,193.38 3,072.80 1,859.98 1,062.62 2,588,522.28 333,126.84 2.01 2,120.93 MWD +SCC +SAG (2) 4,292.72 56.11 29.33 3,228.02 3,107.44 1,905.15 1,088.05 2,588,567.07 333,152.92 0.47 2,172.31 MWD +SCC +SAG (2) 4,356.32 55.97 29.46 3,263.55 3,142.97 1,951.11 1,113.95 2,588,612.65 333,179.48 0.28 2,224.58 MWD +SCC +SAG (2) 4,419.92 55.60 29.05 3,299.31 3,178.73 1,996.99 1,139.65 2,588,658.15 333,205.84 0.79 2,276.71 MWD +SCC +SAG (2) 4,483.67 55.56 28.93 3,335.35 3,214.77 2,042.99 1,165.14 2,588,703.78 333,231.99 0.17 2,328.87 MWD +SCC +SAG (2) 4,547.02 55.43 29.26 3,371.23 3,250.65 2,088.61 1,190.52 2,588,749.02 333,258.03 0.48 2,380.64 MWD +SCC +SAG (2) 4,611.07 55.17 29.55 3,407.70 3,287.12 2,1,34.48 1,216.38 2,588,794.51 333,284.55 0.55 2,432.82 MWD +SCC +SAG (2) 4,673.77 54.76 29.56 3,443.69 3,323.11 2,179.14 1,241.70 2,588,838.79 333,310.51 0.65 2,483.68 MWD +SCC +SAG (2) 4,706.77 55.01 29.65 3,462.67 3,342.09 2,202.61 1,255.03 2,588,862.07 333,324.18 0.79 2,510.41 MWD +SCC +SAG (2) 4,767.07 55.50 29.48 3,497.04 3,376.46 2,245.71 1,279.48 2,588,904.80 333,349.25 0.84 2,559.49 MWD +SCC +SAG (2) 4,832.62 56.13 29.67 3,533.87 3,413.29 2,292.87 1,306.24 2,588,951.57 333,376.69 0.99 2,613.20 MWD +SCC +SAG (2) 4,895.52 55.96 29.50 3,569.00 3,448.42 2,338.24 1,332.00 2,588,996.56 333,403.11 0.35 2,664.88 MWD +SCC +SAG (2) 4,958.67 55.78 29.48 3,604.43 3,483.85 2,383.74 1,357.74 2,589,041.68 333,429.49 0.29 2,716.67 MWD +SCC +SAG (2) I 5 55.49 29.66 3,638.02 3,517.44 2,426.46 1,381.97 2,589,084.04 333,454.35 0.55 2,765.32 MWD +SCC +SAG (2) 5,085.27 55.86 29.75 3,675.86 3,555.28 2,474.59 1,409.43 2,589,131.76 333,482.50 0.56 2,820.19 MWD +SCC +SAG (2) 5,149.57 55.93 30.09 3,711.91 3,591.33 2,520.74 1,435.99 2,589,177.51 333,509.72 0.45 2,872.88 MWD +SCC +SAG (2) .5,213.42 56.85 31.02 3,747.25 3,626.67 2,566.53 1,463.02 2,589,222.90 333,537.41 1.88 2,925.41 MWD +SCC +SAG (2) 5,277.82 56.51 .31.48 • 3,782.63 3,662.05 2,612.53 1,490.94 2,589,268.50 333,565.99 0.80 2,978.48 MWD +SCC +SAG (2) 5,340.77 56.40 31.41' ' 3,817.41 3,696.83 2,657.29 1,518.31 2,589,312.85 333,594.00 0.20 3,030.18 MWD +SCC +SAG (2) 5,405.72 56.83 31.96 3,853.15 3,732.57 2,70.44 1,546.80 2,589,358.58 333,623.15 0.97 3,083.59 MWD +SCC +SAG (2) 5,469.87 57.02 32.39 3,888.16 3,767.58 2,748.94 1,575.42 2,589,403.66 333,652.43 0.63 3,136.44 MWD +SCC +SAG (2) 5,530.90 57.45 32.02 3,921.19 3,800.61 2,792.36 1,602.77 2,589,446.68 333,680.41 0.87 3,186.90 MWD +SCC +SAG (2) 5,594.60 57.53 32.21 3,955.43 3,834.85 2,837.86 1,631.33 2,589,491.76 333,709.62 0,28 3,239.73 MWD +SCC +SAG (2) 5,656.35 57.60 32.36 3,988.55 3,867.97 2,881.92 1,659.17 2,589,535.40 333,738.09 0.23 3,290.95 MWD +SCC +SAG (2) 5,721.45 57.51 32.73 4,023.47 3,902.89 2,928.23 1,688.72 2,589,581.28 333,768.31 0.50 3,344.91 MWD +SCC +SAG (2) 5,783.45 57.19 32.51 4,056.92 3,936.34 2,972.20 1,716.86 2,589,624.83 333,797.08 0.60 3,396.16 MWD +SCC +SAG (2) 5,848.50 56.16 32.67 4,092.66 3,972.08 3,018.00 1,746.14 2,589,670.20 333,827.02 1.60 3,449.53 MWD +SCC +SAG (2) 11/24/2008 10 :48 :09AM Page 4 COMPASS 2003.16 Build 42F S ConocoPhillips or its affiliates Definitive Survey Report Company: ConocoPhillips(Alaska) Inc. Local Co-ordinate Reference: Well NCIU A -14 Project: North Cook Inlet Unit TVD Reference: NCIU A -14 @ 120.58ft (Kuukpik 5) Site: North Cook Inlet Unit MD Reference: NCIU A -14 @ 120.58ft (Kuukpik 5) Well: NCIU A -14 North Reference: True Wellbore: NCIU A -14 Survey Calculation Method: Minimum Curvature Design: NCIU A -14 Database: EDM Alaska Prod v16 Survey Map Map Vertical MD ' Inc Azi TVD • TVDSS +NI-S +El -W Northing Easting DLS Section (ft) ( ( (ft) (ft) (ft) . .(ft) (ft) (ft) ( 1100') (ft) Survey Tool Name 5,912.60 55.84 32.31 4,128.50 4,007.92 3,062.82 1,774.68 2,589,714.60 333,856.21 0_68 3,501.73 MWD +SCC +SAG (2) 5,975.50 55.41 31.89 4,164.02 4,043.44 3,106.80 ` 1,802.27 2,589,758.17 333,884.43 m.88 3,552.78 MWD +SCC +SAG (2) 6,038.95 55.35 31.26 4,200.07 4,079.49 3,151.28 1,829.61 2,589,802.25 333,912.41 0.82 3,604.22 MWD +SCC +SAG(2) 6,102.00 54.99 31.42 4,236.08 4,115.50 3,195.49 1,856.53 2,589,846.06 333,939.98 0_61 3,655.24 MWD+SCC +SAG (2) 6,166.90 54.72 30.42 4,273.44 4,152.86 3,241.01 '1,883.80 2,589,891.18 333,967.89 1_33 3,707.62 MWD+SCC +SAG [,2) 6,228.70 55.15 29.27 4,308.94 4,188.36 3,284.89 1,908.97 2,589,934.68 333,993.69 1_67 3,757.69 MWD +SCC +SAG (2) 6,292.15 55.56 29.19 4,345.01 4,224.43 3,330.44 1,934.46 2,589,979.86 334,019.83 0_65 3,809.44 MWD+6CC +SAG (2) 6,357.15 56.26 29.35 4,381.44 4,260.86 3,377.40 1,960.78 2,590,026,42 334,046.83 1.10 3,862.79 MWD +SAG (2) 6,418.85 56.94 28.79 4,415.41 4,294.83 3,422.42 1,985.81 2,590,071.07 334,072.50 1534 3,913.87 MWD +SCC +SAG (2) 6,482.10 57.85 29.31 4,449.49 4,328.91 3,469.00 2,011.68 2,590,117.27 334,099.05 1560 3,966.71 MWD +SCC +SAG (2) 6,546.50 58.59 29.53 4,483.41 4,362.83 3,516.68 2,038.57 2,590,164.55 334,126.63 1_19 4,020.96 MWD+SCC +SAG (2) 6,610.05 58.19 29.11 4,516.72 4,396.14 3,563.87 2,065.07 2,590,211.35 334,153.81 0_034 4,074.60 MWD+SCC +SAG (2) 6,673.60 57.72 29.14 4,550.43 4,429.85 3,610.92 ' 2,091.29 2,590,258.02 334,180.70 0_74 4,128.01 MWD+SCC +SAG (2) 6,737.40 57.54 28.83 4,584.59 4,464.01 3,658.06 2;117.40 2,590,304.77 334,207.49 0..60 4,181.46 MWD +SCC +SAG (2) 6,802.35 56.92 28.69 4,619.75 4,499.17. 3,705.94 - 2,143.68 2,590,352.26 334,234.46 0 _97 4,235.66 MWD+SCC +SAG (2) 6,863.90 56.79 29.33 4,653.40 4,532.82 3,751.01 '2,168.67 2,590,396.95 334,260.10 0_90 4,286.77 MWD +SCC +SAG (2) 6,926.60 57.07 30.08 4,687.61 4,567.03 3,796.64 '2,194.71 2,590,442.21 334,286.79 1.10 4,338.80 MWD +SCC +SAG (2) 6,988.40 56.47 30.36 4,721.48 4,600.90 3,841.31 2,220.73 2,590,486.49 334,313.45 1.004 4,389.92 MWD +SCC +SAG (2) I 7 56,16 30.34 4,756.67 4,636.09 3,886.87 2,247.40 2,590,531.66 334,340.79 0_49 4,442.11 MWD+SCC +SAG (2) 7,116.75 56.26 30.89 4,792.77 4,672.19 3,933.29 2,274.87 2,590,577.67 334,368.92 072 4,495.39 MWD+SCC +SAG 7,180.90 55.80 31.24 4,828.61 4,708.03 3,978.86 '2,302.32 2,590,622.84 334,397.03 0.85 4,547.88 MWD +SCC +SAG(c'2) 7,243.50 56.61 32.75 4,863.43 4,742.85 4,022.98 2,329.89 2,590,666.54 334,425.23 239 4,599.06 MWD +SCC +SAG (2) 7,306.40 56.72 32.87 4,898.00 4,777.42 4,067.15 2,358.36 2,590,710.29 334,454.34 0524 4,650.62 MWD+SCC +SAG (2) 7,370.65 56.44 33.08 4,933.38 4,812.80 4,112.13 '2,387.55 2,590,754.85 334,484.17 0.51 4,703.21 MWD+SCC +SAG (2) 7,435.60 56.46 33.14 4,969.28 4,848.70 4,157.47 2,417.12 2,590,799.75 334,514.39 0108 4,756.26 MWD +SCC +SAG (2) 7,498.40 56.86 32.25 5,003.79 4,883.21 4,201.63 2,445.46 2,590,843.49 334,543.37 1.34 4,807.76 MWD+SCC +SAG (2) 7,562.85 57.60 31.80 5,038.68 4,918.10 4,247.57 '2,474.20 2,590,889.01 334,572.77 1.29 4,861.07 MWD +SCC +SAG(2) 7,625.20 57.24 31.93 5,072.25 4,951.67 4,292.19 2,501.93 2,590,933.22 334,601.14 0.050 4,912.78 MWD +SCC +SAG (2) 7,688.50 56.76 31.58 5,106.73 4,986.15 4,337.33 2,529.87 2,590,977.95 334,629.73 0.89 4,965.05 MWD +SCC +SAG (2) 7,751.60 57.18 29.30 5,141.13 5,020.55 4,382.94 2,556.67 2,591,023.16 334,657.19 3_ 5,017.32 MWD +SCC +SAG (2) 7,815.40 56.94 28.58 5,175.82 5,055.24 4,429.80 2,582.58 2,591,069.63 334,683.77 1.032 5,070.44 MWD +SCC +SAG (2) 7,878.60 56.39 28.25 5,210.55 5,089.97 4,476.24 2,607.70 2,591,115.70 334,709.56 0.87 5,122.87 MWD +SCC +SAG (2) 7,942.45 57.29 28.01 5,245.47 5,124.89 4,523.37 2,632.90 2,591,162.46 334,735.44 1.44 5,175.99 MWD +SCC +SAG (2) 8,005.80 57.43 26.68 5,279.64 5,159.06 4,570.76 2,657.41 2,591,209.48 334,760.63 178 5,229.07 MWD +SCC +SAG (2) 8,069.35 56.58 23.97 5,314.25 5,193.67 4,618.92 2,680.21 2,591,257.31 334,784.12 3.82 5,282.25 MWD +SCC +SAG (2) 8,132.05 56.02 21.88 5,349.05 5,228.47 4,666.96 2,700.53 2,591,305.05 334,805.14 2.91 5,334,40 MWD +SCC +SAG (2) 8,196.05 55.33 19.13 5,385.14 5,264.56 4,716.46 2,719.04 2,591,354.27 334,824.37 371 5,387.23 MWD +SCC +SAG (2) 8,259.40 54.49 16.60 5,421.56 5,300.98 4,765.79 2,734.95 2,591,403.35 334,840.98 3.53 5,438.95 MWD +SCC +SAG (2) 8,323.55 53.75 14.02 5,459.16 5,338.58 4,815.91 2,748.68 2,591,453.27 334,855.44 3.46 5,490.60 MWD+SCC +SAG (2) 8,387.10 53.59 10.54 5,496.82 5,376.24 4,865.92 2,759.56 2,591,503.12 334,867.05 4.42 5,541.10 MWD +SCC +SAG (2) 11/24/2008 10:48:09AM Page 5 COMPASS 2003.16' Build 42F • • ConocoPhillips or its affiliates Definitive Survey Report Company: ConocoPhillips(Alaska) Inc. Local Co-ordinate Reference: Well NCIU A -14 Project: North Cook Inlet Unit TVD Reference: NCIU A -14 (cry 120.58ft (Kuukpik 5) Site: North Cook Inlet Unit MD Reference: NCIU A -14 ( 120.58ft (Kuukpik 5) Well: NCIU A -14 North Reference: True Wellbore: NCIU A -14 Survey Calculation Method: Minimum Curvature Design: NCIU A-14 Database: EDM Alaska Prod v16 Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/S +El -W Northing Easting DLS Section (ft) (°) ( °) (ft) (ft) (ft) (ft) (ft) (ft) (1100) (ft) . , Survey Tool Name ° 8,450.00 52.68 5.91 5,534.57 5,413.99 4,915.70 2,766.77 2,591,552.78 334,874.97 6.06 5,590.02 MWD +SCC +SAG (2) 8,513.30 51.82 2.58 5,573.33 5,452.75 4,965.60 2,770.49 2,691,602.62 334,879.41 4.38 5,637.76 MWD +SCC +SAG (2) 8,576.92 50.11 2.43 5,613.39 5,492.81 5,014.97 2,772.65 2,591,651.95 334,882.28 2.69 5,684.44 MWD +SCC +SAG (2) 8,640.82 49.64 1.84 5,654.57 5,533.99 5,063.50 2,774.47 2,591,700.74 334,884.81 1.02 5,730.48 MWD +SCC +SAG (2) 8,704.52 49.43 1.96 5,695.91 5,575.33 5,112.23 2,776.07 2,591,749.15 334,887.12 0.36 5,776.09 MWD +SCC +SAG (2) 8,768.37 50.07 2.76 5,737.17 5,616.59 5,160.92 2,778.08 2,591,797.80 334,889.83 1.39 5,822.08 MWD +SCC +SAG (2) 8,831.27 50.20 2.81 5,777.49 5,656.91 5,209.15 2,780.43 2,591,845.98 334,892.88 0.22 5,867.76 MWD +SCC +SAG (2) 8,894.57 49.51 2.42 5,818.30 5,697.72 5,257.48 2,782.64 2,591,894.27 334,895.79 1.19 5,913.49 MWD +SCC +SAG (2) 8,959.12 48.88 2.45 5,860.48 5,739.90 5,306.30 2,784.71 2,591,943.05 334,898.57 0.98 5,959.62 MWD +SCC +SAG (2) 9,022.07 49.05 " 2.75 5,901.81 5,781.23 5,353.73 2,786.87 2,591,990.45 334,901.41 0.45 6,004.50 MWD +SCC +SAG (2) 9,085.37 49.56 3.99 5,943.08 5,822.50 5,401.64 2,789.69 2,592,038.31 334,904.93 1.69 6,050.06 MWD +SCC +SAG (2) 9,149.57 50.56 3.55 5,984.30 5,863.72 5,450.76 2,792.92 2,592,087.37 334,908.87 1.64 6,096.90 MWD +SCC +SAG (2) 9,211.27 51.84 2.58 6,022.96 5,902.38 5,498.77 2,795.49 2,592,135.34 334,912.14 2.41 6,142.47 MWD +SCC +SAG (2) 9,275.27 51.34 2.32 6,062.72 5,942.14 5,548.88 2,797.64 2,592,185.40 334,915.01 0.84 6,189.82 MWD +SCC +SAG (2) 9,337.72 50.90 2.82 6,101.92 5,981.34 5,597.44 2,799.81 2,592,233.93 334,917.89 0.94 6,235.76 MWD +SCC +SAG (2) 9,401.12 50.69 3.64 6,142.00 6,021.42 5,646.49 2,802.58 2,592,282.93 334,921.37 1.06 6,282.36 MWD +SCC+SAG (2) 9,464.62 50.36 3.55 6,182.36 6,061.78 5,695.41 2,805.66 2,592,331.79 334,925.15 0.53 6,328.96 MWD +SCC +SAG (2) 9,528.22 51.13 3.07 6,222.61 6,102.03 5,744.57 2,808.50 2,592,380.91 334,928.70 1.34 6,375.69 MWD +SCC +SAG (2) 9,590.27 51.82 3.07 6,261.26 6,140.68 5,793.05 2,811.10 2,592,429.34 334,932.00 1.11 6,421.70 MWD +SCC +SAG (2) 9,654.47 52.67 2.99 6,300.57 6,179.99 5,843.7'4 2,813.78 2,592,479.98 334,935.42 1.33 6,469.79 MWD +SCC +SAG (2) 9,717.97 51.79 2.87 6,339.46 6,218.88 5,893.38 2,816.35 2,592,530.06 334,938.71 1.39 6,517.33 MWD +SCC +SAG (2) 9,782.57 51.52 3.65 6,379.54 6,258.96 5,944.45 2,819.23 2,592,580.59 334,942.32 1.04 6,565.40 MWD +SCC+SAG (2) 9,845.92 51.72 4.25 6,418.87 6,298.29 5,993.99 2,822.65 2,592,630.07 334,946.46 0.81 6,612.70 MWD +SCC+SAG (2) 9,910.72 50.97 3.94 6,459.34 6,338.76 6,044.46 2,826.26 2,592,680.49 334,950.81 1.22 6,660.94 MWD +SCC+SAG (2) 9,972.42 50.23 3.54 6,498.51 6,377.93 6,092.04 2,829.37 2,592,728.01 334,954.61 1.30 6,706.30 MWD +SCC +SAG (2) 10,036.32 51.44 3.96 6,538.86 6,418.28 6,141.46 2,832.62 2,592,777.39 334,958.57 1.96 6,753.44 MWD +SCC+SAG (2) 10,099.22 52.83 4.69 6,577.47 6,456.89 6,190.99 2,836.36 2,592,826.84 334,963.03 2.39 6,800.84 MWD +SCC +SAG (2) i 10,192.47 51.53 4.54 6,634.65 6,514.07 6,264.41 2,842.29 2,592,900.16 334,970.02 1.40 6,871.25 MWD +SCC +SAG (2) 10,255.42 50.53 4.15 6,674.24 6,553.66 6,313.21 2,846.00 2,592,948.90 334,974.44 1.66 6,917.97 MWD +SCC +SAG (2) 10,313.17 50.30 4.44 6,711.04 6,590.46 6,357.59 2,849.33 2,592,993.23 334,978.41 0.56 6,960.45 MWD +SCC +SAG (2) 10,383.07 52.76 4.06 6,754.52 6,633.94 6,412.17 2,853.39 2,593,047.73 334,983.25 3.54 7,012.66 MWD +SCC+SAG (2) 10,445.67 53.27 3.80 6,792.18 6,671.60 6,462.05 2,856.81 2,593,097.56 334,987.40 0.88 7,060.28 MWD +SCC+SAG (2) 10,499.32 52.77 3.46 6,824.45 6,703.87 6,504.62 2,859.53 2,593,140.29 334,990.74 1.06 7,101.03 MWD +SCC +SAG (2) 10,560.77 51.95 3.16 6,861.98 6,741.40 6,553.46 2,862.34 2,593,188.82 334,994.25 1.39 7,147.22 MWD +SCC +SAG (2) 10,632.57 51.54 2.94 6,906.44 6,785.86 6,609.76 2,865.34 2,593,245.06 334,998.07 0.62 7,200.64 MWD +SCC +SAG (2) 10,694.22 50.86 2.62 6,945.07 6,824.49 6,657.69 2,867.67 2,593,293.01 335,001.09 1.17 7,246.10 MWD +SCC +SAG (2) 10,765.12 51.16 3.14 6,989.67 6,869.09 6,712.73 2,870.44 2,593,348.00 335,004.66 0.71 7,298.27 MWD +SCC +SAG (2) 10,828.32 50.84 3.13 7,029.45 6,908.87 6,761.77 2,873.12 2,593,396.99 335,008.05 0.51 7,344.84 MWD +SCC +SAG (2) 10,891.32 50.16 2.77 7,069.52 6,948.94 6,810.32 2,875.63 2,593,445.50 335,011.26 1.17 7,390.88 MWD +SCC +SAG (2) 10,954.77 49.63 2.46 7,110.39 6,989.81 6,858.80 2,877.84 2,593,493.94 335,014.18 0.92 7,436.75 MWD +SCC +SAG (2) 11/24!2008 10:48:09AM Page 6 COMPASS 2003.16 Build 42F • ConocoPhillips or its affiliates Definitive Survey Report Company: ConocoPhillips(Alaska) Inc. Local Co- ordinate Reference: ' Well NCIU A -14 Project North Cook Inlet Unit TVD Reference: NCIU A -14 @ 120.58ft (Kuukpik 5) Site: ` North Cook Inlet Unit MD Reference: NCIU A -14 @ 120.58ft (Kuukpik 5) Well: NCIU A -14 North Reference: True Wellbore: NCIU A -14 Survey Calculation Method: Minimum Curvature Design: NCIU A -14 Database: EDM Alaska Prod v16 Survey Map Map Vertical MD Inc Azi TVD TVDSS +N /-S +E/-W Northing Easting DLS ' Section (ft) ( ( (ft) (ft) (ft) (ft) (ft) (ft) (1100') (ft) Survey Tool Name 11,018.72 49.12 2.02 7,152.03 7,031.45 6,907.30 2,879.74 2,593,542A0 335,016.78 0.95 7,482.52 MWD +SCC +SAC', (2) 11,082.22 48.27 1.74 7,193.95 7,073.37 6,954.97 2,881.30 2,593,590.04 335,019.03 1.38 7,527.40 MWD +SCC +SAG (2) 11,142.47 47.78 1.25 7,234.24 7,113.66 6,999.75 2,882.47 2,593,634.80 335,020.85 1.01 7,569.44 MWD +SCC +SAG (2) 11,206.27 47.32 0.96 7,277.30 7,156.72 7,046.82 2,883.38 2,593,681.84 335,022.44 0.80 7,613.52 MWD +SCC +SAG (2) 11,269.87 46.92 0.54 7,320.58 7,200.00 7,093.42 2,883.99 2,593,728.43 335,023.73 0.79 7,657.05 MWD +SCC +SAG (2) 11,333.37 46.20 0.35 7,364.24 7,243.66 7,139.52 2,884.35 2,593,774.52 335,024.75 1.15 7,700.03 MWD +SCC +SAG (2) 11,396.61 45.35 0.29 7,408.35 7,287.77 7,184.84 2,884.60 2,593,819.82 335,025.66 1.35 7,742.23 MWD +SCC +SAG (2) 11,458.82 44.49 0.10 7,452.40 7,331.82 7,228.77 2,884.75 2,593,863.74 335,026.45 1.40 7,783.11 MWD +SCC +SAG (2) • 11,501.00 44.49 0.10 7,482.49 • 7,361.91 7,258.33 2,884.80 2,593,89329 • 335,026.93 • 0.00 7,810.60 PROJECTED to TD • I � 11/24!2008 10:48:09AM Page 7 COMPASS 2003.16 Build 42F MECHANICAL ITEGRITY TEST (MIT) FORM WELL NO.: A -14 DATE: 10 / 31 / 2008 WELL TYPE: Prod i,e,: Prod, Prod A/L, MI, SWI, PWI MIT TEST TYPE: 9 -5/8 i.e., Tbg, IA / 9 -5/8 ", OA / 13 -3/8 ", T x IA combo, etc. REQUIRED TEST PRESSURE: 3000 psi. Note: Please consult the PWS if there's any question @ 7224, pager 909. FLUID TYPE(S) USED TO PRESSURE TEST: DrIg Mud 9.2 ppg Record all Wellhead Pressures before and during Test. PRE MIT INITIAL MIT 15 MINUTE 30 MINUTE 45 MINUTE 60 MINUTE PASS T START TIME: 1530 hrs PRESSURES PRESSURES PRESSURES PRESSURES PRESSURES PRESSURES OR E (PSI) (PSI) (PSI)* (PSI)** (PSI)* (PSI)** FAIL S 9 -5/8 csg 0 3000 2995 2995 PASS T IA OA 1 COMMENTS: PRE MIT INITIAL MIT 15 MINUTE 30 MINUTE 45 MINUTE 60 MINUTE PASS T START TIME: PRESSURES PRESSURES PRESSURES PRESSURES PRESSURES PRESSURES OR E (PSI) (PSI) (PSI)* (PSI)** (PSI)* (PSI)** FAIL S TUBING T IA / 9 -5/8" OA / 13 -3/8" 2 COMMENTS: PRE MIT INITIAL MIT 15 MINUTE 30 MINUTE 45 MINUTE 60 MINUTE PASS T START TIME: PRESSURES PRESSURES PRESSURES PRESSURES PRESSURES PRESSURES OR E (PSI) (PSI) (PSI) (PSI) (PSI)* (PSI) ** FAIL S TUBING T IA / 9 -5/8" OA / 13 -3/8" 3 COMMENTS: MISC COMMENTS: * Start the MIT over if press loss is = 5% @ 15 minutes. ** Repeat the MIT if press loss is = 10% @ 30 minutes. Note: Test must exhibit pressure stabilization - press loss second 15 min < 50% press loss first 15 min 45 and 60 minute readings for extended tests only FINAL STEPS MUST BE COMPLETED AND CHECKED OFF!!! -- FLAG THE CASING VALVE WITH LOAD AND TEST INFORMATION -- FLAG THE WING VALVE IF SI AT TIME OF LOADING AND TESTING. -- NOTIFY DSO OF TEST RESULTS, VOLUMES PUMPED AND STATUS OF WELL. David Morrs Witness: cc: PWS 6/3/00 • I Time Lo • • & Summa n oPh�ll� s Log Summary �o oc p Weltv+ew Web 12eporveg Report Well Name: NCI A - 14 Rig Name: KUUKPIK 5 Job Type: DRILLING ORIGINAL Rig Accept: 4/1/2009 4:00:00 AM Rig Release: late TO ; `N Phase ctide code - T•. comment . , „ \ • 08/14/2008 24 hr Summa 20:30 00:00 3.50 SURFA( MOVE OTHR P PJSM and skid to A -10 08/15/2008 Skid rig from A -10 to A -14. Rig up wire line to set PX plug 00:00 01:30 1.50 SURFA( WELCTL OTHR P A -10, Rig up wire line lubricator and test to 1350 PSI. Test OK 01:30 04:30 3.00 SURFA( WELCTL OTHR P RIH with PX plug and set in CMV profile at 4656' MD. 04:30 11:30 7.00 SURFA( WELCTL OTHR T Test plug, test failed. Work plug to try and make it seal. 11:30 12:30 1.00 SURFA( WELCTL OTHR T RIH with AD -Stop. Got stuck at 4259' MD. POOH, at surface we noticed we were missing 1/2 of tool. 12:30 15:30 3.00 SURFA( WELCTL OTHR T RIH to 4259' MD and latch onto fish. Work free, POOH 15:30 18:00 2.50 SURFA( WELCTL OTHR T RIH with GS 4 1/2" Pack off to 4259' MD. Got stuck on the way in at 422' MD 18:00 00:00 6.00 SURFA( WELCTL OTHR T RIH with fishing tool to 422' MD, Latch onto fish and try to work free. Part line. POOH 08/16/2008 Finish with wire line work on A -10. Move to A -14 and rig up. 00:00 07:00 7.00 SURFA( WELCTL OTHR T Retrieve fish, RIH retrieve gs pkf, RIH dd pkf plug, at 4257, RIH 4.5 gs & ad stop 4255. Test / monitor well. Test successful. POH wireline, RD lubricator / risers. 07:00 10:00 3.00 SURFA( MOVE RURD P PJSM, skid over well A -14. 10:00 00:00 14.00 SURFA( DRILL RURD P PJSM, Skid to well A -14. Start A -14 rig up. Install starter head and 20" riser. Set diverter, nipple into flow line and set bell nipple. Set in walkways and stairways. Work on overboard line. Work on cat walk and beaver slide. 08/17/2008 Finish wire line work on A -10, PJSM, Skid to rig A -14. Start A -14 rig up. Install starter head and 20" riser. Set diverter, nipple into flow line and set bell nipple. Set in walkways and stairways. Work on overboard line. Work on cat walk and beaver slide. 00:00 07:30 7.50 SURFA( DRILL RURD P Continue with rig up. Work on overboard line. Finish walkways and stair ways. Change hydraulic ram on link tilt. Finish with cat walk and beaver slide. Start to make up Kick Off BHA Page 1 of 39 • • Time , zkl A From To D i e Su. T Ci -nt 07:30 12:00 4.50 SURFA( DRILL TRIP P Make up BHA #1, Orient bend in motor, install kick pad, make up bit to motor, make up MWD and orient UBHO sub. Change out big, rig tongs. 12:00 20:00 8.00 SURFA( DRILL RURD P Finish modifying flow line, install cellar walk ways, unload 9 5/8" casing from boat, slip and cit drilling line while finishing walkways and install surface loop clamp on top drive. 20:00 20:30 0.50 SURFA( DRILL OTHR P Function test diverter and 16" overboard line valve. Perform Koomey test. All OK. (witnessing was waived by Chuck Sheave, AOGCC) 20:30 23:00 2.50 SURFA( DRILL OTHR T While attempting to fill riser, it was noticed that one of the two 2" collars welded on the 30" conductor was leaking. Stack was drained and collar was rewelded. 23:00 00:00 1.00 SURFA( DRILL TRIP P RIH and tag bottom at 341' MD. 08/18/2008 Finish with A -14 rig up. Function test diverter and overboard line knife valve. Perform Koomey pulldown test, test passed. Make up BHA #1 and RIH to 341' MD. Reweld 2" collar on 30' conductor that was leaking. Spud in at 341' MD KB at 03:00 hrs. Directionaly drill ahead as /per directional plan :After taking the first Gyro survey at 358' MD, it appears that the conductor was set at a one degree angle to the Northwest. This has put well A -14 up against the A -16 traveling cylinder. It appears to be close but should not be bad enough to stop us. Directional drillers are checking with their tech support to verify. 00:00 02:30 2.50 341 341 SURFA( DRILL CIRC P Check all mud lines going to and comming from rig. Circulate old mud out of conductor at 341' MD and dump overboard. Dump sand trap and fill with new mud. Check all mud lines and hold safety meeting before cleaning out conductor. 02:30 06:00 3.50 341 440 SURFA( DRILL DRLG P Spud in at 341' MD KB at 03:00 hrs. Directionaly drill ahead as /per directional plan. After taking the first Gyro survey at 358' MD, it appears that the conductor was set at a one degree angle to the Northwest. This has put well A -14 up against the A -16 traveling cylinder. It appears to be close but should not be bad enough to stop us. Directional drillers are checking with their tech support to verify. 06:00 07:30 1.50 440 440 SURFA( DRILL WOOR T Wait on orders from Sperry Sun in town regarding traveling cylinder encroachment. At 07:30 hrs Sperry Sun in town gave orders to proceed. Page 2 of 39 TaLog , ,,z i I :.Date From To eV ` . S. Depth E. ► rtit` 1eee .Codek: Subcod bb,T Smment....,,,, , § 07:30 12:00 4.50 440 549 SURFA( DRILL DDRL P Drill ahead as /per directional plan, from 440' MD to 549' MD. Take Gyro surveys every 60'. No problems building angle or turning direction with this assembly. Circulate two bottoms up before Gyro Surveys. Hole appears to be in great shape. Hole drag up = 57k, dn = 57K & Rot = 57k. Torque on bottom = 3K, off bottom = 1K. 12:00 00:00 12.00 549 1,047 SURFA( DRILL DDRL P Drill ahead as /per directional plan from 549' MD to 1047' MD. Circulate two bottoms up before Gyro Surveys. Hole appears to be in great shape. At 1047' MD the well was 3.5' off the proposed line at 292 degrees HS. Hole drag up = 57k, dn = 57K & Rot = 57k. Torque on bottom = 3K, off bottom = 1K. 08/19/2008 Spud in at 341' MD KB at 03:00 hrs. Directionaly drill ahead as /per directional plan. After taking the first Gyro survey at 358' MD, it appears that the conductor was set at a one degree angle to the Northwest. This has put well A -14 up against the A -16 traveling cylinder. It appears to be close but should not be bad enough to stop us. Drill ahead as /per directional plan. Take Gyro surveys every 60'. No problems building angle or turning direction with this assembly. Circulate two bottoms up before Gyro Surveys. Hole appears to be in great shape. At 1200' MD the well is 5.2' off the proposed line at a 179 degrees HS. Hole drag up = 59K, dn = 59K & Rot = 59K, Rotary torque off bottom = 3K, on bottom = 2K. 00:00 12:00 12.00 1,047 1,519 SURFA( DRILL DRLG P Drilling ahead as /per directional plan from 1047' MD to 1519' MD. At 1500' MD the well is 3.64' off the proposed line at 92 degree HS. Having no problems building angle or turning direction. Hole drag up = 59K, dn = 59K & Rot = 59K, Rotary torque off bottom = 3K, on bottom = 2K. 12:00 00:00 12.00 1,519 2,282 SURFA( DRILL DDRL P Drilling ahead as /per directional plan from 1519' MD to 2282" MD. At 2280' MD the well is 7 feet off of the proposed path at 178 degree HS. Having no problems with directional control, motor producing 9 degree DLS's. No hole problems either. Hole drag up = 62K, Dn = 61K, & Rot = 62K. Off Bottom torque = 3K, On bottom = 5K. 08/20/2008 Drilling ahead as /per directional plan from 2282' MD to 2475' MD. Directional objective meet at 2475' MD. At 2475' MD the well is 9.8' feet off of the proposed path at -150 degrees HS. Having no problems with directional control, motor producing 8 degree DLS's and is easy to slide. No hole problems either. Hole Drag Up = 77K Dn = 60K & Rot = 67K. Off Bottom Torque = 7K, On Bottom Torque = 6K. Projected on Bottom Angle = 58 degrees with a Direction of N30E. Pump sweep at 2471' MD and circulate bottoms up. BROOH @ 40 -50 ft/min, at 475 GPM's - 60 RPM's to 1000'. POOH on elevators. Breakout & lay down BHA #1. MU BHA #2 with a 1.15 deg motor assembly. TIH. I Page 3 of 39 Time Logsik s r,5 Date From To ° N. S. Depth .:E. neotilPhase Gods* ..tcodl� \..€rrr a nt. : . 00:00 04:15 4.25 2,282 2,475 SURFAC DRILL DDRL P Drilling ahead as /per directional plan from 2282' MD to 2475' MD. Directional objective meet at 2475' MD. At 2475' MD the well is 9.8' feet off of the proposed path at -150 degrees HS. Having no problems with directional control, motor producing 8 degree DLS's and is easy to slide. No hole problems either. Hole Drag Up = 77K Dn = 60K & Rot = 67K. Off Bottom Torque = 7K, On Bottom Torque = 6K. Projected on Bottom Angle = 58 degrees with a Direction of N30E. 04:15 05:30 1.25 2,475 2,475 SURFA( DRILL CIRC P Circulate sweep arround to clean hole for trip out. 05:30 10:00 4.50 2,475 1,015 SURFA( DRILL TRIP P Back ream while POOH F/ 2475' MD -1015' MD @450gpm's -60 RPM, pulling speed - 40 ft/min. Minor tight spots at 2000' to 1850', 1680' to 1620', 1550' to 1520' and 1485' to 1445'. Reamed them one time and they were gone. No packing off observed while POOH 10:00 10:30 0.50 1,015 1,015 SURFA( DRILL CIRC P Circulate and condition mud 10:30 11:30 1.00 1,015 190 SURFA( DRILL TRIP P POOH to 190' MD. No tight spots 11:30 19:00 7.50 190 0 SURFA( DRILL TRIP P Swap out rig tongs change out BHA. Change MWD and mud motor. Set motor bend to 1.15 degrees. 19:00 20:00 1.00 0 0 SURFA( RIGMNT SVRG P Service rig and top drive. Tighten turn buckles on torque tube. Install spiral wrap on top drive service loop outside derrick. 20:00 00:00 4.00 0 2,310 SURFA( DRILL TRIP P RIH to 2310' MD. No tight spots and the hole gave back the right amount of fluid. Stop and fill pipe at 1481' MD. 08/21/2008 Back ream while POOH F/ 2475' MD - 1015' MD @ 450 GPM with 60 RPM, pulling speed _ 40 ft/min. Minor tight spots at 2000' to 1850', 1680' to 1620', 1550' to 1520' and 1485' to 1445'. Reamed them one time and they were gone. No packing off observed while POOH. Finish POOH and change BHA. Put motor bend at 1.15 degrees and change out MWD. RIH to 2310' MD with no tight spots, and no fill. The hole gave back the right amount of fluid. At 2529' MD the #1 rig generator burnt up. Back up generator was put on line and drilling continued. Drill from 2529' MD to 2688' MD. Hole drag Up = 82K, Dn = 62K and Rot = 66K. Rotary Torque = 7K On Bottom and 6K On Bottom. 00:00 00:30 0.50 2,310 2,475 SURFA( DRILL TRIP P RIH from 2310' MD to 2475' MD, No tight hole or fill. 00:30 01:00 0.50 2,475 2,529 SURFA( DRILL DDRL P Drill from 2475' MD to 2529' MD. 01:00 01:30 0.50 2,529 2,529 SURFA( RIGMNT RGRP T Number 1 rig generator failed. Troubleshoot problem. Take generator offline. Reasign other generators to run rig. Page 4 of 39 _ � .t4� `" x sr : s Y l: hese �� ? \ \ \O\ `3,`'., mot .. Time Logs Date :. :... From :Depth E:. ',.•ode T �... \ 01:30 12:00 10.50 2,529 3,071 SURFA( DRILL DDRL P Drill from 2529' MD to 3071' MD. Hole drag Up = 90K, Dn = 55K and Rot = 72K. Rotary Torque = 11K On Bottom and 10K On Bottom. No problems sliding motor, motor produced 4 degree DLS's 12:00 00:00 12.00 3,071 3,961 SURFA( DRILL DDRL P Drill from 3071' MD to 3961' MD. Hole drag Up = 104K, Dn = 55K and Rot = 72K. Rotary Torque = 11K On Bottom and 10K On Bottom. No problems sliding motor, motor produced 4 degree DLS's. 08/22/2008 RIH from 2310' MD to 2475' MD, No tight hole or fill. Drill from 2475' MD to 2529' MD. Number 1 rig generator failed. Troubleshoot problem. Take generator offline. Reasign other generators to run rig. Drill from 2529' MD to 3961' MD. Hole drag Up = 104K, Dn = 55K and Rot = 72K. Rotary Torque = 11K On Bottom and 10K On Bottom. No problems sliding motor, motor produced 4 degree DLS's. Drill from 3961' MD to 4340' MD. Hole drag Up = 106K, Dn = 64K and Rot = 76K. Rotary Torque = 12K On Bottom and 9K On Bottom. No problems sliding motor, motor produced 4 degree DLS's. Traveling cylinder coordinates at 4230' are 18 ft at 59 degree TF. Directional drill to TD at 4755' MD, 3490' TVD as per Geologist. Circulate Hi- visc nut plug sweep, and BRROH from TD - 2141' MD. 00:00 05:30 5.50 3,961 4,340 SURFA( DRILL DRLG P Drill from 3961' MD to 4340' MD. Hole drag Up = 106K, Dn = 64K and Rot = 76K. Rotary Torque = 12K On Bottom and 9K On Bottom. No problems sliding motor, motor produced 4 degree DLS's. Traveling cylinder coordinates at 4230' are 18 ft at 59 degree TF. 05:30 11:30 6.00 4,340 4,756 SURFA( DRILL DRLG P Continue directional drill from 4340' - 4756' MD, 3490' ND, TD called as per Geologist. 11:30 14:00 2.50 4,756 4,756 SURFA( DRILL CIRC P Mix & pump Hi visc sweep with nut plug @ 550 GPM's 2100 PSI while reciprocate & rotate drill string. 14:00 22:00 8.00 4,756 4,756 SURFA( DRILL REAM P BROOH from TD to 2141' MD. with a pulling rate of 30 -50 ft/minute. Observed good hole conditions. 22:00 22:30 0.50 4,756 4,756 SURFA( DRILL TRIP P Service rig and top drive. 22:30 00:00 1.50 4,756 4,756 SURFA( DRILL TRIP P RIH from 2141' MD to 3771' MD. No hole problems. Hole gave back the right amount of fluid. 08/23/2008 Drill from 3961' MD to 4756' MD. Hole drag Up = 106K, Dn = 64K and Rot = 76K. Rotary Torque = 12K On Bottom and 9K On Bottom. No problems sliding motor, motor produced 4 degree DLS's. Traveling cylinder coordinates at 4756' MD are 4.7 ft at 10.4 degrees TF. Mix & pump Hi vis sweep with nut plug @ 550 GPM's 2100 PSI while reciprocate & rotate drill string. BROOH from TD to 2141' MD. with a pulling rate of 30 -50 ft/minute. Observed good hole conditions. RIH from 2141' MD to 4184' MD. No hole problems. Hole gave back the right amount of fluid. RIH picking up drill pipe from 4184' MD to 4756' MD. Circulate hole clean at 4756' MD. Pump at 600 GPM with 110 rotary RPM. Pump a 25 barrel nut plug - high vis sweep. Pull 5 stands. observe well, pump slug and POOH. 00:00 00:30 0.50 4,756 4,756 SURFA( DRILL TRIP P RIH from 3771' MD to 4184' MD. No tight spots and the hole gave back the right amount of fluid. 00:30 02:30 2.00 4,756 4,756 SURFA( DRILL TRIP P RIH picking up drill pipe from 4184' MD to 4756' MD. Page 5 of 3 • .Date. Frtai oTo � \ \O 'ur..` :,.,moth: E. Wirth Phase Suboode ' T . ' ' Comment 02:30 04:30 2.00 4,756 4,756 SURFA( DRILL CIRC P Circulate hole clean at 4756' MD. Pump at 600 GPM with 110 rotary RPM. Pump a 25 barrel nut plug - high vis sweep. 04:30 11:30 7.00 4,756 4,756 SURFA( DRILL TRIP P Pull 5 stands. observe well, pump slug and POOH to 573' MD. No tight hole, hole took the right amount of fluid. 11:30 17:00 5.50 4,756 4,756 SURFA( DRILL TRIP P Change out small rig tongs fort big ones. Dump MWD data ans lay down all of BHA #2. 17:00 19:00 2.00 4,756 4,756 SURFA( CASING RURD P Clean floor and rig up casing running equipment. Pick up bail extender. 19:00 20:30 1.50 4,756 4,756 SURFA( CASING OTHR P Make up landing joint, and make dummy run. Landing joint sets at 49.5 feet 20:30 00:00 3.50 4,756 4,756 SURFA( CASING RNCS P PJSM, Make up shoe, two joints of casing, sting in float collar and two joints of casing. Fill with mud and test. Test OK. RIH with 9 5/8" casing to 247' MD. 08/24/2008 Finish POOH with BHA #2, Dump MWD data and lay down entire BHA. PJSM, Rig up and run casing. RIH with 9 5/8" casing from 0' MD to 1498' MD. No tight spots and the hole gave back the right amount of fluid. Pick up weight at 1498' MD was Up 74K, Dn 45K. At 1495' MD break circulation at 1 barrel per /minute, then slowly bring up to 6 bbls /min. PSI at 6 bbls /min was 140 lbs. Circulate one bottoms up. Continue RIH with casing from 1495' MD to 2001' MD. No problems, hole giving back the right amount of fluid. Drag Up = 107K, Down = 42K. Circulate bottoms up, no problems. Continue running casing from 2001' MD to 3498' MD. No problems, hole giving back the right amount of fluid. Drag Up= 158K, Dn = 38K. Circulate bottoms up, no problems. Continue running casing from 3498' MD to 4136" MD. No Problems, hole gave back the right amount of fluid. Drag Up = 190K, Dn = 38K. Circulate bottoms up, no problems. Continue running casing from 4136' MD to 4747' MD and land hanger. No problems, hole gave back the right amount of fluid. Drag Up = 210K, Dn = 40K. Condition mud and circulate. Start circulating at one barrel per /min, then slowly work up to six barrels per /min. Estimated mud loss for entire casing job was 3 barrels per /hour. 00:00 04:30 4.50 4,756 4,756 SURFA( CASING RNCS P RIH with 9 5/8" casing from 247' MD to 1498' MD. No tight spots and the hole gave back the right amount of fluid. Pick up weight at 1495' MD was Up 74K, Dn 45K. 04:30 05:00 0.50 4,756 4,756 SURFA( CASING CIRC P At 1495' MD. Break circulation at 1 barrel per /minute, then slowly bring up to 6 bbls /min. PSI at 6 bbls /min was 140 lbs. 05:00 06:00 1.00 4,756 4,756 SURFA( CASING RNCS P RIH with casing from 1495' MD to 1835' MD 06:00 07:00 1.00 4,756 4,756 SURFA( RIGMNT RGRP T Circulate while tightening loose clamp on bail extension, retie wires. 07:00 09:00 2.00 4,756 4,756 SURFA( CASING RNCS P Continue RIH with casing from 1835' MD to 2001' MD. No problems, hole giving back the right amount of fluid. Drag Up = 107K, Down = 42K. 09:00 10:00 1.00 4,756 4,756 SURFA( CASING CIRC P Circulate bottoms up, no problems. 10:00 12:30 2.50 4,756 4,756 SURFA( CASING RNCS P Continue running casing from 2001' MD to 3498' MD. No problems, hole giving back the right amount of fluid. Drag Up= 158K, Dn = 38K. 12:30 13:30 1.00 4,756 4,756 SURFA( CASING CIRC P Circulate bottoms up, no problems. Page 6 of 39 • • . ' ®_ ; .., 0 " rn. : °A LUi -1111, - Code 617k::::°' T Corn' ". 13:30 15:00 1.50 4,756 4,756 SURFA( CASING RNCS P Continue running casing from 3498' MD to 4136" MD. No Problems, hole gave back the right amount of fluid. Drag Up = 190K, Dn = 38K. 15:00 16:00 1.00 4,756 4,756 SURFA( CASING CIRC P Circulate bottoms up, no problems. 16:00 18:30 2.50 4,756 4,756 SURFA( CASING RNCS P Continue running casing from 4136' MD to 4747' MD, land hangerat at 18:30 hrs. No problems, hole gave back the right amount of fluid. Drag Up = 210K, Dn = 40K. 18:30 22:00 3.50 4,756 4,756 SURFA( CASING CIRC P Condition mud and circulate. Start circulating at one barrel per /min, then slowly work up to six barrels per /min. Estimated mud loss for entire casing job was 3 barrels per /hour. 22:00 23:30 1.50 4,756 4,756 SURFA( CASING RURD P Pull 9 5/8" casing pup from landing joint. Lay down elevators and bail extender, rig up drill pipe elevators and install rig floor mats. 23:30 00:00 0.50 4,756 4,756 SURFA( CEMEN" CIRC P Rig up cement stinger, 3 centralizer on drill pipe and run in hole. 08/25/2008 Pick up and run 9 5/8" casing, land at 4747' MD. RIH with cement stinger on drill pipe. Stab into float collar and break circulation. Rig up and test cement lines to 3000 PSI, Test OK. Mix and pump 1310 sacks of type 1 cement. Cement in place at 09:00 hrs. No lost returns during cement job. Seventy barrels of cement returned to surface. Unsting from float collar, shoe track holding. Circulate casing clean, POOH and lay down cement stinger. 00:00 04:00 4.00 4,756 4,756 SURFA( CEMEN" TRIP P RIH with cement stinger on Drill Pipe to float collar at 4665' MD. 04:00 04:30 0.50 4,756 4,756 SURFA( CEMEN" TRIP P Space out with stinger & install pups. Sting into FC. 04:30 05:00 0.50 4,756 4,756 SURFA( CEMEN" CIRC P Rig up lines. Break circulation. Stage to 6 BPM - 400 PSI. 05:00 05:30 0.50 4,756 4,756 SURFA( CEMEN" SFTY P Held PJSM with crew & BJ Cementing crew. Discuss Safety & Hazard Recognition issues. Discuss cementing procedure. Designate Spill Champion. 05:30 09:30 4.00 4,756 4,756 SURFA( CEMEN" CIRC P Pressure test lines. Pump 20 BBLS Mud Clean II, Turn over to BJ. Pump 2 BBLS of water. Pressure test lines to 3000 PSI. Continue mix & pump 1310 sacks of 12.0 PPG cement staging to 6 BPM. No loss returnes during cement job. 70 barrels of cement returned to surface. 09:30 16:00 6.50 4,756 4,756 SURFA( CEMEN" CIRC P Unsting from float collar, pump wiper ball down drill pipe and circulate till hole was clean. Pump second wiper ball and circulate 9 5/8" casing clean. 16:00 16:30 0.50 4,756 4,756 SURFA( CEMEN" OTHR P Change out elevators and bails. 16:30 22:00 5.50 4,756 4,756 SURFA( CEMEN" TRIP P POOH with drill pipe and lay down cementing string. 22:00 00:00 2.00 4,756 4,756 SURFA( CEMEN" OTHR P Lay down landing joint Page 7 of 39 Date c * 4 %rn To Dur S. Depth E. Depth Phase Code Sub , Co rnt , . y.. „ . • 08/26/2008 24 hr Su Finish nipple down A 14 & set wellhead. Move to A 10 & load boat. 00:00 12:00 12.00 0 0 SURFA( MOVE RURD P Hold PJSM. Lay down landing joint. Finction & flush annular preventer. Clear & clean rig floor. Wash cellar & stack. Remove mouse hole & pipe ramp. Clean pits & nippkle down surface equipment. Pull diverter & knife valve.Unhook mud lines & riser pipe. Continue cleaning pits while preparing for rig move. 12:00 18:00 6.00 0 0 SURFA( MOVE MOB P Finish nipple down 20" riser. Nipple up A 14 well head & test to 5000 psi. 18:00 20:00 2.00 0 0 MIRU MOVE MOB P Prepare rig to skid & skid rig from A 14toA10. 20:00 00:00 4.00 0 0 MIRU MOVE MOB P Back load boat with surface tools & clean up cellar area. 08/27/2008 Finish loading boat. Rig up pollard wireline & Slick line work. 00:00 02:30 2.50 0 0 MIRU MOVE RURD P PJSM= Continue to clear deck of all surface equipment on boat. 02:30 04:00 1.50 0 0 MIRU MOVE RURD P Rig up pollard wireline. 04:00 06:00 2.00 0 0 MIRU WELCTI BOPE P Test lubricator to 1100 psi & RIH w/ bailer to 4255'. POH. 06:00 07:00 1.00 0 0 MIRU WELCTL OTHR P Run #2 -RIH w/ 4 1/2" GS, to 4255' Latched & POH w/ top Stop. 07:00 08:00 1.00 0 0 MIRU WELCTL OTHR T Run #3 -RIH w/ 4 1/2" GS to top plug @ 4256'. Shear out & POH. 08:00 10:00 2.00 0 0 MIRU WELCTL OTHR T Run #4 -RIH w/ Same to plug @ 4256' shear out & POH. 10:00 10:30 0.50 0 0 MIRU WELCTI OTHR T Change out oil jars from 1 1/4" to 1 /1/2 ". 10:30 11:30 1.00 0 0 MIRU WELCTI OTHR T Run #5 -RIH w/ 1 1/2" oil jars & 4 1/2" GS, tag @ 4248' shear out & POH. 11:30 12:00 0.50 0 0 MIRU WELCTI OTHR T Run #6 -make up 5' weight bar & RIH w/ same as #5. 12:00 15:00 3.00 0 0 MIRU WELCTL OTHR T Finish run #6 Retrieve plug. 15:00 16:00 1.00 0 0 MIRU WELCTL OTHR T Run #7 & shear out. 16:00 18:00 2.00 0 0 MIRU WELCTL OTHR T Rerun #7. Wire line parted. Wait on fishing tools for wireline work. 18:00 00:00 6.00 0 0 MIRU WELCTL OTHR P While waiting on fishing tools =Bolt up annular preventer to upper gate & mud cross to lower gate. Back load boat. Change liners in mud pumps. 4 1/2" liners in #1 pump & 5 1/2' liners in #2 pump. Put turnbuckles on torque tube. 08/28/2008 Rig maintenance. Rig up & fish wireline & plugs. 00:00 06:00 6.00 0 0 MIRU WELCTL OTHR P Hammer up bolts on BOP,S- valves- DSA flange to riser, while waiting on wireline fishing tools. 06:00 10:00 4.00 0 0 MIRU WELCTL OTHR P Building mud for drlg. rig maintenance & house keeping. 10:00 11:30 1.50 0 0 MIRU WELCTL OTHR T PJSM =rig up pollard wireline unit. Page 8 of 39 • rime Le rom. To. � th f=7 'Phase Code ° _ ' �lt� 3Gt3f�e T CorilrT ° " 11:30 12:30 1.00 0 0 MIRU WELCTL OTHR T RIH with wireline grab. Catch wireline. 12:30 14:00 1.50 0 0 MIRU WELCTL OTHR T Lace wireline thru sheaves. 14:00 18:30 4.50 0 0 MIRU WELCTL OTHR P Rig up E -Line. RIH. Catch Stop & POH retrieve same. 18:30 00:00 5.50 0 0 MIRU WELCTL OTHR T RIH with prong catcher. POH. misrun. RIH w/ bailer. Estimated sand op top of prong. 08/29/2008 Finish wireline work & prep for rig move. 00:00 06:00 6.00 0 0 MIRU WELCTL OTHR T Continue with wireline operations running in hole with bailer. Recovered no sand. Running in hole with JDC tool. ( Jar down type 'C' tool.) to recover prong. 4 runs. 06:00 08:00 2.00 0 0 MIRU WELCTL OTHR T RIGH w/ bailer. 2 runs. 08:00 09:30 1.50 0 0 MIRU WELCTL OTHR P RIH w/ JDC. Latch up & POH w/ prong. 09:30 11:00 1.50 0 0 MIRU WELCTL OTHR T RIH w/ 4 1/2" GS & POH. 11:00 13:00 2.00 0 0 MIRU WELCTL OTHR T Lay down GS pick up Bailer & RIH. POH w/ bailer 13:00 15:00 2.00 0 0 MIRU WELCTL OTHR T RIH w/ GS tool 2 runs. No luck. 15:00 18:00 3.00 0 0 MIRU WELCTL OTHR P RIH w/ vacum bailer. 2 runs. RIH w/ GS tool. POH retrieved plug. 18:00 18:30 0.50 0 0 MIRU WELCTL OTHR P Rig down wireline tools & lubricator. 18:30 21:00 2.50 0 0 MIRU MOVE DMOB P PJSM- Prepare rig for moving from A -10 to A -15. ( Release rig from A -14 @ 21:00 hrs. 8- 29 -08) 10/31/2008 Skid rig from A -16 to A -14. Rig up. NU and test BOP's. ACCEPT KUUKPIK RIG 5 THIS DATE 0400 HRS. 00:00 04:00 4.00 0 0 MIRU MOVE RURD P Skid from A -16 to A -14. RU over well. ACCEPT KUUKPIK RIG 5 THIS DATE 0400 HRS 04:00 06:00 2.00 0 0 MIRU WELCTL NUND P PJSM, remove temp tree. RU riser. 06:00 15:30 9.50 0 0 MIRU WELCTL NUND P PJSM, NU BOPE. Make all component connections, charge accumulator. Function test BOPE. 15:30 16:30 1.00 0 0 MIRU CASING DHEQ P Close blind rams. test 9 -5/8 csg 3000 psi / 30 min. Test successful, no re -tests 16:30 00:00 7.50 0 0 MIRU WELCTL BOPE P Drain stack. RU test plug. Test BOP's to 250 psi low / 3500 psi high. Test PVT alarms, flow alarms, gas detectors. Had one gas detector fail test (must be working before drilling out in open hole). 11/01/2008 PU and TIH with BHA. Drilled float collar, cement, float shoe. Drilled 20' of new formation. Circulate and condition mud for LOT. 00:00 01:30 1.50 0 0 MIRU WELCTL BOPE P Pull test plug, set wear ring, blow down and line up choke. 01:30 02:00 0.50 0 0 MIRU RIGMNT SVRG P Adjust hoses on top drive and inspect drill line. 02:00 06:00 4.00 0 0 PROD1 DRILL TRIP P Make up BHA. Upload MWD. Page 9 of 39 Oa , From . T..: Our S: 2 .11: (` ' : bcode T ; ' ment 06:00 15:30 9.50 0 4,660 PROD1 DRILL TRIP P TIH. Circulate mud every 1000 ft. Inspect drill line. 15:30 16:00 0.50 4,660 4,667 PROD1 DRILL CIRC P Wash to float collar at 4667' MD. Circulate bottoms up. 16:00 17:30 1.50 4,667 4,756 PROD1 CEMEN COCF P Drill float collar at 4667' MD, cement, and float shoe at 4747' MD. Clean out hole to 4756' MD. Drill to 4776' MD. Samples did not indicate new formation being drilled. Drilled to 4796' MD. Rot trq 10/14k float collar. Rot trq 10/13k float shoe. Rot trq 9/12k new hole. PU wt 110k. Rot wt 80k. Slack off wt 65k. 17:30 18:00 0.50 4,756 4,796 PROD1 DRILL DDRL P Drilled from 4756' to 4796' 18:00 00:00 6.00 4,796 4,796 PROD1 DRILL CIRC P Circulate hole clean. Displace hole with 9.2 ppg mud. Circulate at 415 GPM. Rotate at 10 RPM. Circulate and condition mud for LOT. 11/02/2008 LOT 16.6 ppg MWE. Directionally drilling 8 -3/4" hole from 4796' MD to 6108' MD. 00:00 01:30 1.50 4,796 4,796 PROD1 DRILL CIRC P Circulate and condition mud for LOT. 01:30 02:00 0.50 4,796 4,796 PROD1 DRILL LOT P Prep for LOT. Pressure up on formation for LOT. Formation leaked off at 16.6 ppg MWE. 02:00 12:00 10.00 4,796 5,537 PROD1 DRILL DDRL P Directionally drilling 8 -3/4" hole from 4796' to 5537' MD (3924' TVD). AST = 0.94. ART = 5.42. ADT = 6.36. Jar hrs = 6.36. Up wt = 109k. Down wt = 67k. Rot wt = 84k. Pressure = 1900 psi off, 2100 psi on @ 510 GPM. Torque = 10k off, 11k on @ 90 RPM w/ 4k bit wt. Max gas = 750 u. 12:00 00:00 12.00 5,537 6,108 PROD1 DRILL DDRL P Directionally drilling 8 -3/4" hole from 5537' to 6108' MD (4245' TVD). AST = 1.8. ART = 3.82. ADT = 5.62. Jar hrs = 11.98. Up wt = 120k. Down wt = 70k. Rot wt = 88k. Torque = 11k. Max gas 900 u @ 5725' MD. ECD = 10.3 ppg. 11/03/2008 Directionally drill 8 -3/4" hole from 6108' to 6742' MD. Hold safety meeting. Directionally drill 8 -3/4" hole from 6742' to 7058' MD. Weight up mud to 9.6 ppg. Repair rig. Directionally drill 8 -3/4" hole from 7058' to 7283' MD. 00:00 09:00 9.00 6,108 6,742 PROD1 DRILL DDRL P Directionally drill 8 -3/4" hole from 6108' to 6742' MD. 09:00 10:00 1.00 6,742 6,742 PROD1 DRILL SFTY P Circulate well and hold safety meeting. • Page 10 of 39 • \e y T o . Dur S. Math.. `1st: Phase Code Subcxxe /NaAv Comment 10:00 12:00 2.00 6,742 6,870 PROD1 DRILL DDRL P Directionally drill 8 -3/4" hole from 6742' to 6870' MD (4657' ND). AST = 1.76. ART = 4.97. ADT = 6.73. Jar hrs = 18.71. Up wt = 120k. Down wt = 74k. Rot wt = 90k. Pressure = 2150 psi off / 2260 psi on at 510 GPM. Torque = 11k on / 10 k off at 90 RPM w/ 4 - 5k on bit. Checking flow each connection. Inspected drill line. 12:00 16:00 4.00 6,870 7,058 PROD1 DRILL DDRL P Directionally drill 8 -3/4" hole from 6870' to 7058' MD. 16:00 16:30 0.50 7,058 7,058 PROD1 DRILL CIRC P Check well for flow. Circulate out gas spike (1200 u). Weight up mud from 9.4 to 9.6 ppg. 16:30 17:00 0.50 7,058 7,058 PROD1 RIGMNT RGRP T Trouble shoot electrical controls on mud pump #2 (Throttle switch stuck). 17:00 18:30 1.50 7,058 7,058 PROD1 RIGMNT RGRP T Attempt to orientate for slide. Pipe grabber not functioning on top drive. Touble shoot pipe grabber electrical controls. (Loose wire) 18:30 00:00 5.50 7,058 7,283 PROD1 DRILL DDRL P Directionally drill 8 -3/4" hole from 7058' to 7283' MD (4896' ND). AST = 1.56. ART = 3.53. ADT = 5.09. Jar hrs = 23.8. Up wt = 127k. Down wt = 75k. Rot wt = 96k. Pressure = 2246 psi off / 2530 psi on at 512 GPM. Torque = 11 - 12k on / 10 off at 85 RPM w/ 5k on bit. Max gas = 1124 u. Check flow every connection. Inspect drill line. 11/04/2008 Continue directional drill 8 -3/4" hole from 6870' to 77884' MD. Circulate hole clean. Attempt to POOH on elevators. BROOH to 6425' MD. Work through cuttings beds. Observed no gas, proper fluid displacement. Drilling line inspection. 00:00 11:00 11.00 7,283 7,729 PROD1 DRILL DDRL P Directionally drill 8 -3/4" hole from 7283' to 7529' MD. 11:00 11:30 0.50 7,729 7,729 PROD1 RIGMNT RGRP T PJSM, C/O piston mud pump #1 11:30 15:00 3.50 7,729 7,884 PROD1 DRILL DDRL P PJSM, resume drill ahead 8 -3/4 hole drctnl 7729 -7884 AST = 2.41, ART = 8.11, Up 127, Dn 77, Rot 95, RPM 90, WOB 5 -6, SPP 2620 / 2725, GPM 510 15:00 16:00 1.00 7,884 7,884 PROD1 DRILL CIRC P CBU for wiper trip, cuttings return normal quantity / quality. Cont circ shaker clean. Page 11 of 39 • Date lk;;itik E .,•! ji s l; Comment 16:00 00:00 8.00 7,884 6,425 PROD1 DRILL REAM P PJSM, flow check, POH wiper trip trip to csg shoe. Attempt tp POOH on elevators observing excessive drag & overpull. Continue BROOH @ 15 -25 ft/minute from 7450' - 6425. Observed hole unloading with pump rates at 510 GPM's and rotating at 60 RPM's as per Directional Driller, reaming through cuttings beds twice, working through "ratty" hole in the formation transition at 4250' TVD. Observed ECD's dropping from 11.4 PPG to 10.4 PPG with no gas observed. Mud wt = 9.6 PPG. No Fluid loss. 11/05/2008 Continue BROOH from 6425' to shoe @ 4747" MD. Work through cuttings beds. Observed no gas, proper fluid displacement. Slip & cut 80' of drilling line. Perform Top Drive trouble shooting work, repairing faulty electrical connector. Adjust bales on link tilt. Service rig. TIH from shoe @ 4747' to 7884 with no issues and proper displacement. Continue directional drill 8 3/4" hole from 7884' - 7921' MD. TVD = 5310'. Perform Drilling line ins ?ection. 00:00 03:30 3.50 6,425 4,747 PROD1 DRILL REAM P Held Pre -tour meeting. Continue BROOH @ 15 -25 ft/minute from 6425' to shoe at 4747' MD'. Observed hole unloading with pump rates at 510 GPM's and rotating at 60 RPM's as per Directional Driller, reaming through cuttings beds twice.Observed ECD's at 10.35 PPG with no gas observed. Mud wt = 9.6 PPG. No Fluid loss. Pull last 5 stands slower to aid in getting bottoms up and clean hole before bit at the shoe. 03:30 04:00 0.50 4,747 4,747 PROD1 DRILL CIRC P Continue CBU until hole clean @ 510 GPM's - 2200 PSI. Reciprocate & rotate drill string. 04:00 06:00 2.00 4,747 4,747 PROD1 RIGMNT SVRG P Held PJSM. Discuss safety & hazard recognition issues. Discuss procedure to slip & cut drilling line, and inspection of same. Rig up, hang blocks, and perform slip & cut of 80'. Inspect drilling line. 06:00 18:00 12.00 4,747 4,747 PROD1 RIGMNT RGRP T PJSM, flow check, troubleshoot / repair top drive. Find water filled plug & receptacle "J" box at top drive. Disassemble, blow dry all components. Run in top drive, test all functions. OK. Re -seal all water tight connections. Adjust link tilt bale. Service Rig. 18:00 21:30 3.50 4,747 7,884 PROD1 DRILL TRIP P Trip in hole from the shoe @ 4747', to 7884'. Wash down last stand. Observed good hole conditions with no issues. Fill drill string every 1000', with proper displacement. Page'12of3 S Ting Our S. Depth E. Depth Ph Cod Bode T. Cent Dot From To .. �. ,;...., <, ....:. 21:30 00:00 2.50 7,884 7,981 PROD1 DRILL DDRL P Obtain parameters, Continue directional drill 8 -3/4" hole from 7884' to 7981' MD (5310' TVD). AST = .67 ART = .69. ADT = 1.36. Jar hrs = 35.68. Up wt = 140k. Down wt = 85k. Rot wt = 106k. Pressure = 2730 psi off / 2800 psi on at 520 GPM. Torque = 11 - 12k on/ 10 off at 100 RPM w/ 5 -6K wt on bit. Max gas = 192 Units. ECD = 10.5 PPG. Check flow every connection. Perform Drilling line inspection. Crew Change 11/06/2008 Continue directional drill 8 3/4" hole from 7981' - 8965' (984') TVD = 5765'. Repair dresser sleeve in flowline. Performed drilling line inspection. 00:00 12:00 12.00 7,981 8,480 PROD1 DRILL DDRL P Continue directional drill 8 -3/4" hole from 7981' - 8480' MD (5435' ND). AST = 5.61 ART = 2.93 ADT = 8.57 Jar hrs = 44.22 HRS Up wt = 143k. Down wt = 87K. Rot wt = 107k. Pressure = 2870 psi off / 2970 psi on at 520 GPM. Torque = 12 -13k on / 12 off at 100 RPM w/ 6 -7K wt on bit. Max gas = 225 Units. ECD = 10.52 PPG. Check flow every connection. Perform Drilling line inspection. Obtained slow pump rates. Crew Change 12:00 16:30 4.50 8,480 8,709 PROD1 DRILL DDRL P Continue directional drill 8 -3/4" hole from 8480' - 8709' MD (5704' ND). Pressure = 2870 psi off / 2970 psi on at 520 GPM. Torque = 12 -13k on / 12 off at 100 RPM w/ 6 -7K wt on bit. Max gas = 225 Units. ECD = 10.52 PPG. Check flow every connection. Perform Drilling line inspection. 16:30 18:00 1.50 8,709 8,709 PROD1 RIGMNT RGRP T Repair dresser sleeve on flow line, bell nipple to shakers. Reciprocate drill string. Flush test line. 18:00 00:00 6.00 8,709 8,965 PROD1 DRILL DDRL P Continue directional drill 8 -3/4" hole from 8709' - 8965' MD (5765' ND). AST = 1.28 ART = 5.30 ADT = 6.58 Jar hrs = 50.8 HRS Up wt = 155k. Down wt = 88K. Rot wt = 114k. Pressure = 2720 psi off / 2875 psi on at 520 GPM. Torque = 12 -13k on / 12 off at 100 RPM w/ 6 -7K wt on bit. Max gas = 443 Units. ECD = 10.38 PPG. Check flow every connection. Perform Drilling line inspection. Obtained slow pump rates. Crew Change 11/07/2008 Continue directional drill 8 3/4" hole from 8965' - 9217' (252') ND = 6027'. Pump 2 Hi Visc weighted sweeps preparing for short trip. BROOH to 7808' at 90 RPM's - 500 GPM's. CBU, Monitor well, POOH on elevators from 7808' - to shoe @ 4747'. Held PJSM. POOH and lay down 26 jnts of 4 1/2" XH DP. Rig up, slip & cut 50' of drilling line. Page 13 of 30 • • Time Logs \\ Date —From DuG S. Dail, ,E, .Depth Phase Code Sot€fe T.'' COmMeht 00:00 07:00 7.00 8,965 9,217 PROD1 DRILL DDRL P Continue directional drill 8 -3/4" hole from 8965' - 9217 MD (6000' ND). AST = 2.99 ART = 1.66 ADT = 4.65 Jar hrs = 55.45 HRS Up wt = 160k. Down wt = 90K. Rot wt = 116k. Pressure = 2940 psi off / 3080 psi on at 513 GPM. Torque = 12 -14k on / 12 off at 100 RPM w/ 6 -7K wt on bit. Max gas = 425 Units. ECD = 10.70 PPG. Check flow every connection. Perform Drilling line inspection. Obtained slow pump rates. Pumped Hi visc nut plug sweep at 9000' MD. Observed "ratty" detection on MWD with 5 -7 minutes tool face updates. 07:00 10:00 3.00 9,217 9,217 PROD1 DRILL DDRL P C/C wellbore. Pump two sweeps. Sweep #1 with approx 30% addtnl returns to shaker. Sweep #2 clean. No gain / loss. 10:00 14:30 4.50 9,217 7,808 PROD1 DRILL WPRT P Flow check, POH wiper trip planned to 9 -5/8 shoe. Necessary to back ream 8375 - 7808. 520 gpm / 100 rpm. Obtain Slow pump rates before POOH. 14:30 16:30 2.00 7,808 7,808 PROD1 DRILL CIRC P C/C wellbore. Excess sand to shakers. Cont circ / cond fluids, shaker clean. 520 gpm / 2886 psi, while reciprocate & rotate drill stirng. 16:30 19:30 3.00 7,808 4,712 PROD1 DRILL WPRT P Flow check, resume POH wiper trip 7808 - shoe @ 4747'. Observed proper displacement. Monitor well - static. 19:30 22:00 2.50 4,712 4,019 PROD1 DRILL TRIP P Held PJSM. Discuss safety & hazard recognition issues. Discuss JSA on pulling and laying down DP. POOH and lay down 26 joints of 4 1/2" XH drill pipe. 22:00 00:00 2.00 4,019 4,019 PROD1 RIGMNT SVRG P Held PJSM. Discuss safety & hazard recognition issues. Discuss JSA on slipping & cutting drilling line. Rig up and cut 50' of drilling line. Inspect drilling line. Crew Change 11/08/2008 Finish Slip & cut 50' Drilling line. Install Tuff Torque Saver sub. Service Top Drive, blocks & crown section. TIN from 4019' to 9217'. Observed proper displacement. Continue directional drill 8 3/4" hole from 9217' - 9786' MD. (569') ND = 6378'. Total Drilling HRS= 66.50. Total Sliding time = 22.22 HRS Pump sweeps as needed. ECD = 10.92 PPG. 00:00 02:30 2.50 4,019 4,019 PROD1 RIGMNT SVRG P Finish slip & cut 50' of drilling line. Inspect line. Service Top drive, Blocks, and crown section. Change out grabber dies. Clean & clear rig floor. 02:30 07:00 4.50 4,019 9,217 PROD1 DRILL TRIP P Trip in hole form 4019' to 9217'. Monitor well at the shoe - static. Observed proper displacement. Fill drill string every 1000'. Precaution _wash 60 ft to btm. No fill. Page 14 of 39 s • Date Fray* TO ¢. ';:liteettlse ; •'clek . *Ode- T Corheht ,. 07:00 12:00 5.00 9,217 9,405 PROD1 DRILL DDRL P Continue directional drill 8 -3/4" hole from 9217' - 9405' MD (6144' TVD). AST = ..62 ART = 2.43 ADT = 3.05 Jar hrs = 58.5 HRS Up wt = 152k. Down wt = 84K. Rot wt = 108k. Pressure = 3020 psi off / 3085 psi on at 506 GPM. Torque = 12 -14k on / 13 off at 100 RPM w/ 6 -7K wt on bit. Max gas = 900 Units. ECD = 10.91 PPG. Check flow every connection. Perform Drilling line inspection. Obtained slow pump rates. Pumped Hi visc nut plug sweep at 9600' MD. Observed no measurable increase in cuttings when sweep returned. Crew Change 12:00 00:00 12.00 9,405 9,786 PROD1 DRILL DDRL P Continue directional drill 8 -3/4" hole from 9405' - 9786' MD (6378' ND). AST = 2.58 ART = 5.42 ADT = 8.0 Jar hrs = 66.5 HRS Up wt = 158k. Down wt = 80K. Rot wt = 105k. Pressure = 3030 psi off / 3106 psi on at 502 GPM. Torque = 14 -15k on / 14 off at 100 RPM w/ 6 -7K wt on bit. Max gas = 350 Units. ECD = 10.92 PPG. Check flow every connection. Perform Drilling line inspection. Obtained slow pump rates. Crew Change 11/09/2008 Continue directional 8 3/4" hole from 9786' - 10162' MD. ND = 6616'. Lost power to rig. Trouble shoot, and bring rig power on line. Circulate & condition while reciprocate & rotate drill string. Sync up all computers. Continue drill from 10162' - 10232' MD, ND = 6655'. Observed MWD failure, no pulses @ 1600 HRS. Attempt to gain pulses, toggling tool, and trouble shooting with no success. Pump sweep & circulate to clean hole. Monitor well - static. Attempt to POOH on elevators with excessive drag. BROOH from 10232' - 8902'. Observed proper hole fill. No gas. Inspect drilling line. 00:00 11:00 11.00 9,786 10,162 PROD1 DRILL DDRL P Continue directional drill 8 -3/4" hole from 9786' - 10162 ft MD ( 6619 ND). AST = 2.29 ART = 4.79 ADT = 7.08 Jar hrs = 73.58 HRS Up wt = 150k. Down wt = 78K. Rot wt = 102k. Pressure = 2910 psi off / 3090 psi on at 486 GPM. Torque = 16 -17k on /15 off at 100 RPM w/ 6-7K wt on bit. Max gas = 194 Units. ECD = 10.80 PPG. Check flow every connection. Perform Drilling line inspection. Obtained slow pump rates. 11:00 14:00 3.00 10,162 10,162 PROD1 RIGMN1 RGRP T Total loss elect power. No gen set sync. Make repairs. Run / test gen sets. OK. Power up all computers / PLC systems. Page 15 of 39 L©gi . \ \\' • °Date .,, From To Dur S. S:. dotcV t Depth Phase ,,Code Subcod. a ' \.: Com e 14:00 16:00 2.00 10,162 10,232 PROD1 DRILL DDRL P Continue Directional drill 8 -3/4" hole from 10162 - 10232 ft MD ( 6655 ND). AST = 0 ART = 1.47 ADT = 1.47 Jar hrs = 75.13 HRS Upwt= 150k. Down wt = 78K. Rot wt = 102k. Pressure = 2960 psi off / 3095 psi on at 485 GPM. Torque = 16 -17k on /15 off at 100 RPM w/ 6-7K wt on bit. Max gas = 75 Units. ECD = 10.90 PPG. Check flow every connection. Perform Drilling line inspection. Obtained slow pump rates. 16:00 18:30 2.50 10,232 10,232 PROD1 DRILL OTHR T Observed MWD failure, no pulses. Performed multiple attempts to restore pulse, toggling tool with no success. Circulate bottoms up at 500 GPM's - 3090 PSI, while reciprocate & rotate drill string. 18:30 21:00 2.50 10,232 9,851 PROD1 DRILL OTHR T Monitor well - static. BROOH from 10232' - 9851' after attempting to POOH on elevators. Excessive drag, and pulling into ledges. 21:00 22:00 1.00 9,851 9,851 PROD1 RIGMNT RGRP T Observed saver sub backed off duringa connection. Lower top drive. Inspect & re- tighten same. 22:00 00:00 2.00 9,851 8,902 PROD1 DRILL REAM T Continue BROOH from 9851' - 8902'. Attempt numerous time to pull on elevators observing drag & overpulls. 11/10/2008 Continue BROOH from 8902' - 7700'. Monitor well - POOH on elevators observing proper hole fill. Download MWD assembly. Change out BHA. Trip back in hole to drill to 3700'. Observed proper displacement. Inspect drilling line. 00:00 03:30 3.50 8,902 7,700 PROD1 DRILL REAM T Continue BROOH from 8902' - 7700' MD. Attempt numerous time to pull on elevators observing drag & overpulls. 03:30 11:00 7.50 7,700 840 PROD1 DRILL TRIP T Observed drill string pulling free on elevators with proper displacement, and little or no drag. Pull 5 stands to verify fluid falling. pump dry job, continue POOH on elevators to BHA. 11:00 15:00 4.00 840 0 PROD1 DRILL PULD T Flow check. Handle BHA #3, std bk DCs, D/L source / MWD. LD drctnl equip. Break bit, grade, gauge, prep for re -run. 15:00 20:30 5.50 0 0 PROD1 DRILL PULD T Flow check, MU BHA #4. Reposition RES tool. Upload MWD nd install nuclear sources. 20:30 21:00 0.50 843 843 PROD1 DRILL PULD T TIH with remaining BHA. PU first stand of DP. Perform pulse test @ 460 GPM's - 1800 PSI. Good test. 21:00 00:00 3.00 843 3,700 PROD1 DRILL TRIP T TIH with BHA # 4 to 3700'. Observed proper displacement. Inspect Drilling line. Crew Change Page 16 of 39 Time I- S , Date Frqn 1 + Our u ', ! � +: r 'Phase Code Subcod ... it + ent_ \ . 11/11/2008 24 hrSumma TIH to shoe @ 4747''. Slip & cut 65' of drilling line. Continue TIH to 10232'. Obtain Checkshot surveys at 5057'. Observed proper displacement on TIH. No hole issues on TIH. Continue directional drill 8 3/4" hole to 10640' MD. TVD = 6911'. ADT = 8.09 HRS. AST = 2.16 HRS. Loaded cement pods onto deck. Weather did not allow scheduled change out. 00:00 02:00 2.00 3,700 4,747 PROD1 DRILL TRIP T Held PJSM. Discuss safety & hazard recognition issues. Discuss new crew, and procedure for upcoming slip & cut of drilling line. Continue trip in hole with BHA #4 from 3700' - shoe at 4747' MD. Fill drill string. Observed proper displacement. Monitor well - static. 02:00 03:30 1.50 4,747 4,747 PROD1 RIGMNT SVRG P Rig up and slip & cut 65' of drilling line. Inspect drilling line. Service top drive & crown section. Monitor well - static 03:30 10:30 7.00 4,747 10,232 PROD1 DRILL TRIP T Continue trip in hole with BHA #4 from 4747' - 5057. MU top drive and pump to obtain checkshot survey as per MWD rep. Pumps at 410 GPM's - 1717 PSI. Continue TIH form 5057' - 10132. Observed proper displacement. 10:30 12:00 1.50 10,232 10,290 PROD1 DRILL DDRL P Continue Directional drill 8 -3/4" hole from 10232' - 10290' MD ( 6696' TVD). AST = 0 ART = 1.13 HRS ADT = 1.13 HRS JAR HRS = 76.26 HRS Upwt =206K. Down wt= 94K. Rot wt = 124K. Pressure = 3060 psi off / 3230 psi on at 485 GPM. Torque = 16 -17k on / 15 off at 100 RPM w/ 6 -7K wt on bit. Max gas = 75 Units. ECD = 10.90 PPG. Check flow every connection. Perform Drilling line inspection. 12:00 00:00 12.00 10,290 10,640 PROD1 DRILL DDRL P Continue Directional drill 8 -3/4" hole from 10290' - 10640' MD ( 6911' ND). AST = 2.16 HRS ART = 4.81 HRS ADT = 6.96 HRS JAR HRS = 84.36 HRS Up wt = 206K. Down wt = 94K. Rot wt = 128K. Pressure = 2740 psi off / 2848 psi on at 494 GPM. Torque = 18 -19k on / 18 off at 100 RPM w/ 6 -7K wt on bit. Max gas = 203 Units. ECD = 10.97 PPG. Check flow every connection. Perform Drilling line inspection. Obtained Slow pump rates at 10488' 11/12/2008 Continue Directional drill 8 -3/4" hole from 10640' - 11368' MD. Up wt = 215K. Down wt = 96K. Rot wt = 132K. Pressure = 2820 psi off / 3050 psi on at 494 GPM. Torque = 20k on / 19k off at 100 RPM w/ 8K wt on bit. Max gas = 425Units. ECD = 10.94 PPG. Check flow every connection. Perform Drilling line inspection. Obtained Slow um rates at 11300'. p p Page 17 of 39 • '' fit, ` \` \` : �\` ? s .. Time Logs v x 4� rye � ` � \� .. �� \ Date. Fri• <. . C \ ..... r :... , . t1e>�ri�` !:� �� :i5hese bode Suboode . T. .:: :Corbment. 'Vq4 \... , 00:00 12:00 12.00 10,640 10,903 PROD1 DRILL DDRL P Continue Directional drill 8 -3/4" hole from 10640' - 10903' MD. AST = 2.31 HRS ART = 2.98 HRS ADT = 5.29 HRS JAR HRS = 88.52 HRS Up wt = 215K. Down wt = 96K. Rot wt = 132K. Pressure = 2820 psi off / 3050 psi on at 494 GPM. Torque = 20k on / 19k off at 100 RPM w/ 8K wt on bit. Max gas = 425Units. ECD = 10.94 PPG. Check flow every connection. Perform Drilling line inspection. Obtained Slow pump rates at 10640' 12:00 00:00 12.00 10,903 11,368 PROD1 DRILL DDRL P Continue Directional drill 8 -3/4" hole from 10903' - 11368' MD. ADT = 20 HRS JAR HRS = 94.88 HRS Up wt = 215K. Down wt = 96K. Rot wt = 132K. Pressure = 2820 psi off / 3050 psi on at 494 GPM. Torque = 20k on / 19k off at 100 RPM w/ 8K wt on bit. Max gas = 425Units. ECD = 10.94 PPG. Check flow every connection. Perform Drilling line inspection. Obtained Slow pump rates at 10640' 11/13/2008 Continue Directional drill 8 -3/4" hole from 10903' - 11387' MD. Up wt = 215K. Down wt = 96K. Rot wt = 132K. Pressure = 2820 psi off / 3050 psi on at 494 GPM. Torque = 20k on / 19k off at 100 RPM w/ 8K wt on bit. Max gas = 425Units. ECD = 10.94 PPG. Check flow every connection. Perform Drilling line inspection. Obtained Slow pump rates at 10640'. At 11386' MD the hydraulic pump on mud pump #1 broke down. Circulate for one hour to access the situation and look for parts. Drill ahead from 11387' MD to 11501' MD ✓ With pump #2, 120 SPM, #20 GPM and 1500 PSI. Circulate bottoms up before POOH. Back ream out of hole from 11501' MD to shoe. No tight hole, hole took the right amount of fluid. 00:00 01:00 1.00 11,368 11,387 PROD1 DRILL DDRL P Continue Directional drill 8 -3/4" hole from 11368' - 11387 MD. AST = 2.16 HRS ART = 18.84 HRS ADT = 21 HRS JAR HRS = 100.07 HRS Up wt = 215K. Down wt = 96K. Rot wt = 132K. Pressure = 2820 psi off / 3050 psi on at 494 GPM. Torque = 20k on / 19k off at 100 RPM w/ 8K wt on bit. Max gas = 425Units. ECD = 10.94 PPG. Check flow every connection. 01:00 02:00 1.00 11,387 11,387 PROD1 DRILL OTHR T The hydraulic pump on mud pump #1 broke down. Access the situation and look for parts. It was decided to drill ahead with pump #2, 120 SPM, 320 GPM and 1500 PSI. 02:00 09:00 7.00 11,387 11,501 PROD1 DRILL DDRL P Continue to Directional drill 8 -3/4" hole from 11387' MD to 11501' MD. Pump #1, SPM = 12, GPM = 320 and PIS = 1500. ECD is staying at 10.7 PPG with an ROP of 25 ft/hr. No tight hole encountered. Bit hours = 24.97, Jar Hours = 100. Mud pump #1 Still down. Page'', 18 of 39 • Date r,:• �? .th E. o • a Phase - oche; bcode T ; . .raiment 09:00 10:30 1.50 11,501 11,501 PROD1 DRILL CIRC P Circulate bottoms up before POOH. Mud pump #1 still down. 10:30 00:00 13.50 11,501 7,127 PROD1 DRILL REAM P Back ream out of hole from 11501' MD to 7127' MD. No tight hole, hole took the right amount of fluid. 11/14/2008 Back ream out of hole from 7127' MD to 4747' MD. GPM = 320, RPM = 120. No tight spots, Hole took the right amount of fluid. Number one pump still down. Monitor well, circulate at shoe, lube rig and build dry job. POOH from 4747' MD to 1640' MD. Hole took the right amount of fluid. Prepair floor and pipe deck to lay down drill pipe. Held safety meeting and lay down drill pipe, 1640' MD to 843' MD. Held safety meeting. Remove nuke sources from BHA and lay down nuke tools. Dump MWD data, change out pulser -TM, stand back MWD and lay down motor. Test BOPE to AOGCC specifications. Test choke valves, upper IBOP, lower kelly cock, floor valve, dart valve, Hydrill, upper pipe rams, HCR valve, manual choke valve, inside kill and test Koomey unit. Test to 250 PSI low and 3500 PSI high. 00:00 06:00 6.00 7,127 4,747 PROD1 DRILL REAM P Back ream out of hole from 7127' MD to 4747' MD. GPM = 320, RPM = 120. No tight spots, Hole took the right amount of fluid. Number one pump still down. 06:00 08:00 2.00 4,747 4,747 PROD1 DRILL CIRC P Monitor well, circulate at shoe, lube rig and build dry job. 08:00 11:30 3.50 4,747 1,640 PROD1 DRILL TRIP P POOH from 4747' MD to 1640' MD. Hole took the right amount of fluid. 11:30 12:00 0.50 1,640 1,640 PROD1 DRILL TRIP P Prepair floor and pipe deck to lay down drill pipe. 12:00 14:00 2.00 1,640 843 PROD1 DRILL TRIP P Held safety meeting and lay down drill pipe, 1640' MD to 843' MD. 14:00 19:00 5.00 843 0 PROD1 DRILL PULD P Held safety meeting. Remove nuke sources from BHA and lay down nuke tools.Dump MWD data, change out pulser -TM, stand back MWD and lay down motor. 19:00 00:00 5.00 0 0 PROD1 DRILL OTHR P Test BOPE to AOGCC specifications. Test choke valves, upper IBOI?, lower kelly cock, floor valve, dart valve, Hydrill, upper pipe rams, HCR valve, manual choke valve, inside kill and test Koomey unit. Test to 250 PSI low and 3500 PSI high. 11/15/2008 RIH with sonic /FMI tool. Tool set down several times in several places, 5200' 5500', 5700' and lastly 5670' MD. Schlumberger tried several times to make head way with out success. The tool picked up cleanlily without pulling tight untill the last time. It came off bottom at 5670' MD with 1000K over pull. It was then decided to POOH with the wire line unit and rig up and run logs on drill pipe. Next logging run will be the MDT on drill pipe. 00:00 04:30 4.50 0 0 PROD1 DRILL OTHR P Finish testing BOP's. Test blind rams, 7" VBR and annular preventer. Pull test plug and install wear ring. Lay down 7" test joint. 04:30 05:00 0.50 0 0 PROD1 EVALFN OTHR P Service rig and top drive, monitor well. 05:00 06:00 1.00 0 0 PROD1 DRILL OTHR P Blow down top drive. RIH with HWDP 06:00 08:00 2.00 0 0 PROD1 DRILL OTHR P Slip and cut drilling line 08:00 08:30 0.50 0 0 PROD1 DRILL OTHR P Clear and clean rig floor Page 19 of 39 • • Date From To Dor' .. :S. 00001 .'E.De Otft P t ale .. .%* bootie ' or rhernt 08:30 12:00 3.50 0 0 PROD1 EVALFN RURD T Wait for Schlumberger wire line equipment to get off loaded from boat and put in place. 12:00 18:00 6.00 0 0 PROD1 EVALFN PULD P Monitor well, hold pre -job safety meeting. Spot Schlumberger wire line unit and equipment. Assist in wire line unit and equipment rig up. Continue to work on number mud pump. 18:00 20:30 2.50 0 0 PROD1 EVALFN OTHR P Held pre -job safety meeting. Pick up Sonic FMI log and Schlumberger wire line sheaves. 20:30 23:30 3.00 0 0 PROD1 EVALFN DLOG P RIH with sonic/FMI tool. Tool set down several times in several places, 5200' 5500', 5700' and lastly 5670' MD. Schlumberger tried several times to make head way with out success. The tool picked up cleanlily without pulling tight untill the last time. It came off bottom at 5670' MD with 1000K over pull. It was then decided to POOH with the wire line unit and rig up and run logs on drill pipe. Next logging run will be the MDT on drill pipe. 23:30 00:00 0.50 0 0 PROD1 EVALFN RURD P Lay down sheaves and start to lay down sonic logging tools. 11/16/2008 Pick up and run MDT drill pipe convied logging tools. Test loggs and RIH to Shoe. Circulate and condition mud. Circulate at 168 GPM, 215 PSI. Shut off pumps and monitor well. RIH with Logging tools from 4747' MD to 7395' MD. Break circulation every 500'. No tight hole and the hole took the right amount of fluid. Circulate one drill pipe volume. Hold safety meeting. Rig up Schlumberger sheaves and install side entry sub. RIH with wire line and latch up to MDT tool. Test wire line tools and install clamp. Perform wire line MDT logging. Logging depths are 7485' 7585',7657',7688',7766',and 7822'. 00:00 03:00 3.00 0 0 PROD1 EVALFN RURD P Monitor well, Hold safety meeting. Lay down Sonic /LMI logging tools. 03:00 10:00 7.00 0 4,747 PROD1 EVALFN TRIP P Pick up and run MDT drill pipe convied logging tools. Test loggs and RIH to Shoe. 10:00 11:30 1.50 4,747 4,747 PROD1 EVALFN CIRC P Circulate and condition mud. Circulate at 168 GPM, 215 PSI. Shot off pumps and monitor well. 11:30 15:30 4.00 4,747 7,395 PROD1 EVALFN TRIP P RIH with Logging tools from 4747' MD to 7395' MD. Break circulation every 500'. No tight hole and the hole took the right amount of fluid. 15:30 16:00 0.50 7,395 7,395 PROD1 EVALFN CIRC P Circulate one drill pipe volume. 16:00 17:00 1.00 7,395 7,395 PROD1 EVALFN RURD P Hold safety meeting. Rig up Schlumberger sheaves and install side entry sub. 17:00 19:00 2.00 7,395 7,395 PROD1 EVALFN TRIP P RIH with wire line and latch up to MDT tool. Test wire line tools and install clamp. 19:00 00:00 5.00 7,395 7,822 PROD1 EVALFN DLOG P Perform wire line MDT logging. Logging depths are 7485' 7585',7657',7688',7766',and 7822'. Page 20 of 39 Time Logs \ �.. Date :Frorn` �.T0�::\\. NA S. Depth E', ate: i Ph t.. ' r, � Sub T .. Corry ' -nt �' *A. 11/17/2008 24 hr Summa Pick up and run MDT drill pipe convied logging tools. Test loggs and RIH to Shoe. Circulate and condition mud. Circulate at 168 GPM, 215 PSI. Shut off pumps and monitor well. RIH with Logging tools from 4747° MD to 7395' MD. Break circulation every 500'. No tight hole and the hole took the right amount of fluid. Circulate one drill pipe volume. Hold safety meeting. Rig up Schlumberger sheaves and install side entry sub. RIH with wire line and latch up to MDT tool. Test wire line tools and install clamp. Perform wire line MDT logging. Logging depths are 7485' 7585',7657',7688',7766', 7822', 7943', 8003', 8083'. 8216', 8254', 8329' and 8650'. Statis fluid loss while performing MDT logging is 1/2 barrel per /hr. PPOH to shoe. Continue with wire line MDT logging. Logging depths are 5139', 5180', 5230', 5440'. 5544', 5650', 5690' and 5787'. No tight hole. Static fluid loss down hole is 1/2 barrel per /hr. 00:00 09:00 9.00 7,822 9,612 PROD1 EVALFN DLOG P Continue with wire line MDT logging. Logging depths are 7943', 8003', 8083'. 8216', 8254', 8329', 8650', 8808', 8999', 9120', 9225', 9464', and 9612' Statis fluid loss while performing MDT logging is 1/2 barrel per /hr. 09:00 12:00 3.00 9,612 7,427 PROD1 EVALFN TRIP P POOH from 9612' to 7427'. No tight hole. 12:00 13:30 1.50 7,427 7,401 PROD1 EVALFN OTHR P POOH with wire line, lay down side entry sub at 7401'. 13:30 16:30 3.00 7,401 4,957 PROD1 EVALFN TRIP P POOH with drill pipe from 7401' to 4957'. No tight hole. The hole took the right amount of fluid. 16:30 19:00 2.50 4,957 4,957 PROD1 EVALFN OTHR P Pick up side entry sub at 4957, RIH with wire line and look up. 19:00 00:00 5.00 4,957 5,787 PROD1 EVALFN DLOG P Continue with wire line MDT logging. Logging depths are 5139', 5180', 5230', 5440'. 5544', 5650', 5690' and 5787'. No tight hole. Static fluid loss down hole is 1/2 barrel per /hr. 11/18/2008 POOH from 9612' to 7427'. No tight hole. POOH with wire line, lay down side entry sub at 7401'. POOH with drill pipe from 7401' to 4957'. No tight hole. The hole took the right amount of fluid. Pick up side entry sub at 4957, RIH with wire line and look up. Continue with wire line MDT logging. Logging depths are 5139', 5180', 5230', 5440'. 5544', 5650', 5690' and 5787'. to 7280. No tight hole. Static fluid loss down hole is 1/2 barrel per /hr. POH & lay down tools. 00:00 10:30 10.50 5,787 7,280 PROD1 EVALFN DLOG P Continue with wire line MDT logging. Logging depths are 5830', 5914', 6064', 6174', 6231', 6280', 6414', 6465', 6524', 6592' 6616', 6716', 6756', 6851', 6985', 7170', 7250', 7280'. No tight hole. Static fluid loss down hole is 1/2 barrel per /hr. 10:30 15:00 4.50 7,280 4,957 PROD1 EVALFN TRIP P POH from 7280' to 4957'.Side entry sub, unlatch tool & lay down same.'. 15:00 21:00 6.00 4,957 0 PROD1 EVALFN TRIP P POH from 4957'. Monitor well. Move drill collars to ODS & POH. 21:00 00:00 3.00 0 0 PROD1 EVALFN PULD T Lay down tools. Monitor well & pick up new tools. 11/19/2008 Logging well. 00:00 03:30 3.50 0 0 PROD1 EVALFN PULD T Monitor well, PJSM -Make up FMI Sonic logging tools. 03:30 06:00 2.50 0 2,450 PROD1 EVALFN TRIP T RIH w/ logging tools & HWDP, pick up 26 jts. dp & RIH 06:00 08:00 2.00 2,450 4,714 PROD1 EVALFN TRIP T Continue RIH to 4714'. Page 21 of 39 • miiki Date Pratt , To Dur S E. • :: hase _Code Subcode T Comment 08:00 09:00 1.00 4,714 4,714 PROD1 EVALFNCIRC T Condition mud & circulate bottoms up. 09:00 09:30 0.50 4,714 4,714 PROD1 EVALFN OTHR T Blow down top drive & service rig. 09:30 10:30 1.00 4,714 4,747 PROD1 EVALFN PULD T PJSM -Make up side door entry sub. Tie in E line & RIH to 4747'. 10:30 17:30 7.00 4,747 7,255 PROD1 EVALFN DLOG P Test tools & log well from 4747' to 7255'. 17:30 19:00 1.50 7,255 6,776 PROD1 EVALFN DLOG P POH logging out from 7255' to 6776'. 19:00 20:00 1.00 6,776 7,222 PROD1 EVALFN DLOG P RIH from 6776' to 7222' logging in. 20:00 00:00 4.00 7,222 5,539 PROD1 EVALFN DLOG P POH from 7222' to 5539' logging out. PU 130k SO 80k Drilling line inspected OK. Hole taking approx. 2 bbls per hour fluid. 11/20/2008 00:00 02:00 2.00 5,539 4,717 PROD1 EVALFN DLOG P Continue logging from 5539' to 4717'. 02:00 03:30 1.50 4,717 4,717 PROD1 EVALFN OTHR P Rig down E line & lay down side entry sub. 03:30 05:00 1.50 4,717 7,000 PROD1 EVALFN TRIP P RIH from 4717' to 7000'. 05:00 07:30 2.50 7,000 7,000 PROD1 EVALFNCIRC P Condition mud & circ. 07:30 09:30 2.00 7,000 7,000 PROD1 EVALFN TRIP P Blow down top drive & rih w/ wire line. Test same. 09:30 12:00 2.50 7,000 8,460 PROD1 EVALFN DLOG P Log from 7006' to 8460'. 12:00 14:30 2.50 8,460 9,156 PROD1 EVALFN TRIP P RIH from 8460' to 9156'. (hit ledge @ 9156' SWS measurement. 14:30 20:00 5.50 9,156 6,999 PROD1 EVALFN DLOG P Log well from 9156' to 6999' while tripping out. 20:00 22:00 2.00 6,999 6,999 PROD1 EVALFN PULD P Unlatch tool. Lay down side entry sub & rig down floor equipment. 22:00 00:00 2.00 6,999 5,552 PROD1 EVALFN TRIP P POH from 6999' to 5552'. 11/21/2008 Finish poh. Lay down tools. RIH 00:00 06:00 6.00 5,552 1,500 PROD1 EVALFN TRIP T POH from 5552' to 1500'. Lay down drill pipe. 06:00 08:00 2.00 1,500 0 PROD1 EVALFN TRIP T POH & lay down SWS tools. 08:00 08:30 0.50 0 0 COMPZ DRILL TRIP P Monitor well. Clear & clean rig floor & service rig. 08:30 10:30 2.00 0 85 COMPZ DRILL PULD P Make up BHA Plug in & tern on smart tools. 10:30 11:30 1.00 85 814 COMPZ DRILL TRIP P Finish picking up BHA to 814'. Fill pipe & test tools. 11:30 17:30 6.00 814 4,744 COMPZ DRILL TRIP P Pick up drill pipe & RIH to 4744'. 17:30 19:30 2.00 4,744 4,744 COMPZ DRILL OTHR P Circ. @ 4744'. Slip & cut 100' DrIg. line. 19:30 20:00 0.50 4,744 4,744 COMPZ DRILL OTHR P Service top drive & grease crown sheaves. 20:00 00:00 4.00 4,744 7,669 COMPZ DRILL TRIP P RIH from 4744' to 7669'. Fill pipe every 1000'. Check for flow after every fill up. 11/22/2008 Finish wash to bottom. Circ. & BROOH. Page 22 of 3 IDY. Fro ..T� � �< \.. .�. Depth . E. Depth Phan ':Code Subcode .'T 00:00 02:00 2.00 7,669 9,106 COMPZ DRILL TRIP P RIH from 7669' to 9106'. 02:00 02:15 0.25 9,106 9,106 COMPZ DRILL OTHR T Hydraulic pump on #1 mud pump split & caused spill. Clean up spill. Continued washing down with #2 pump. 02:15 12:30 10.25 9,106 11,501 COMPZ DRILL REAM P Slide thru bridge @ 9106 & clean out to 11501'. PU 136k so 110k rot 122k pp 1460 psi 120 spm toq 12k. 12:30 15:30 3.00 11,501 11,501 COMPZ DRILL CIRC P Circ. sweep around. 15:30 00:00 8.50 11,501 8,812 COMPZ DRILL TRIP P BROOH from 11501' to 8812'. MD 320 gpm 100 rpm pp 1300 psi up 170k do 100k rot 130k. (Drill line inspected) 11/23/2008 Finish POH. Lay down BHA. Rig up to run csg. 00:00 09:00 9.00 8,812 4,740 COMPZ DRILL TRIP P Continue BROOH from 8812' MD to 4740'. MD 09:00 10:30 1.50 4,740 4,740 COMPZ DRILL CIRC P Condition mud & circ. pump hi -vis sweep. 10:30 13:00 2.50 4,740 2,337 COMPZ DRILL TRIP P Pump dry job. Blow down topdrive, monitor well & POH from 4740' to2337'. MD 13:00 16:00 3.00 2,337 813 COMPZ DRILL PULD P Continue poh laying down 50 jts. dp. Strap same. 16:00 21:30 5.50 813 0 COMPZ DRILL PULD P PJSM =lay down HWDP & BHA. Get sperry tools off floor. 21:30 22:30 1.00 0 0 COMPZ CASING RURD P Rig up to pull wear bushing & clean up floor. 22:30 00:00 1.50 0 0 COMPZ CASING OTHR P PJSM =Slip & cut 64' drlg. line. 11/24/2008 Clear floor. Rig up & run 7" csg. 00:00 01:00 1.00 0 0 COMPZ CASING OTHR P Finish cut & slip 64' drlg. line. 01:00 06:00 5.00 0 0 COMPZ CASING OTHR P Back load boat w/ DP, sperry tools. etc. Prep rig & deck to make dummy run & rig up to run 7" csg. 06:00 07:00 1.00 0 0 COMPZ CASING RNCS P Make up 7" casing hanger onto landing joint and RIH for dummy run. Verify seated. 07:00 07:30 0.50 0 0 COMPZ CASING SFTY P Held PJSM with rig crew, weatherford reps and crane operator. Discuss safety & hazard recognition issues. Discuss procedure to rig up and run 7" casing. 07:30 09:00 1.50 0 0 COMPZ CASING RURD P Rig up casing tongs. Obtain hot work permits and leak check tong unit. Pull tools to rig floor. Verify count on centralizers. 09:00 23:30 14.50 0 4,554 COMPZ CASING RNCS P MU shoe track assembly with baker loc connections. Fill pipe & check floats.Continue RIH with 7" casing as per detail filling each joint. Observed proper displacement. Torque on connections 6000 -6500 ft/lbs. RIH to 4554'. Page', 23 of 3 Da i roi11 ')_: � , .. Ettb e >�\k'Com ment 23:30 00:00 0.50 4,554 4,554 COMPZ CASING CIRC P Circ. csg. & hole while unloading 70 jts. 7" off boat. Strap & drift same. 11/25/2008 Rig up & run 7" csg. to 9978'. 00:00 02:30 2.50 4,554 4,554 COMPZ CASING OTHR P Slip & cut drlg. line. 02:30 06:00 3.50 4,554 4,554 COMPZ CASING CIRC P Circ. Capacity of csg. while unloading boat . Strap & drift remainder of 7" csg. 06:00 07:30 1.50 4,554 4,554 COMPZ CASING OTHR P PJSM =Line #1 pump back on hole. Prepare to run csg. 07:30 10:00 2.50 4,554 6,000 COMPZ CASING RNCS P Run 7" csg. to 6000'. MD 10:00 11:00 1.00 6,000 6,000 COMPZ CASING CIRC P Circ. cond mud @ 3 bpm 500 psi. 11:00 13:30 2.50 6,000 7,000 COMPZ CASING RNCS P Run 7" csg. from 6000' to 7000'. MD 13:30 14:30 1.00 7,000 7,000 COMPZ CASING CIRC P Circ. cond mud @ 4 bpm up 175k dn 50k. 14:30 17:30 3.00 7,000 8,000 COMPZ CASING RNCS P Run 7" csg. from 7000' to 8000'. MD 17:30 18:30 1.00 8,000 8,000 COMPZ CASING CIRC P Circ. cond mud @ 4.5 bpm. 700 psi 18:30 21:00 2.50 8,000 9,000 COMPZ CASING RNCS P Run 7" csg. from 8000' to 9000'. MD 21:00 22:00 1.00 9,000 9,000 COMPZ CASING CIRC P Circ. cond mud @ 7 -8 bpm 300 -350 gpm. 1150 psi. 22:00 00:00 2.00 9,000 9,978 COMPZ CASING RNCS P Run 7" csg. from 9000' to 9978'. MD v Bridge took wt. rig up to circ. Up wt 280k dn 58k 11/26/2008 Stuck pipe @ 9982'. Circ. & cement csg. 00:00 06:00 6.00 9,978 9,982 COMPZ CASING OTHR T Tagged @ 9978'. Make up circ. head & attempt to move pipe. Break circ. & work pipe. Pump from 200 to 475 gpm while working pipe to 350k up & 40k down. Appears to be differential stuck as we have full circ. Recovered 2 rubber stabilizer blades over shakers while circ. & working pipe. BJ rigging up to cement. PJSM w/ cement & rig crews. 06:00 08:00 2.00 9,982 9,982 COMPZ CASING CIRC P Rig up cement equipment, break circulation. 08:00 11:00 3.00 9,982 9,982 COMPZ CEMEN" DISP P Pump 3 BBIs water to fill pumps and lines. Pressure test to 5k. Pump 80 BBLs 10.3 ppg Seal bond spacer @ 5 BPM. Drop 1st plug. Pump 254 BBLs 10.9 ppg cement @ 5 BPM. Drop 2nd plug. Push out plug with 5 BBLs water. Rig pump #2 displaced @ 5 BPM. 374 BBLs inhibited water. Bump plug. 11:00 11:30 0.50 9,982 9,982 COMPZ CEMEN P Hold 700 psi over last pressure reading.(1200 to 1900) 2 mins bleed off, test float , good. 11:30 12:30 1.00 9,982 9,982 COMPZ CASING DHEQ P Test casing to 4150 psi, 30 mins. charted. Page 24 of 39 1 Time Logs \ \` Date .. e To : :; ,_ Der :> „:' E� Del�'kts��Dc�e,, ,j S�bcod T4;C6frtt»enf 12:30 00:00 11.50 9,982 9,982 COMPZ CEMEN" WOC P WOC. Prep BOP stack for setting emergency slips. Remove cement head. Drain stack. Clean pits & clean rig floor. 11/27/2008 WOC. Cut off & set slips. Test bop breaks. 00:00 02:00 2.00 9,982 9,982 COMPZ CEMEN" WOC P Cleaning mud tanks while WOC to set slips on 7" csg. 02:00 06:00 4.00 9,982 9,982 COMPZ CASING NUND P Nipple down BOPE to set slips on 7" csg. 06:00 10:00 4.00 9,982 9,982 COMPZ CASING NUND T Finish PU and hang stack. 10:00 10:30 0.50 9,982 9,982 COMPZ CASING OTHR T Install emergency slips w/ 230k wt. (10k over string wt). 10:30 12:00 1.50 9,980 9,980 COMPZ CASING OTHR T Cut off 7" csg. Dress stump. Cut 14.80' off Jt. #242 in hole. New 7" shoe depth is 9980' MD. 12:00 14:00 2.00 9,980 9,980 COMPZ CASING OTHR T Lay down jt. 7" & cut off stump. Lay down slips & elevators. 14:00 16:00 2.00 9,980 9,980 COMPZ CASING NUND T Rig up slings to pick BOP,S. Install packoff. PJSM. 16:00 22:00 6.00 9,980 9,980 COMPZ CASING NUND •T Land BOP,S test packoff. Install flow nipple & flow line. 22:00 00:00 2.00 9,980 9,980 COMPZ CASING OTHR T Set test plug & fill stack w/ water. Test both breaks 250/3500 psi. OK Drain stack & lay down test jt. 11/28/2008 Lay down 4.5" dp. & flush bope. 00:00 21:00 21.00 9,980 9,980 COMPZ CASING OTHR P Rig up & lay down 4.5" drill pipe out of derrick. Break down w/ mouse hole in rotary table. Tuff torque pipe make up was 30k torque & is very tight to break out w/ no hanging wt. 21:00 00:00 3.00 9,980 9,980 COMPZ CASING OTHR P Clean rig floor. Flush bop stack & choke. Blow down choke to shakers. 11/29/2008 Run USIT log. & clean pits. 00:00 03:30 3.50 9,980 9,980 COMPZ CASING OTHR P Clean up rig, flush stack, blow down mud lines. Move schlumberger unit in place. 03:30 04:30 1.00 9,980 9,980 COMPZ EVALWE ELOG P PJSM =rig up sclumberger E -line. 04:30 06:30 2.00 9,980 9,980 COMPZ EVALWE ELOG P Running 6" gauge ring junk basket. Tagged up at 9800'. POH. 06:30 12:30 6.00 9,980 9,980 COMPZ EVALWE ELOG P RIH w/ USIT tool to 9820'. Run USIT log from 9795' to 2920'. Lay down schlumberger tools & rig down same. 12:30 00:00 11.50 9,980 9,980 COMPZ EVALWE WOW P Clean -Rig & pits & suction,s on #1 & 2 mud pumps while waiting on weather to settle down to get boat in w/ 4.5" tbg. & backload Schlumberger & drill pipe. 11/30/2008 Clean tanks & rig. Unload & load boat. Run 40 jts. tbg. 00:00 20:00 20.00 9,980 9,980 COMPZ RPCOM WOW P Cleaning rig & mud tanks. Rig maintenance. Clean cellar. Backload & unload boat. 20:00 21:00 1.00 9,980 9,980 COMPZ RPCOM RURD P Rig up to run 4.5" tbg. kill string. Page 26 of 39 Date a4 .: TO Dur 2191aeth E. E rth Phase Code c ide omment ., .. 21:00 00:00 3.00 9,980 9,980 COMPZ RPCOM RCST P PJSM =Run 40 jts. 4.5" 12.6# L -80 IBTM tbg. 12/01/2008 Hang off 4.5" tbg. Nipple down bope. Install tree test same & release rig. 00:00 02:00 2.00 9,980 9,980 PROD1 RPCOM OTHR P Make up Landing jt. Drain bop stack. Land kill string w/ BPV installed @ 1263' MD. Test hanger 5000 psi OK. Lay down landing jt. 02:00 06:00 4.00 9,980 9,980 COMPZ RPCOM OTHR P Pull rotary table. Clean up cellar area prior to nipple down bope. 06:00 12:00 6.00 9,980 9,980 COMPZ RPCOM NUND P PJSM =Pull mouse hole & bleed off Koomey unit. Remove Koomey lines. Disconnect mud lines & nipple down bope, remove riser. Install dry hole tree, test to 5000 psi 10 mins. OK. Release rig from A -14 to A -16 @ 1200 hrs. 12 -1 -2008) 03/31/2009 Finish well A -15, Skid rig to A -14 and start to nipple up. 19:00 00:00 5.00 9,980 COMPZ RPCOM NUND P Finish skidding and start to nipple up. 04/01/2009 Finish nipple up of BOPE on A -14. Perform BOP test to all AOGCC specifications. Offload supply boat of 4 1/2" frack string. tubing. 00:00 06:00 6.00 COMPZ RPCOM NUND P Held Safety Meeting. Install riser beaver slid and catwalk. Connect flow lines to pit system. Stack BOP's on riser, nipple up choke and kill lines. 06:00 11:30 5.50 COMPZ RPCOM NUND P Hammer up all connection on riser and BOP's, connect Koomey lines, picture nipple and flow lines. Function test Hydrill rams and HCR valve. 11:30 13:30 2.00 COMPZ RPCOM PRTS P Notified AOGCC on 3 -31 -09 @ 07:00 hrs for BOP test, witness of test waved by Chuck Scheve. Test #1 Test Blind Rams Choke Valves 1,8,12 and inside Kill to 250/5000 PSI. 13:30 15:30 2.00 COMPZ RPCOM PRTS P Test Hydril with 4" drill pipe, Choke valves, HYD IBOP, Manual IBOP and Dart valve to 250/5000 PSI. 15:30 16:30 1.00 COMPZ RPCOM PRTS P Break down 4" test joint and make up 4 1/2" test joint. 16:30 19:00 2.50 COMPZ RPCOM PRTS T Attempt to continue BOP test, dart valve in tubing hanger would not hold. POOH and inspect then run back in, attempt to test would not test. 19:00 19:30 0.50 COMPZ RPCOM PRTS P Test floor valve, make up FOSV valve and test to 250/5000 PSI. Pull test joint. 19:30 21:00 1.50 COMPZ RPCOM PRTS P Break off test dart and running tool, lay down test joint. 21:00 22:00 1.00 COMPZ RPCOM PRTS P Change out elevators, pick up landing joint and pull back pressure valved. Page 26 of 39 • T ime !Logs From To Dar � 8 ' Depth -:� Deth:`Pl�es,�ode � � �� Date Fr ��11�... 22:00 00:00 2.00 COMPZ RPCOM PRTS P Make up landing joint and pull tubing hanger. Lay down hanger and landing joint. Change elevators and move Weatherford tongs off rig floor. Bring storm packer to rig floor. 04/02/2009 Finish testing BOP's. Rig up Weatherford tubing equipment and POOH with 40 joints of 4 1/2" Kill String. Pick up mill and MI Swaco casing cleaning BHA and RIN to 9871' MD. Circulate bottoms up then make short trip back to casing scraper, then back to bottom. 00:00 01:30 1.50 COMPZ RPCOM PRTS T Held Safety Meeting. Make up Halliburton RTTS and set at 60'. 01:30 04:00 2.50 COMPZ RPCOM PRTS P Make up and set 4 1/2" test plug. Test Hydril with 4 1/2" drill pipe to 250/35000 PSI. Test variable pipe rams with 4 1/2" drill pipe to 250/5000 PSI. Test manual choke to 250/5000 PSI. Can not get HCR to test. 04:00 06:00 2.00 COMPZ RPCOM PRTS T Held safety meeting and go over JSA for changing out HCR valve. Change out HCR Valve. 06:00 07:00 1.00 COMPZ RPCOM PRTS T Test HCR and down stream flange to 250/5000 PSI, Test OK. Lay down test joint. 07:00 08:00 1.00 COMPZ RPCOM PRTS T POOH with Halliburton Storm Packer and lay down same. 08:00 10:30 2.50 COMPZ RPCOM TRIP P Held safety meeting. Rig up Weatherford tubing equipment and POOH with Kill String. 10:30 11:00 0.50 COMPZ RPCOM OTHR P Rig down Weatherford and set wear bushing. 11:00 17:30 6.50 COMPZ RPCOM TRIP P Make up MI Swaco casing cleaning assembly and RIH, tag up at 9795' MD. 17:30 18:30 1.00 COMPZ RPCOM CIRC P Wash down from 9795' to 9871'. Circulate @ five barrels a minute with 500 PSI. 18:30 21:30 3.00 COMPZ RPCOM CIRC P Circulate clean water at 2 barrels a minute with 175 PSI until returnes are clean. Pump rate was limited because trash pits were full, BJ injecting at same time. 21:30 00:00 2.50 COMPZ RPCOM TRIP P Make short trip to 7277' MD. 04/03/2009 Make short trip up to 4928' MD, then RIH to 8790' MD and ream to 9857' MD. Slip and cut drilling line. Install head pin in drill pipe and rig up BJ hard lines to rig floor. Held safety meeting and then pump 20 bbls Flow -vis, 420 gallons safety pickel and displace with 95 barrels of water at 1 barrel per /min to place at bottom of drill pipe. Close Hydril and displace with 220 barrels of water at 2 barrels a minute. 00:00 02:30 2.50 COMPZ RPCOM TRIP P Held Pre -Tour safety meeting. POOH from 7277' MD to 4928' MD. 02:30 06:00 3.50 COMPZ RPCOM TRIP P RIH from 4928' to 8790' MD. 06:00 08:30 2.50 COMPZ RPCOM REAM P Ream from 8790' MD to 9795' MD. 08:30 09:00 0.50 COMPZ RPCOM SFTY P Held safety meeting and review job A. (hand placement and hazards) � P ) 09:00 10:30 1.50 COMPZ RPCOM SLPC P Slip and cut drill line. Page 27 of 39 �rU V v.. n'1... T �..�� e � eo °.4 Phase Cade Skib;6% a S g„a ': •rl"f.�t'a \...:. � ... 10:30 11:30 1.00 COMPZ RPCOM SVRG P Complete rig service and derrick inspection. 11:30 12:30 1.00 COMPZ RPCOM RURD P Rig up BJ reverse circulating line, clear and clean rig floor. 12:30 13:00 0.50 COMPZ RPCOM REAM P Ream to through perforation zone, from 9785 MD to 9857' MD. 13:00 14:30 1.50 COMPZ RPCOM RURD P Install floor valve and head pin in drill pipe, on rig floor. Finish rigging up BJ hard line to floor. 14:30 17:30 3.00 COMPZ RPCOM CIRC P Held safety meeting, Test lines and pump 20 barrels of Flow -vis, 420 gallons of safety pickel and displace with 95 barrels of water till safety pickel is at bottom of drill pipe. 17:30 19:30 2.00 COMPZ RPCOM CIRC P Close Hydril and reverse out safety pickel with 220 barrel of water at 2 barrels a minute. 19:30 20:30 1.00 COMPZ RPCOM OPNW T BJ pump could not inject waste fluid because of pump breakdown. Valves in pump head came apart. Pump heads were tore apart and problem fixed. 20:30 00:00 3.50 COMPZ RPCOM OTHR P Waste pits were all full of waste fluid. We can not proceed with caustic wash untill all waste pits are emptied. Continue to inject waste fluid. 04/04/2009 Pump caustic train using rig pumps at 2 barrels a minute. Pump 20 barrels of fresh water treated with 2 ppb Flow -vis. Then pump 70 barrels of fresh water with 3 ppb caustic. Then 75 barrels of fresh water with 2 drums Safe -Surf W. Then pump 25 barrels of fresh water with 2 ppb Flow -Vis. Then pump 110 barrels of fresh water treated with one drum Filter Floc. Pump all this at 2 Barrels a minute. Circulate well clean with 8.6 ppg brine and 6 % KCL. Drop rabbit and POOH with MI casing cleaning BHA. Pick and make BJ cast iron bridge plug and RIH at 2 minutes a stand. 00:00 03:00 3.00 COMPZ RPCOM OTHR P Waste pits were full of fluid, inject 750 barrels of waste fluid to get ready for caustic wash job. 03:00 06:00 3.00 COMPZ RPCOM CIRC P Pump caustic train using rig pumps at 2 barrels a minute. Pump 20 barrels of fresh water treated with 2 ppb Flow -vis. Then pump 70 barrels of fresh water with 3 ppb caustic. Then 75 barrels of fresh water with 2 drums Safe -Surf W. Then pump 25 barrels of fresh water with 2 ppb Flow -Vis. Then pump 110 barrels of fresh water treated with one drum Filter Floc. Pump all this at 2 Barrels a minute. 06:00 10:30 4.50 COMPZ RPCOM CIRC P Circulate well with clean water. 10:30 13:00 2.50 COMPZ RPCOM CIRC P Displace well with 8.6 ppg, 6% KCL brine at 294 gallons a minute till brine was at 20 NTU or less. 13:00 21:30 8.50 COMPZ RPCOM TRIP P Drop rabbit and POOH with MI casing scraping BHA. Drag up = 134K, Drag Down = 78K Page 28 of 39 E ;2447-7 Su c £ , C&n nt 21:30 00:00 2.50 COMPZ RPCOM TRIP P Held safety meeting. Pick up cast iron bridge plug and RIH at 2 minutes a stand. RIH to 1709' MD. 04/05/2009 RIH with cast iron bridge to 9801' MD. Drop ball and pressure up to 2000 PSI, Pick up and shear out of packer with 12,700 Ibs over pull. Packer set at 9801' MD. Blow down top drive and POOH to surface. Lay down packer setting tool. Rig up Weathrtford equipment and run 4 1/2" Frac string from surface to 2826' MD. 00:00 08:30 8.50 COMPZ RPCOM TRIP P RIH with cast iron bridge plug from 1709' MD to 9801' MD. RIH at two minutes a stand. 08:30 10:00 1.50 COMPZ RPCOM CIRC P Drop 1 7/16" Ball, allowing to fall & seat. Pump at 1 BPM to flush CIBP. Observed ball seat in 52 minutes. Pressure up to 2000 PSI. Pick up to 12,700 Ibs overpull. Observed shear off, and pressure drop. Cast Iron Bridge plug set at 9801' MD. 10:00 17:00 7.00 COMPZ RPCOM TRIP P Blow down top drive and POOH from 9801' MD to surface. Lay down Baker packer running tool. 17:00 18:00 1.00 COMPZ RPCOM TRIP P Rig up Weatherford tubing running equipment. 18:00 00:00 6.00 COMPZ RPCOM RCST P Held safety meeting. RIH with 4 1/2" frac string to 2826' MD. Spill Drill = 65 seconds. Check crown -o -matic 04/06/2009 RIH with 4 1/2' Frac string to 8818' MD, rig down Weatherford tubing equipment. Slip and cut drilling line, service rig. Rig up BJ hard lines to floor and test to 3000 PSI. Pump acid pickle, 20 barrels of flow vis, 550 gallon of 15% HCL @ 1.5 barrels a minute then displace with 117 barrels of 8.6 ppg 6% KCL brine. Close Hydrill and reverse out acid pickle at 2.6 barrels a minute with 8.6 ppg, 6% KCL brine. Circulate and filter brine until we got three NTU readings under 20. Ash fallout from volcano delayed travel for crew changeout. Utilized Boat for personnel. 00:00 06:00 6.00 8,818 8,818 COMPZ RPCOM RCST P RIH with 4 1/2' Frac String, from 2826' MD to 8818' MD. 06:00 07:30 1.50 8,818 8,818 COMPZ RPCOM OTHR P Rig down Weatherford tubing equipment, make up safety valve and clear rig floor. 07:30 09:30 2.00 8,818 8,818 COMPZ RPCOM SLPC P Heal safety meeting, slip and cut drilling line. 09:30 15:30 6.00 8,818 8,818 COMPZ RPCOM OTHR P Off load supply boat with BJ personal and equipment. Finish rigging up BJ hard lines for acid picket job. 15:30 16:00 0.50 8,818 8,818 COMPZ RPCOM SFTY P Held safety meeting for acid pickel. 16:00 18:00 2.00 8,818 8,818 COMPZ RPCOM CIRC P Pressure test lines to 3000 PSI and pump acid pickel. Pump 20 barrels of Flow Vis, 550 gallons of 15% HCL at 1.5 barrels a minute, then displace with 117 barrels of 8.6 ppg, 6% KCL brine. 18:00 00:00 6.00 8,818 8,818 COMPZ RPCOM CIRC P Close Hydril and reverse out acid picket at 2.6 barrels a minute. Change out crew and have safety meeting. Continue to reverse out at 5 barrels a minute. 04/07/2009 Rig up SWS & BJ. Test. Had leaks. Repair same. Page 29 of 39 • t % : . i s From ��'ta.. ' Du€" :.I th E. Death 1 .,.., t or1ment .:: . 00:00 02:00 2.00 8,818 8,818 COMPZ RPCOM RURD P PJSM=Circ. filtered 8.6 ppg 6% KCL to achieve less than 20 ntu,s. 02:00 09:00 7.00 8,818 8,818 COMPZ RPCOM RURD P PJSM =Rig up SWS, Frac head & related equipment. Rig up BJ • um • inq for frac job. 09:00 11:00 2.00 8,818 8,818 COMPZ RPCOM SFTY P Safety Stand Down. 11:00 18:00 7.00 8,818 8,818 COMPZ RPCOM RURD P Off load needed equipment from boat. Review JSA on rig up of frac head, SWS wire line bop,s & lubricator. Finish rigging up BJ lines. Held bucket test on BJ chemical pumps as per completion engineer. Pick up weight bar on E -Line. 18:00 18:30 0.50 8,818 8,818 COMPZ RPCOM PRTS P Test lubricator w/ blank weight bar to 3000 psi. OK 18:30 20:30 2.00 8,818 8,818 COMPZ RPCOM PRTS T Pick up perf guns/ Retest to 3000 psi. Test failed. Trouble shoot leak. 20:30 21:00 0.50 8,818 8,818 COMPZ RPCOM SFTY T PJSM on JSA prior to laying down guns. 21:00 00:00 3.00 8,818 8,818 COMPZ RPCOM RURD T Lay down perforating guns- Lubricator & remove master valve on frac head. Master valve & wing valve failed pressure test. 04/08/2009 Change valves. Perforate well. 00:00 02:30 2.50 8,818 8,818 COMPZ RPCOM OTHR T PTSM= Change out master valve on BJ frac head. Pull wing valve & make up SWS bop,s. 02:30 13:00 10.50 8,818 8,818 COMPZ RPCOM OTHR T Rig maintenance while waiting on boat for new generator for SWS as one on hand shorted out & wing valve for BJ frac head should come out on helicopter this morning. 13:00 16:30 3.50 8,818 8,818 COMPZ RPCOM RURD T Install wing valve on frac head /pick up perforating guns. Make up lubricator & test frac head. 16:30 19:00 2.50 8,818 8,818 COMPZ RPCOM PERF P RIH w/ perforating guns on E- Line - pressure to 3000 psi on annulus. Correlate perforating depths & fire guns. Monitor well 1 hr. (Note - perforated from 9604' to 9624' MD. 6269' TVD top of pert w/ 3 1/8" high volume 6 spf power frac 3106. 20.1 g charge guns.) 19:00 21:30 2.50 8,818 8,818 COMPZ PERF PERF P POH w/ guns. Break otis nipple & check guns. All shots fired. Make up lubricator. 21:30 00:00 2.50 8,818 8,818 COMPZ RPCOM PRTS P PJSM =Test BJ lines to 6000 psi OK 04/09/2009 #1 frac job. Perforate & prep for #2 frac. (Note =Frac #1 injected 824 bbls. fluid in formation. Total to formation 824 bbls.) 00:00 02:00 2.00 8,818 8,818 COMPZ RPCOM OTHR P Complete pumping DFIT w/ 20 bbls. 8.6 ppg 6% KCL.7.7 bpm Max surface treating pressure =3804 psi. max annulus pressure 3528 psi ISIP 3212 psi. Shut in and analize. Mix and gel brine for mini frac. Page 30 of 3 • rrr�e Lo < \.. bat. Fr. . • ;; 1 Pha ..: >• � � �.. Subcode .'T ‘<>,. \\ 02:00 03:00 1.00 8,818 8,818 COMPZ RPCOM OTHR P PJSM. Pump mini -frac. 03:00 06:00 3.00 8,818 8,818 COMPZ RPCOM OTHR P Complete mini frac after pumping 100 bbls of Lightning 2000 crosslinked fluid and flushed with 164.5 bbls 6% KCL at a max rate of 13.3 bpm. Circulated crosslinked fluid to end of frac string at 9.6 bpm. Performed step down during the last 20 bbls of crosslinked fluid at 11.4 bpm, 9.6 b /m, and 4.2 b /m. SD and monitor. Redesign main frac design. Max sfc treating pressure -4135 psi; Max. annulus pressure -3670 psi; ISIP -3260 psi. 06:00 08:00 2.00 8,818 8,818 COMPZ RPCOM OTHR P PJSM= Pumped main fracw /553 bbls. lightning 2000 & flushed w/ 150 bbls. 8.6 ppg 6% KCL @ max rate of 13.2 bpm. Circulated crosslinked fluid to end of frac string @ 8.1 bpm. Closed choke pumped 48000 Ibs 20/40 Carbolite @ max concentration of 5 ppg. placed 43000 Ibs propant in formation, left 5000 Ibs in casing. MSTP =3800 psi. MAP =3300 psi ISP =3122 psi. 08:00 12:00 4.00 8,818 8,818 COMPZ RPCOM OTHR P Monitor well. 12:00 18:00 6.00 8,818 8,818 COMPZ RPCOM ELNE P RIH w/ spent guns & tag sand @ 9430' . POH. Pressure test wellbore to 3000 PSI for 1/2 HR. Pressure held. Bleed pressure to 2500 PSI. WLIH w/ spent guns under 2500 psi on well. Tag sand @ 9441'. POH & continue mix KCL in production pits to build volume for next frac job. 18:00 20:00 2.00 8,818 8,818 COMPZ RPCOM RURD P Lay down spent guns. Make up & pick up new guns. Make up lubricator & test same. 20:00 21:30 1.50 8,818 8,818 COMPZ RPCOM PERF P RIH w/ perforating guns #2. Correlate depth & perf from 9023' to 9040' w/ 3 • 1/8" 6 spf powerfrac 3106 20.1 gram charges. Shut in well pressure when perforate was 1906 psi. Pressure dropped to 1777 psi. 21:30 22:30 1.00 8,818 8,818 COMPZ RPCOM PERF P Monitor well. POH 22:30 00:00 1.50 8,818 8,818 COMPZ RPCOM PERF P Verify all shots fired. Pull spent guns into lubricator & make up lubricator. 04/10/2009 Monitor well & pump kill wt. fluid. 00:00 01:00 1.00 8,818 8,818 COMPZ RPCOM OTHR P PTSM= Monitor well. 01:00 07:00 6.00 8,818 8,818 COMPZ RPCOM OTHR P PJSM =Test lines to 6000 psi. Pump DFIT w/ 25 bbls. 8.6 ppg 6% KCL @ 9.4 bpm MSTP -3857 psi MAP -3280 psi ISIP -3182 psi & Monitor well. Analyze data from DFIT. Page 31 of 3 • • TimekLogs • z • Dade F.e : 4 ® r - , .. i� E. d Buie ._ .. • slew,. � \T.. I'C`I 07:00 10:00 3.00 8,818 8,818 COMPZ RPCOM OTHR P Bleed down well pressure 150 psi every 10 mins. Then let build back. 10:00 18:30 8.50 8,818 8,818 COMPZ RPCOM OTHR P Increase aggression on bleed offs 150 psi every 5 mins. to '0'. Continue to bleed every 5 mins. to '0' to establish kill wt. fluid. While rigging down frac head -SWS & Lubricator. 18:30 20:30 2.00 8,818 8,818 COMPZ RPCOM CIRC P Displace 8.6 ppg in hole w/ 9.4 ppg fluid @ 3 bpm 80 psi 312 bbls. pumped. 20:30 00:00 3.50 8,818 8,818 COMPZ RPCOM OWFF P Monitor well for loss or gain w/ trip tank. 04/11/2009 Pump 9.6 ppg fluid. Lay down 4.5" tbg. 00:00 01:30 1.50 8,818 8,818 COMPZ RPCOM CIRC P Circ. well @ 2.5 bpm w/ 9.4 ppg 6% KCI. 01:30 02:30 1.00 8,818 8,818 COMPZ RPCOM OWFF P Monitor well. Well perculating & small gain of fluid while monitoring. Need to raise fluid density to 9.6 ppg to obtain 50-60 psi overbalance or safety margin. 02:30 06:00 3.50 8,818 8,818 COMPZ RPCOM OTHR P Monitor well while increasing fluid wt. to 9.6 ppg. 06:00 07:30 1.50 8,818 8,818 COMPZ RPCOM CIRC P Displace 9.4 ppg in hole w/ 9.6 ppg 6% KCL. 07:30 08:30 1.00 8,818 8,818 COMPZ RPCOM OWFF P Monitor well while rigging up weatherford tbg. handling equipment. 08:30 10:00 1.50 8,818 8,818 COMPZ RPCOM CIRC P Well out of balance. Circ. till balance. 10:00 10:30 0.50 8,818 8,818 COMPZ RPCOM OWFF P Monitor well. PJSM w/ weatherford on laying down 4.5" tbg. 10:30 13:00 2.50 8,818 8,100 COMPZ RPCOM PULD P POH laying down 4.5" 12.6# L -80 BTM tbg. from 8818' MD to 8100'. 13:00 14:00 1.00 8,100 8,100 COMPZ RPCOM SFTY P Abandon Platform Drill. 14:00 01:00 11.00 8,100 3,131 COMPZ RPCOM PULD P Laying down 4.5" tbg. from 8100' MD to 3131' MD. (Total jts. Down 188.) 04/12/2009 Make up CIBP & RIH. No Test POH. 00:00 06:00 6.00 3,131 0 COMPZ RPCOM PULD P PTSM= Monitor well & lay down 4.5" 12.6# L -80 BTCM tbg. from 3131' MD to '0'. Rig down tbq. equipment. 06:00 19:00 13.00 0 8,944 COMPZ RPCOM TRIP P Make up Baker CIBP & RIH 2 min. per stand drifting DP from derrick to 8944' MD. 19:00 19:30 0.50 8,944 8,944 COMPZ RPCOM PACK P Drop ball. Chase ball w/ 1.5 bpm pressure to 2000 psi. Pull 13k over to shear out. (CIBP set @ 8944' DPM ) 19:30 21:30 2.00 8,944 8,944 COMPZ RPCOM DHEQ P Test CIBP to 3000 psi (No Test) Check all surface equipment. Grease 2 stem leaks. Retest (No Test) Surface equipment OK. 21:30 00:00 2.50 8,944 7,045 COMPZ RPCOM TRIP T POH for RTTS packer from 8944' to 7045'. 04/13/2009 POH. Run RTTS. Test. Displace. POH 00:00 05:30 5.50 7,045 0 COMPZ RPCOM TRIP T PTSM =POH from 7045' to '0' Page', 32 of 39 1 • Date From ira�� .To ' Our $. Depth E. l,th Phase rC� � :�?bcode T 05:30 07:30 2.00 0 2,000 COMPZ RPCOM PULD T Make up Haliburton RTTS packer & RIH to 2000' MD. 07:30 09:00 1.50 2,000 2,000 COMPZ RPCOM PRTS T Test downhole bridge plug & surface equipment. Test held 3000 psi 30 mins. each OK. 09:00 11:00 2.00 2,000 0 COMPZ RPCOM TRIP T POH & lay down RTTS. Clear rig floor. 11:00 12:00 1.00 0 2,077 COMPZ RPCOM TRIP T Make up mule shoe & RIH to 2077'. 12:00 12:30 0.50 2,077 2,077 COMPZ RPCOM SVRG P Service top drive. 12:30 18:00 5.50 2,077 8,930 COMPZ RPCOM TRIP T RIH from 2077' to 8930' 18:00 19:30 1.50 8,930 8,930 COMPZ RPCOM CIRC P Reverse out 9.6 ppg KCL to 8.6 ppg KCL. @ 4 bpm 19:30 20:30 1.00 8,930 8,930 COMPZ RPCOM OWFF P Observe well. Fluid out of balance. 20:30 22:00 1.50 8,930 8,930 COMPZ RPCOM CIRC P Circ. well till Fluid is balanced in well. 22:00 00:00 2.00 8,930 7,299 COMPZ RPCOM TRIP P POH from 8930' to 7299'. 04/14/2009 Finish POH. Test BOPE. Pick up guns. 00:00 04:00 4.00 7,299 678 COMPZ RPCOM TRIP P POH from 7299' to 678' for BOPE test & pick up haliburton perforating guns. 04:00 05:30 1.50 678 678 COMPZ RPCOM SLPC P PJSM= Slip & cut 72' drlg. line. 05:30 06:00 0.50 678 0 COMPZ RPCOM TRIP P POH from 678' to '0'. For BOPE test. 06:00 09:00 3.00 0 0 COMPZ RPCOM PRTS P Rig up & pull wear ring. Pull bell nipple & set test plug. Prblem with test plug going thru annular preventer. 09:00 18:30 9.50 0 0 COMPZ RPCOM PRTS P Testing all BOPE & Koomey unit 250 -3500 psi. Lay down test jt. & test plug. Set wear bushing. Flow nipple & catch can. 18:30 19:00 0.50 0 0 COMPZ RPCOM SFTY P PJSM w/ haliburton & crews on running perforating guns. 19:00 00:00 5.00 0 1,214 COMPZ RPCOM PULD P Pick up & make up 49 haliburton perforating guns. Size 4 5/8" 14 spf SH guns. 221' loaded guns. 1214' overall. 04/15/2009 RIH. POH change tools. RIH. Perforate & circ. 00:00 04:00 4.00 1,214 4,880 COMPZ RPCOM TRIP P RIH w/ perforating guns on DP. from 1214' to 4880'. Filling DP every stand. 04:00 05:00 1.00 4,880 4,880 COMPZ RPCOM OTHR T Fluid running over DP. Assumed probably air. Monitor & no air worked out. Pick up & fluid dropping down annulus. Below packer vent possibly opened up. 05:00 07:30 2.50 4,880 1,214 COMPZ RPCOM TRIP T POH to change out tool from 4880' to 1214' MD. 07:30 08:30 1.00 1,214 1,214 COMPZ RPCOM PULD T Lay down packer & below packer vent, '0' ring was leaking. Pick up new packer & below packer vent. Page 33of39 1 • T 4ogs :. too Frsm To thr" .1$`Mep}th E Depth Phase _ Code , va° comment ..r,o ....a ....... \ \\ 08:30 18:30 10.00 1,214 8,246 COMPZ RPCOM TRIP T RIH w/ haliburton perforating guns from 1214' to 8246' MD. Left 1732' of drill pipe dry for underbalance. 18:30 19:30 1.00 8,246 8,246 COMPZ RPCOM SFTY P PJSM w/ SWS =rig up lubricator. 19:30 22:00 2.50 8,246 8,246 COMPZ RPCOM ELOG P RIH w/ E -Line. Correlate perforating depth. POH & rig down SWS. 22:00 23:00 1.00 8,246 8,246 COMPZ RPCOM PERF P PJSM =Set Packer pressure up on annulus 3500 psi. Fire guns. (Perforate from 7161' MD to 8228' MDw /14spf) 23:00 00:00 1.00 8,246 8,246 COMPZ RPCOM CIRC P Open bypass on packer & reverse circ. untill NTU,s down to -20 04/16/2009 Work NTU,s to 20-45 POH w/ guns. (Daily downhole fluid losses 325 bbls. Total 962 bbls.) 00:00 02:00 2.00 8,246 8,246 COMPZ RPCOM CIRC P Reverse circ. @ 2.5 bpm working NTU,s down to -20. 02:00 02:30 0.50 8,246 8,246 COMPZ RPCOM OTHR P Release Hawco packer. 02:30 03:00 0.50 8,246 8,212 COMPZ RPCOM OWFF P Pull from 8246' to 8212' & monitor well on trip tank ( hole taking 17 bbls. per hr.). 03:00 04:30 1.50 8,212 8,212 COMPZ RPCOM CIRC P Circulate and filter brine at 3 bpm. NTU +80 04:30 06:00 1.50 8,212 8,212 COMPZ RPCOM OTHR P Clean Filter Press. (Circ. across top of hole w/ trip tank monitoring losses while cleaning filter press. 17 bph loss 06:00 16:00 10.00 8,212 8,212 COMPZ RPCOM CIRC P Circ and filter brine at 4 bpm. Initial NTU - 80. Max NTU - 149. Final NTU stabilized at 45. 16:00 00:00 8.00 8,212 1,800 COMPZ RPCOM TRIP P POH w/ Hawco perforating guns to 1800'. 04/17/2009 POH. Lay down guns. Pick up clean out assembly & RIH. Circ. & clean hole. 00:00 01:00 1.00 1,800 1,214 COMPZ RPCOM TRIP P POH to packer assembly @ 1214' MD. ( Fluid losses to hole @ 11 bph.) 01:00 02:00 1.00 1,214 1,150 COMPZ RPCOM PULD P Lay down packer assembly & 2 jts. 2 7/8" tbg. 02:00 05:00 3.00 1,150 0 COMPZ RPCOM PULD P PJSM =Lay down Hawco perforating guns. 05:00 05:30 0.50 0 0 COMPZ RPCOM OTHR P Clear & clean floor of Hawco perforating gun equipment. 05:30 06:00 0.50 0 0 COMPZ RPCOM SFTY P PJSM on making up clean out assembly. 06:00 10:00 4.00 0 7,095 COMPZ RPCOM TRIP P Make up clean out assembly consisting of Junk mill - Ridgeback burr mill- Magnets- Razorback Scraper -Well Patroller & Ported By Pass. Run in hole to 7095' MD. 10:00 15:00 5.00 7,095 8,296 COMPZ RPCOM REAM P Wash & Ream from 7095' to 8296' MD. 15:00 16:00 1.00 8,296 8,296 COMPZ RPCOM CIRC P Circ. hole clean @ 6 bpm 337 bbls. @ 700 psi. 16:00 17:30 1.50 8,296 8,944 COMPZ RPCOM TRIP P Run in hole from 8296' to 8944' MD. Tag CIBP. 17:30 20:00 2.50 8,944 8,914 COMPZ RPCOM CIRC P Revese circ. @ 4 bpm 800 psi. NTU,s 48 Page 34 of 39 • TIE ' L© g s ? � .. . • a ‘17..' .. ub oode T n te . � :.rarra ;; ,' i)ur �� E. ® „t :God � �.: 4‘‘ \� ... ... 20:00 00:00 4.00 8,914 8,914 COMPZ RPCOM CIRC P Change to circ. long way 6 bpm @ 800 psi. to clean up NTU,s. 14/18/2009 Circ. hole to get NTU,s down. POH Lay down Swaco clean out tools. Pick up 10 jts. 3.5" tbg. & sump packer. 00:00 01:00 1.00 8,914 8,914 COMPZ RPCOM CIRC P Circ. long way to clean up NTU,s. to 30 01:00 05:00 4.00 8,914 7,080 COMPZ RPCOM TRIP P POH above perforations @ 7166'. Pump out, hole tight w/ possibly sand around clean out tools. 05:00 06:00 1.00 7,080 7,080 COMPZ RPCOM CIRC P Cleaning filter press. Monitor well on trip tank. Service rig. 06:00 07:00 1.00 7,080 7,080 COMPZ RPCOM SLPC P PJSM= Slip & cut 85' drlg. line. Adjust compensators. 07:00 10:00 3.00 7,080 7,080 COMPZ RPCOM CIRC P Rotate & reciprocate @ 9 bpm 1440 psi. 41 bph hole losses while circ. 10:00 11:00 1.00 7,080 8,265 COMPZ RPCOM TRIP P RIH from 7080 to 8265' MD. Hole is clean. No tight spots. 11:00 11:30 0.50 8,265 7,095 COMPZ RPCOM TRIP P POH to 7095' MD No tight spots. 11:30 13:00 1.50 7,095 7,095 COMPZ RPCOM CIRC P Circ. @ 7 bpm 890 psi to lower NTU,s. NTU,s dropped to under 10. 13:00 21:30 8.50 7,095 0 COMPZ RPCOM TRIP P POH to lay down Swaco clean out tools from 7095' to '0'. 21:30 00:00 2.50 0 318 COMPZ RPCOM PULD P Rig up & pick up 10jts. 3 1/2" tbg. & sump packer. 64/19/2009 RIH w/ sump packer. Set same & POH. Run screens. 00:00 08:00 8.00 318 8,243 COMPZ RPCOM TRIP P RIH w/ Baker sump packer from 318' MD to 8243' MD Pick up & put pipe in tension. 08:00 09:30 1.50 8,243 8,243 COMPZ RPCOM RURD P PJSM =Rig up SWS wireline & lubricator. 09:30 11:30 2.00 8,243 8,243 COMPZ RPCOM ELNE P Wireline correlation log. 11:30 12:00 0.50 8,243 8,243 COMPZ RPCOM RURD P Rig down wireline equipment & drop 1 7/16" ball. let fall for 30 mins. 12:00 13:00 1.00 8,243 8,238 COMPZ RPCOM OTHR P Pressure up & set sump packer © 8238' WLM w/1200 psi & shear out w/ 170k. 13:00 21:00 8.00 8,238 0 COMPZ RPCOM TRIP P POH from 8238' to '0'. Lay down setting tool. 21:00 00:00 3.00 0 0 COMPZ RPCOM RURD P PJSM =Rig up floor to run screens. 14/20/2009 Run screens on DP land same. Set Packer & prep for Gravel pack. Page 35 of 39 1 • Ti ' Iogs \ \ ? \fie Da Roe To D tr .. .th. EADellitt Phi `C€ e...;. Sdlicode T :.Co ent 00:00 03:00 3.00 0 1,215 COMPZ RPCOM SCRN P Running Excluder 2000 4" 11# P -110 SLHT screens & Blank pup jts. to 1215. (Run 28 screens & 7 blank pup + 1 full jt. blank.) Note :Some slight damage to the shroud on the second to last full joint of screen was observed. The damage appeared to be caused by a large blunt object, possibly crushing by a heavy weight. This was the second to last screen in the assembly and therefore, on the bottom of the basket. It is quite possible the damage was caused by the way the screens were stacked. The shroud openings were not fully closed so it deemed OK to run. This was based on previous testing of the Baker Excluder 2000 screens when various modes of damage were tested and it was determined that as long as the shroud opening is not fully crimped closed, damage to the mesh is not expected. 03:00 04:00 1.00 1,215 1,215 COMPZ RPCOM PULD P Rig up to run 2 7/8" 6.4# 511 hydril inner string. 04:00 06:00 2.00 1,215 1,215 COMPZ RPCOM SCRN P Run inner string into screens. (38 jts.) 06:00 07:30 1.50 1,215 1,215 COMPZ RPCOM RURD P Make up seal assembly & rig down tbg. equipment. 07:30 15:00 7.50 1,215 8,238 COMPZ RPCOM TRIP P RIH from 1215 to 8238' MD. Drift DP while RIH. Latch into sump packer. 15:00 19:00 4.00 8,238 8,238 COMPZ RPCOM OTHR P Unlatch from sump packer. Change bails & elevators. Install link tilt clamps. Space out & latch up. Pump 5 bbls. to clean ball seat. Drop ball. 19:00 21:00 2.00 8,238 8,238 COMPZ RPCOM RURD P Rig up BJ hard lines on rig floor. 21:00 22:30 1.50 8,238 8,238 COMPZ RPCOM PRTS P PJSM =Test lines to 6000 psi. Set packer w/ 1900 - 2500 -3100 psi. hold each pressure 5 mins. & bleed each pressure to '0'. Pull test packer to 175k. 22:30 23:00 0.50 8,238 8,238 COMPZ RPCOM PRTS P Test annulus 500 psi 5 mins. Pressure to 2500 psi to release packer. Mark all tool positions as per Baker rep. 23:00 00:00 1.00 8,238 COMPZ RPCOM CIRC P Reverse circ. ball out @ 5 bpm w/ 630 psi for 155 bbls. Remove ball & catcher from 3" BJ hard line. 04/21/2009 Pressure test lines. Peform injection test and gravel pack. Reverse out sand and filter brine. Rig down gravel pack lines. Pull above KOIV. Lay down frac head. Pull out of the hole. Off load boat. Rig up and lay down 2 -7/8" inner string. 00:00 00:30 0.50 8,238 8,238 COMPZ RPCOM PRTS P PJSM =Fill BJ hard lines & test same. Page 36 of 39 • • e. 47.tme Logs � From ' D . � S. t eeth' E Deb&Phase ;- Subcade T omment 00:30 02:00 1.50 8,238 8,238 COMPZ RPCOM GRVL P Injection test. Circulation Test & gravel Pack. Pumped the gravel pack at 11.1 BPM with returns at 3.1 BPM (28% returns) and screened out with 13, 688 lbs of sand below the gravel pack port, which equates to 17 lbs/ft of perfs. Screened out at approx 4000 psi. Reversed out 3,000 lbs of sand. 02:00 06:00 4.00 8,238 8,238 COMPZ RPCOM CIRC P Pulled into reverse position & reversed out sand. Circ. to get NTU,s down to -20. 06:00 09:30 3.50 8,238 8,238 COMPZ RPCOM CIRC P Reverse circulate at 5 bpm. NTU value stabilized at 50. 09:30 09:45 0.25 8,238 8,238 COMPZ RPCOM SFTY P PJSM on RD BJ equipment. 09:45 11:30 1.75 8,238 7,039 COMPZ RPCOM TRIP P RD BJ line. POH with 18 stds DP. Losses were approx 140 bph. Shut off hole fill for 5 min. Close annular and IBOP. Strip out w/ 4" DP until 2 7/8" inner string was above KOIV. Open annular. Fill annulus. Monitor well. Static. KOIV is holding. 11:30 12:00 0.50 7,039 7,039 COMPZ RPCOM PULD P Make up single. Break out pup, TIW and head pin. 12:00 13:30 1.50 7,039 7,039 COMPZ RPCOM OTHR P Change out bails. Install link tilt clamps and elevators. 13:30 17:00 3.50 7,039 7,039 COMPZ RPCOM TRIP P Pull out of the hole to 1298' 17:00 19:30 2.50 7,039 7,039 COMPZ RPCOM OTHR P Finish off loading 4 -1/2" tubing from the boat, monitor well 19:30 21:30 2.00 7,039 7,039 COMPZ RPCOM OTHR P Clear catwalk and lay down packer running tool 21:30 22:00 0.50 7,039 7,039 COMPZ RPCOM RURD P Rig up Weatherford 22:00 00:00 2.00 7,039 7,039 COMPZ RPCOM PULD P Lay down 2 -7/8" inner string 04/22/2009 Finish laying down 2 -7/8" inner string. Pull wear ring. Cut and slip 66 ft. of drill line. Rigged up and ran 4 -1/2" production tubing and jewelry. Spotted 130 bbl inhibitted brine in annulus. Spaced out and made up tubing hanger. Connected conrol lines and landed hanger. Tested hanger to 5000 psi. Laid down landing joint. Rigged up Pollard wireline and pulled dummy sleeve in BP6i nipple. Rigged down wire line. Made up landing joint and dropped ball and rod. Rigged down wireline. Tested tubing to 3500 pis for 5 minutes -OK. Pressure tested annulus to 3500 psi for 30 minutes -OK. Installed BPV. Laid down mouse hole and pulled rotary table. Rigged down flowline and bell nipple. 00:00 00:30 0.50 7,039 7,039 COMPZ RPCOM PULD P Finish POH and LD 2 7/8" innerstring. 00:30 01:00 0.50 7,039 7,039 COMPZ RPCOM RURD P RD 2 7/8" equipment. Clear floor. Pull wear bushing. 01:00 02:00 1.00 7,039 7,039 COMPZ RIGMNT SVRG P PJSM. Slip and cut 66' of drilling line. 02:00 02:15 0.25 7,039 7,039 COMPZ RPCOM SFTY P PJSM on running 4 1/2" completion equipment. 02:15 03:00 0.75 7,039 7,039 COMPZ RPCOM RURD P RU 4 1/2" tbg equipment. 03:00 08:30 5.50 7,039 7,039 COMPZ RPCOM RCST P RIH w/ 4 1/2" completion equipment as per plan to jt #165. 08:30 09:30 1.00 7,039 7,039 COMPZ RIGMNT SVRG P Service rig while verifying valve in the #6 GLM. Page 37 of 39 • \\ \\ �\ Time Loat. "OR 1.4 , From T6 Dur S. De , �\\ p#h ` Deoth Phan.. Code .: ��= e � °�. men ;< < 09:30 11:00 1.50 7,039 7,039 COMPZ RPCOM RCST P Continue RIH w/ 4 1/2" completion. Total of 207 jts in hole. MU 4.5 BP6i nipple. 11:00 12:00 1.00 7,039 7,039 COMPZ RPCOM SSSV P Rig up control line for SSSV 12:00 13:00 1.00 7,039 7,039 COMPZ RPCOM RCST P Continue running 4 -1/2" completion. Ran a total of 221 joints of tubing 13:00 14:30 1.50 7,039 7,039 COMPZ RPCOM HOSO P Latch into packer at 7039'. Space out 14:30 15:30 1.00 7,039 7,039 COMPZ RPCOM CRIH P Spot 130 bbl of inhibitted brine in annulus 15:30 16:30 1.00 7,039 7,039 COMPZ RPCOM THGR P Make up tubing hanger. Connect and test control line. Installed control line with 18 ea.5 /8" stainless steel clamps 16:30 17:30 1.00 7,039 7,039 COMPZ RPCOM THGR P Land hanger and test to 5000 psi for 10 minutes 17:30 18:30 1.00 7,039 7,039 COMPZ RPCOM PULD P Lay down landing joint and test hanger to 5000 psi for 10 minutes 18:30 20:00 1.50 7,039 7,039 COMPZ RPCOM SLKL P Rig up slick line. Pull dummy sleeve from BP6i nipple at 491.5'. Rig down slick line 20:00 21:00 1.00 7,039 7,039 COMPZ RPCOM RURD P Make up landing joint. Drop ball and rod. Lay down landing joint 21:00 22:00 1.00 7,039 7,039 COMPZ RPCOM PRTS P Pressure test tubing to 3500 psi for 5 minutes. Pressure test annulus to 3500 psi for 30minutes. Installed BPV. 22:00 00:00 2.00 7,039 7,039 COMPZ RPCOM NUND P Lay down mouse hole and pull rotary. Nipple down flow line and bell nipple 04/23/2009 Nipple down BOPE, choke /kill lines and riser. Nipple up tree. Pull BPV and set two -way check. Test tree to 5000 psi. Pull two -way check. Rig up slickline. Attempt to test lubricator without success. Change o -rings in lubricator. Retest lubricator to 1000 psi -OK. Attempt to pull ball and rod without success. Make 2nd run and pull ball and rod. Retrieve RHC catcher. (Tagged fluid level at 1730'.) Run in hole with chisel to 7300'. No indication of KOIV at 7073'. Make 2nd pass to verify KOIV broken. Run in hole with SSSV and set @ 492'. Test control line to 5000 psi. Rig down slick line and release rig at 2400 hrs 4/23/2009 to move to NCIU A -15. 00:00 04:00 4.00 7,039 7,039 COMPZ RPCOM NUND P Nipple down BOPE, choke /kill lines, and riser 04:00 06:00 2.00 7,039 7,039 COMPZ RPCOM NUND P Prep to nipple up tree 06:00 12:00 6.00 7,039 7,039 COMPZ RPCOM NUND P Clean well head room. Nipple up tree and orient per Production rep. Pull BPV and install 2 -way check 12:00 14:00 2.00 7,039 7,039 COMPZ RPCOM PRTS P Tighten flange. Test tree to 5000 psi for 10 minutes. Pull 2 -way check 14:00 16:00 2.00 7,039 7,039 COMPZ RPCOM RURD P Rig up slick line and lubricator. Attempt to test. Drain lubricator and chenge o- rings. Test lubricator to 1000 psi. 16:00 17:00 1.00 7,039 7,039 COMPZ RPCOM SLKL P Run in the ole and attempt to pull ball and rod without success 17:00 19:00 2.00 7,039 7,039 COMPZ RPCOM SLKL P Swap tools and run in the hole. Retrieve ball and rod. 19:00 20:30 1.50 7,039 7,039 COMPZ RPCOM SLKL P Swap tools and run in the hole. Retrieve RHC catcher. Slickline tagged fluid at 1730'. Page 38 of 39 • From rf ,;• - Our S. [)ep E: ase` Code \C !Cie ., T Oomen# .._ :� Date - \.... �T ®• �� 20:30 21:30 1.00 7,039 7,039 COMPZ RPCOM SLKL P Run in the hole with chisel on slickline. Attempt to pressure up on tubing without success. Run throug KOIV with chisel without hitting anything. Make 2nd pass through KOIV. 21:30 22:30 1.00 7,039 7,039 COMPZ RPCOM SLKL P Change tools and set SSSV. Test control line to 5000 psi. 22:30 00:00 1.50 7,039 7,039 COMPZ RPCOM SLKL P Rig down slickline and release rig from NCIU A -14 to NCIU A -15 Page 39 of 39 i Hole Section (inc Batch Interval Time Drilling Depths (ft) Casing Mud Weight (ppg) Well Start End Start End Section TD Reached Size (in) )epth Set (f Date Set Start End A -16 12 1/4 7/11/2008 8/2/2008 400 4546 7/29/2008 9 5/8 4535 8/1/2008 8.9 9.3 A -15 12 1/4 8/2/2008 8/14/2008 400 4303 8/10/2008 9 5/8 4291 8/13/2008 8.8 9.2 --1 A -14 12 1/4 8/14/2008 8/29/2008 400 4756 8/22/2008 9 5/8 4747 8/25/2008 8.8 9.1 A -15 8 3/4 8/29/2008 9/27/2008 4303 8867 9/12/2008 7 8832 9/25/2008 9.15 10.1 A -16 8 3/4 9/28/2008 10/30/2008 4546 9314 10/16/2008 7 9256 10/25/2008 9.35 9.4 --P A -14 8 3/4 10/31/2008 12/1/2008 4756 11501 11/13/2008 7 9978 11/26/2008 9.2 9.9 A -16 Completions 12/1/2008 Ongoing • III 1 NCIU A -14 (PTD 208 -096) C,letion Page 1 of 1 Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA) Sent: Friday, April 10, 2009 9:49 AM To: 'Braden, John C' Cc: Jasser, Rami; Eggemeyer, Jerome C.; Freedman, Kerry C Subject: RE: NCIU A -14 (PTD 208 -096) Completion John, et al, Either method is acceptable. Tom Maunder, PE AOGCC From: Braden, John C [mailto: John .C.Braden @conocophillips.com] Sent: Friday, April 10, 2009 9:26 AM To: Maunder, Thomas E (DOA) Cc: Jasser, Rami; Eggemeyer, Jerome C.; Freedman, Kerry C Subject: NCIU A -14 (PTD 208 -096) Completion Tom - We are completing NCIU A -14 (PTD 208 -096). We are attempting to complete the lower Beluga zones (Beluga I- R). We fractured the Beluga Q (9603 -9632' MD) earlier this week. The results of the fracture treatment indicated 0.02 to 0.04 mD. The next zone (Beluga M at 9023- 9040'MD) indicated between 0.02 and 0.07 mD. These were two of the best zones in the lower Beluga in A -14. Our plan is to complete up hole in the Beluga B through I. The Beluga Q perfs (9603- 9632'MD) are covered with sand and held a 3000 psia pressure test prior to shooting the Beluga M perfs (9023- 9040'MD), which are currently exposed. We plan to isolate the Beluga M perfs from the new completion interval with a CIBP. An alternative would be to place a tailpipe with an X- nipple in the sump packer. Please confirm that either method of isolation is acceptable. Sincerely, John C. Braden Cook Inlet Development ConocoPhillips Alaska, Inc. (907) 263 -4536 phone (907) 265 -1441 fax john .c.braden @conocophillips.com 4/10/2009 • • Page 1 of 1 Maunder, Thomas E (DOA) From: Hayden, Philip [Philip .Hayden ©conocophillips.comj Sent: Monday, April 06, 2009 11:14 AM To: Maunder, Thomas E (DOA); Braden, John C Cc: Regg, James B (DOA) Subject: RE: Inlet Operations Tom, We have had to stop operations only intermittently since the volcano first erupted. Looking at our daily reports we have recorded just -20 hours of down time due to this. The biggest impact so far has been the limited number of helicopter flights. However, we are able to manage our personnel transfers via our supply boat MN Champion. Regards Philip From: Maunder, Thomas E (DOA) [mailto:tom.maunder @alaska.gov] Sent: Monday, April 06, 2009 11:03 AM To: Braden, John C; Hayden, Philip Cc: Regg, James B (DOA) Subject: Inlet Operations John and Philip, Could you please provide information of how Mt. Redoubt's activity is or is not affecting CPAI's production and drilling operations on Tyonek Platform? Thanks in advance. Tom Maunder, PE AOGCC 4/22/2009 Page 1 of 1 Maunder, Thomas E (DOA) From: Braden, John C [ John .C.Braden @conocophillips.com] Sent: Monday, April 06, 2009 11:13 AM To: Maunder, Thomas E (DOA); Hayden, Philip; Tyonek Supervisor Cc: Regg, James B (DOA) Subject: RE: Inlet Operations Philip can weigh in as well. It is mostly affecting helicopter traffic, delaying crew changes. Barge traffic has slowed a bit. We are making some crew changes by boat. John Braden From: Maunder, Thomas E (DOA) [mailto:tom.maunder @alaska.gov] Sent: Monday, April 06, 2009 11:03 AM To: Braden, John C; Hayden, Philip Cc: Regg, James B (DOA) Subject: Inlet Operations John and Philip, Could you please provide information of how Mt. Redoubt's activity is or is not affecting CPAI's production and drilling operations on Tyonek Platform? Thanks in advance. Tom Maunder, PE AOGCC 4/22/2009 Tyonek platform activity • • Page 1 of 1 Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA) Sent: Monday, March 23, 2009 10 :56 AM To: Hayden, Philip Subject: RE: Tyonek platform activity Thanks much Philip. From: Hayden, Philip [mailto:Philip .Hayden @conocophillips.com] Sent: Monday, March 23, 2009 10:55 AM To: Maunder, Thomas E (DOA) Subject: Tyonek platform activity Tom, Currently we are running completion operations on well A -15. We finished TCP ops over the weekend and today should be PU the clean out assembly prior to running gravel pack screens. We finished operations on A -16 on 2/24/09. We should be moving onto A -14 at the end of the month. No impact from Mt Redoubt just yet apart from some delayed flights from Anchorage & potential helicopter flight restrictions. Regards Philip 4/22/2009 • Conoco Phillips TRANSMITTAL CONFIDENTIAL DATA FROM: Sandra D. Lemke, AT01486 TO: Christine Mahnken ConocoPhillips Alaska, Inc. State of Alaska - AOGCC P.O. Box 100360 333 W. 7 Avenue, Suite 100 Anchorage, Alaska 99501 -3539 RE: North Cook Inlet A -14 DATE: 02/12/2008 Hand car — Transmitted: I Upper Cook Inlet, Alaska NCI Unit A -14 1508832012500 Report and CDROM Final Well Report, Mud Logging Data, NCUI A -14; Epoch, report date: 11/13/2008; table of contents, equipment and crew, well data, geological data, pressure /strength data, drilling data, daily reports, formation logs; Color log prints: Mud Log MD and TVD 4757 - 11501' LWD Combo Log MD and TVD 4757 - 11501' Gas Ratio Log MD and TVD 4757 - 11501' Drilling Dynamics MD and TVD 4757 - 11501' CDROM contains: well report, morning reports, LAS data, PDF and tiff format color log image files; DML and lithology remarks. CC: Rick Levinson, CPAI Geologist 17 1 d _ I . Receipt .. L Date: i T i - h ic- P r^ ,� - c,f- ?/ ;C7.2555947 .,mow ✓' s.�. r :;� -'_:� :l . �.�r .. � e...r�� ; a:Y. rrP. ',� �,�7iC.:'�s.A�I�� Alaska � Ph: Sant]tia D. Lemknoco(3/ a ss coom 30.2r —646, r' -5 NCIU A -16, Permit to Drill # 4 -098, Update 1/9/09 • Page 1 of 2 Maunder, Thomas E (DOA) From: Hayden, Philip [Philip .Hayden @conocophillips.com] Sent: Wednesday, January 21, 2009 10:16 AM To: Maunder, Thomas E (DOA) Cc: Chambers, Mark A Subject: RC: NCH A -10, Pa iiiul k Di ill # 208 -098, Update 1/9/09 Attachments: Operations Summary 1- 21- 09.xls Tom. \■) — � C)SS OC With reference to your note below: 1. At this time we are still looking at ice conditions & boat availability in the Inlet in order to determine the best path forward. We expect to have a decision made some time this week whether to proceed with completion operations or to suspend until later in the Spring. I will send you an update when we have that decision. 4. Please see the attached spreadsheet for a summary of operations so far on the Tyonek for all three wells. Please let me know if you need any more information Regards Philip From: Maunder, Thomas E (DOA) [mailto :tom.maunder @alaska.gov] Sent: Tuesday, January 20, 2009 1:26 PM To: Hayden, Philip Cc: Chambers, Mark A Subject: RE: NCIU A -16, Permit to Drill # 208 -098, Update 1/9/09 Philip, Thanks for calling. I had no questions or comment regarding your message of January 9. However, due to the Monarch incident, I now have some. 1. When does it look like operations will be resuming on NCIU A -16 and the other wells? 2. If this is in the short term, 1 don't believe that any sundry paperwork is needed. It had been stated in the plans that the wells would be "batched" and that is what you have /are accomplishing, although the entire process has been delayed by the broken Whitaker and now the Monarch. 3. If it looks like operations won't be resumed until toward 2nd quarter, then some paperwork might need to be submitted. 4. For my info, could you summarize how the operations were accomplished on the 3 wells? Thanks in advance. Call or message with any questions. Tom Maunder, PE AOGCC From: Hayden, Philip [mailto: Philip .Hayden @conocophillips.com] Sent: Friday, January 09, 2009 9:16 AM To: Maunder, Thomas E (DOA) Subject: NCIU A -16, Permit to Drill # 208 -098, Update 1/9/09 Tom, 1/22/2009 NCIU A -16, Permit to Drill # 4 -098, Update 1/9/09 • Page 2 of 2 wanted to bring you up to speed with operations on the Tyonek. Due to the ice in the inlet we are unable to get supplies & equipment to the rig in order to continue with completion operations. We have decided to "warm stack" the rig until next week when we will revisit the situation. The well status is as follows: 7" production casing set at 9301' MD, cemented & pressure tested to 4500 psi 4 1/2" tubing string run to 8400' MD Casing displaced to 6% KCI brine @ 8.6 ppg Tubing hanger run, landed & tested BPV installed BOPs still installed If our "warm stack" period is extended we are not planning on any further BOP tests until we recommence operations. Our rationale is that the formations are currently isolated with two barriers - cemented & tested 7" casing and the tested tubing hanger /BPV - and that the BOPs are not required for well control at this time. Please let me know if you have any comments on this or need any further information. Regards Philip 1/22/2009 WELL LOG TRANSMITTAL To: State of Alaska December 17, 2008 Alaska Oil and Gas Conservation Comm. Attn.: Librarian 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: MWD Formation Evaluation Logs: NCIU A -14 AK -MW- 5744712 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Bryan Burinda, Sperry Drilling Services, 6900 Arctic Blvd., Anchorage, AK 99518 NCIU A -14 2" x 5" MD RESISTIVITY & GAMMA RAY Logs: 1 Color Log 50- 883 - 20125 -00 2" x 5" TVD RESISTIVITY & GAMMA RAY Logs: 1 Color Log 50- 883 - 20125 -00 Digital Log Images 1 CD Rom 50- 883 - 20125 -00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry Drilling Services Attn: Bryan Burinda 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: (907)273 -3536 r •(907135 -� ,, • Dater Signed: uy • • WELL LOG TRANSMITTAL To: State of Alaska December 16, 2008 Alaska Oil and Gas Conservation Comm. Attn.: Librarian 333 West 7 Avenue, Suite 100 Anchorage, Alaska 99501 -3539 RE: MWD Formation Evaluation Data: NCIU A -14 AK -MW- 5744712 The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the attention of: Bryan Burinda, Sperry Drilling Services, 6900 Arctic Blvd., Anchorage, AK 99518 1 LDWG formatted CD Rom with verification listing. API #: 50- 883 - 20125 -00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry Drilling Services Attn: Bryan Burinda 6900 Arctic Blvd. Anchorage, Alaska 99518 Off ce (9A ; 273.,526 r _ CO- )0.73`8515 j , ,, , ( ' Date ` , ., , 7::,;:j Signed: L.=-- r 0 0 Halliburton Sperry Drilling Services 6900 Arctic Blvd Anchorage, AK 99518 December 19, 2008 Christine Mahnken State of Alaska Alaska Oil and Gas Conservation Commission 333 W. 7th Ave., #100 Anchorage, Alaska 99501 -3539 Dear Sir or Madam: Subject: NCIU A -14 Definitive Survey Enclosed is one hard copy of the definitive well path. Also enclosed is a disc containing an electronic export of the survey data. Please acknowledge kin n H Ili n. m or b receipt by sending an email to Steve.Par so a burto co P Y 9 @ by signing and returning a copy of this letter to the following address: Halliburton Sperry Drilling Services ATTN: Steve Parkinson 6900 Arctic Blvd Anchorage, AK 9 18 Received by: alkd' Date: 6 J«`. .Z Cl d q Please contact me at 907.273.3534 with questions or concerns. Regards, Pete Schiermeier Enclosure(2) Tyonek Progress 1 /5/09 • Page 1 of r Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA) Sent: Tuesday, January 06, 2009 11:19 AM To: Regg, James B (DOA) Subject: RE: Tyonek Progress 1/5/09 The Whitaker life boat/capsule. Apparently it was damaged in a collision by the boat in mid - December. From: Regg, James B (DOA) Sent: Tuesday, January 06, 2009 10:10 AM To: Maunder, Thomas E (DOA) Subject: RE: Tyonek Progress 1/5/09 life sphere? Jim Regg AOGCC 333 W.7th Avenue, Suite 100 Anchorage, AK 99501 907 - 793 -1236 From: Maunder, Thomas E (DOA) Sent: Tuesday, January 06, 2009 10:05 AM To: DOA AOGCC Prudhoe Bay Subject: FW: Tyonek Progress 1/5/09 Some info on activities or not on Philips Tyonek platform. Tom From: Hayden, Philip [mailto: Philip .Hayden @conocophillips.com] Sent: Tuesday, January 06, 2009 9:50 AM To: Maunder, Thomas E (DOA) Subject: RE: Tyonek Progress 1/5/09 I believe the next BOP test is due on Monday, 1/12, but we may try and bring that forward so as not to clash with fracing operations. Yet to be decided though. Yes, you are correct. The work on A -16 was severely curtailed due to the damaged lifesphere. We did manage to pickle our DP, caustic wash the casing and displace to brine while waiting for the lifesphere to be replaced. But instead of hours each of these operations took days instead due to the reduced man count. The lifesphere was damaged on the night of Monday 12/15 and I can confirm that the new one was certified good for use yesterday, 1/5. Again, please let me know if you need any more info Philip From: Maunder, Thomas E (DOA) [mailto:tom.maunder @alaska.gov] 4/22/2009 Tyonek Progress 1/5/09 Page 2 of,3r • Sent: Tuesday, January 06, 2009 9:25 AM To: Hayden, Philip Subject: RE: Tyonek Progress 1/5/09 Philip, Thanks for the summary/update. I'd expect that there will be a BOP test coming as operations resume. I presume that the work on A -16 was interrupted by the damage to the life sphere? When was the sphere damaged? Tom From: Hayden, Philip [mailto:Philip .Hayden @conocophillips.com] Sent: Tuesday, January 06, 2009 9:18 AM To: Maunder, Thomas E (DOA) Subject: RE: Tyonek Progress 1/5/09 Please see below a summary status of the wells: A -14, Permit to Drill # 208 -096: 8 3/4" hole drilled to 11501' MD. 7" casing set & cemented at 9980' MD. Temporarily suspended while continuing with batch completion operations on A -16. A -15, Permit to Drill # 208 -097: 8 3/4" hole drilled to 8867' MD. 7" casing set & cemented at 8833' MD. Temporarily suspended while continuing with batch completion operations on A -16. A -16, Permit to Drill # 208 -098: 8 3/4 hole drilled to 9314' MD. 7" casing set & cemented at 9301' MD. Pumped acid pickle for 4" drill pipe. Pumped caustic wash for 7" casing. Well displaced to 6% KCI brine. 4 1/2" treating string run to 8400' MD. Currently waiting on equipment in order to begin perforating & fracing operations. As you can see none of the wells have been completed at this point. The plan is to complete A -16 first followed by A -15 & 14. If operations resume soon we will hopefully have A -16 finished by the end of this month. Please let me know if you need any of this filled out. Philip From: Maunder, Thomas E (DOA) [mailto:tom.maunder @alaska.gov] Sent: Tuesday, January 06, 2009 8:15 AM To: Hayden, Philip Subject: RE: Tyonek Progress 1/5/09 Thanks Philip. If you wouldn't mind, could you give a status update on the wells? I show the permits were issued about July 4 and there has been some 403 and 404 activity since then, however I don't show that I have seen a 407 yet. That doesn't mean that a 407 may not have been filed, just that I haven't gotten to it yet. Tom From: Hayden, Philip [mailto:Philip .Hayden @conocophillips.com] Sent: Monday, January 05, 2009 7:14 PM To: Maunder, Thomas E (DOA) Subject: Tyonek Progress 1/5/09 Tom, Sorry for not getting back to you sooner. I tried your office phone but it was late so I didn't catch you. The replacement life sphere was offloaded from the boat on Saturday and should have been certified for use earlier today. The plan is to start manning up as soon as possible. However, operations are still waiting on two boat loads that we are struggling to deliver to the platform due to the ice. At this point a resumption of operations doesn't look likely until Wednesday/Thursday at the earliest. 4/22/2009 Tyonek Progress 1/5/09 • Page 1 of 2 Maunder, Thomas E (DOA) From: Hayden, Philip [Philip .Hayden @conocophillips.com] Sent: Tuesday, January 06, 2009 9:50 AM To: Maunder, Thomas E (DOA) Subject: RE: Tyonek Progress 1/5/09 I believe the next BOP test is due on Monday, 1/12, but we may try and bring that forward so as not to clash with fracing operations. Yet to be decided though. Yes, you are correct. The work on A -16 was severely curtailed due to the damaged Iifesphere. We did manage to pickle our DP, caustic wash the casing and displace to brine while waiting for the Iifesphere to be replaced. But instead of hours each of these operations took days instead due to the reduced man count. The Iifesphere was damaged on the night of Monday 12/15 and I can confirm that the new one was certified good for use yesterday, 1/5. Again, please let me know if you need any more info Philip From: Maunder, Thomas E (DOA) [mailto:tom.maunder @alaska.gov] Sent: Tuesday, January 06, 2009 9:25 AM To: Hayden, Philip Subject: RE: Tyonek Progress 1/5/09 Philip, Thanks for the summary/update. I'd expect that there will be a BOP test coming as operations resume. I presume that the work on A -16 was interrupted by the damage to the life sphere? When was the sphere damaged? Tom From: Hayden, Philip [mailto:Philip .Hayden @conocophillips.com] Sent: Tuesday, January Janua 06, 2009 9:18 AM To: Maunder, Thomas E (DOA) Subject: RE: Tyonek Progress 1/5/09 Please see below a summary status of the wells: A -14, Permit to Drill # 208 -096: 8 3/4" hole drilled to 11501' MD. 7" casing set & cemented at 9980' MD. Temporarily suspended while continuing with batch completion operations on A -16. A -15, Permit to Drill # 208 -097: 8 3/4" hole drilled to 8867' MD. 7" casing set & cemented at 8833' MD. Temporarily suspended while continuing with batch completion operations on A -16. A -16, Permit to Drill # 208 -098: 8 3/4 hole drilled to 9314' MD. 7" casing set & cemented at 9301' MD. Pumped acid pickle for 4" drill pipe. Pumped caustic wash for 7" casing. Well displaced to 6% KCI brine. 4 1/2" treating string run to 8400' MD. Currently waiting on equipment in order to begin perforating & fracing operations. As you can see none of the wells have been completed at this point. The plan is to complete A -16 first followed by A -15 & 14. If operations resume soon we will hopefully have A -16 finished by the end of this month. Please let me know if you need any of this filled out. 1/6/2009 Tyonek Progress 1/5/09 • • Page 2 of 2 Philip From: Maunder, Thomas E (DOA) [mailto:tom.maunder @alaska.gov] Sent: Tuesday, January 06, 2009 8:15 AM To: Hayden, Philip Subject: RE: Tyonek Progress 1/5/09 Thanks Philip. If you wouldn't mind, could you give a status update on the wells? I show the permits were issued about July 4 and there has been some 403 and 404 activity since then, however I don't show that I have seen a 407 yet. That doesn't mean that a 407 may not have been filed, just that I haven't gotten to it yet. Tom From: Hayden, Philip [mailto:Philip .Hayden @conocophillips.com] Sent: Monday, January 05, 2009 7:14 PM To: Maunder, Thomas E (DOA) Subject: Tyonek Progress 1/5/09 Tom, Sorry for not getting back to you sooner. I tried your office phone but it was late so I didn't catch you. The replacement life sphere was offloaded from the boat on Saturday and should have been certified for use earlier today. The plan is to start manning up as soon as possible. However, operations are still waiting on two boat Toads that we are struggling to deliver to the platform due to the ice. At this point a resumption of operations doesn't look likely until Wednesday/Thursday at the earliest. Please let me know if you need any more information. Philip 1/6/2009 12/15/08 SclImb rue NO. 4992 Schlumberger -DCS 2525 Gambell Street, Suite 400 Company: Alaska Oil & Gas Cons Comm Anchorage, AK 99503 -2838 Attn: Christine Mahnken ATTN: Beth 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: North Cook Inlet Well Job # Log Description Date BL Color CD NCIU A -14 AXML - 00003 FORMATION EVALUATION SONIC SCANNER 11115108 1 NCIU A -14 AXML-00003 FMI 11/15/08 1 NCIU A-14 AXML - 00003 MDT 11/18/08 1 NCIU A -14 AXML -00003 CEMENT EVALUATION 11/29/08 1 S NCIU A -14 AXML -00003 OH LDWG EDIT 11/15/08 2 1 ^ \ \1 n` • Please sign and return one copy of this transmittal to Beth at the above address or tax to (907) 561-8317. Thank you. NCIU A -14 Permit # 208 -096 Iodate 11/26/08 • Page 1 of 2 Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA) Sent: Wednesday, November 26, 2008 3:44 PM To: 'Hayden, Philip' Subject: RE: NCIU A -14 Permit # 208 -096 Update 11/26/08 Philip, It is unfortunate that the casing was not able to reach TD. It is likely that the 9.9 ppg will provide isolation in the open hole. Good luck with the remaining operations. Tom Maunder, PE AOGCC From: Hayden, Philip [mailto:Phihip .Hayden @conocophillips.com] Sent: Wednesday, November 26, 2008 3:26 PM To: Maunder, Thomas E (DOA) Subject: NCIU A -14 Permit # 208-096 Update 11/26/08 Tom, An update on operations on NCIU A -14 on the Tyonek platform: 9 5/8" Casing set at 4747' MD & cemented to surface 8 3/4" hole drilled to 11501' MD Ran 7" to 9982' MD where it became differentially stuck Mud in the hole is 9.9 ppg 7" casing was cemented in place with shoe at 9982' MD Full retums during the cement job Plugs were bumped on calculated strokes Planned TOC is 3445' MD 7" casing was successfully pressure tested to 4150 psi for 30 minutes Although intervals of interest were identified below the current 7" shoe depth none were planned on being produced in this well The 7" casing is the final casing string on this well and it is not planned to drill out the shoe Plan ahead: WOC 15 hours & compressive strength build up to +500 psi Break connection between BOP stack & wellhead after confirming well is dead Set emergency slips & pack off MU BOP & test connection Run USIT bond log Run 4 1/2" kill string with tubing hanger ND BOPs NU dry hole tree Begin move to next well 12/1/2008 NCIU A -14 Permit # 208 -096 liate 11/26/08 Page 2 of 2 • Please let me know if you need any further information Regards Philip II 12/1/2008 BOP Close in Kuukpik 5 • • Page 1 of 3 Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA) Sent: Monday, September 08, 2008 10:20 AM To: DOA AOGCC Prudhoe Bay Subject: FW: BOP Close in Kuukpik 5 - -NCIU A -15 (208 -097) FYI From: Hayden, Philip [mailto:Philip .Hayden @conocophillips.com] Sent: Monday, September 08, 2008 10:06 AM To: Maunder, Thomas E (DOA) Cc: Chambers, Mark A Subject: RE: BOP Close in Kuukpik 5 Surface casing is set & cemented on all three wells. -i—P A -14 (208 -096) @ 4748 ft MD A -15 (208 -097) @ 4290 ft MD A -16 (208 -098) @ 4536 ft MD A -15 is currently the only well drilled beyond the surface pipe. Plan ahead is to drill A -15 to TD. Log, run & cement pipe. Run a kill string. Skid to A -16 & repeat. Skid to A -14 and repeat. Completion operations will be conducted in the following order: A -16, A -15 & A -14. This is the current plan but there are ongoing discussions about changing it for gas delivery optimisation etc. Philip From: Maunder, Thomas E (DOA) [mailto:tom.maunder @alaska.gov] Sent: Monday, September 08, 2008 9:51 AM To: Hayden, Philip Cc: Chambers, Mark A Subject: RE: BOP Close in Kuukpik 5 Thanks Philip. I sort of figured it likely was the Beluga. I know doing the jack up work that there always was the risk of finding a virgin sand due to the discontinuous nature of the intervals. If you wouldn't mind, could you provide a status of where the 3 wells are out there and the forward plans? As I remember batch drilling was planned. Thanks in advance. Tom Maunder, PE AOGCC From: Hayden, Philip [mailto:Philip .Hayden @conocophillips.com] Sent: Monday, September 08, 2008 9:42 AM To: Maunder, Thomas E (DOA) Cc: Chambers, Mark A Subject: RE: BOP Close in Kuukpik 5 Tom, 9/8/2008 BOP Close in Kuukpik 5 • . Page 2 of 3 Well: A -15 on Tyonek Depth of initial shut -in: 7245 ft MD / 5946 ft TVD Last casing shoe: 4290 ft MD FIT at shoe: 16 ppg Formation: Logs correlate this depth to a coal section with potential sand in the Beluga formation Let me know if you need any more information. Philip From: Maunder, Thomas E (DOA) [mailto:tom.maunder @alaska.gov] Sent: Monday, September 08, 2008 9:26 AM To: Hayden, Philip Cc: Chambers, Mark A Subject: RE: BOP Close in Kuukpik 5 Philip or Mark, What well was being drilled and what are the specifics regarding depth, last casing shoe, formation being drilled and anything else of interest. Thanks in advance. Tom Maunder, PE AOGCC From: Regg, James B (DOA) Sent: Monday, September 08, 2008 8:49 AM To: Maunder, Thomas E (DOA); Grimaldi, Louis R (DOA) Subject: FW: BOP Close in Kuukpik 5 fyi Jim Regg AOGCC 333 W.7th Avenue, Suite 100 Anchorage, AK 99501 907 - 793 -1236 From: Kuukpik 5 Company man [ mailto :KUUK5CM @conocophillips.com] Sent: Saturday, September 06, 2008 5:10 PM To: Regg, James B (DOA) Cc: Chambers, Mark A; Hayden, Philip Subject: BOP Close in Kuukpik 5 Mr Regg, As you requested, here is brief review of BOP shut in Kuukpik 5, 9/5/08. At approximately 10:00 AM, gas bubbling was noted during connection. No attending flow. Annular BOP was closed as precautionary measure. No pressure. Several rounds circulation were made through choke, increasing mud wt 9.2 to 9.8 ppg. At one point, ceased pumping to clear plugged chokes. Pressure built to 360 on DP / 240 on csg. Four more complete circulations were made afterwards. Checked pressures, open well, flow check. Well static. Three more complete circulations, insure welibore balanced. 9/8/2008 BOP Close in Kuukpik 5 S Page 3 of 3 Resumed drilling ahead 0200 hrs 9/6/08. Plans are to test all components held against pressures as instructed by Mr Lou Grimaldi first trip out of hole. Regards Dave Morris Co Man Tyonek Platform, Kuukpik 5, well A -15 9/8/2008 ! 40 ID ,.., . 717 ir. .,i,--- c FA n [ (1) pi?' i trA (_11) j ° - 0,2) LA\ i SARAH PALIN, GOVERNOR ALASKA OIL AND GAS 333 W. 7th AVENUE, SUITE 100 CONSERVATION COMMISSION ANCHORAGE, ALASKA 99501 -3539 PHONE (907) 279 -1433 C. Alvord FAX (907) 276 -7542 Drilling Team Lead ConocoPhillips Alaska Inc. PO Box 100360 Anchorage, AK 99510 -0360 Re: North Cook Inlet Field, Tertiary System Gas Pool, NCIU A -14 ConocoPhillips Alaska Inc. Permit No: 208 -096 Surface Location: 1302' FNL, 1019' FWL, SEC. 6, T11N, R9W Bottomhole Location: 4001' FNL, 1045' FEL, SEC. 30, T12N, R9W Dear Mr. Alvord: Enclosed is the approved application for permit to drill the above referenced development well. The permit is approved subject to full compliance with 20 AAC 25.055. Approval to perforate and produce is contingent upon issuance of a conservation order approving a spacing exception. ConocoPhillips assumes the liability of any protest to the spacing exception that may occur. 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. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659 -3607 (pager). Sincerely, 0 Daniel T. Seamount, Jr. '1 Chair DATED this 2_ day of July, 2008 cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. STATE OF ALASKA RECEIVED ALA* OIL AND GAS CONSERVATION COMIION ' JUN 1 0 2008 PERMIT TO DRILL it 20 AAC 25.005 OiL i Cas Cons. Commission la. Type of Work: 1b. Current Well Class: Exploratory ❑ Development Oil ❑ 1c. Specify if we? • . po . Drill 111 Redrill ❑ Stratigraphic Test ❑ Service ❑ Development Gas 0 Coalbed Methane ❑ ANO9Rages ❑ Re -entry ❑ Multiple Zone 0 Single Zone ❑ Shale Gas ❑ 2. Operator Name: 5. Bond: Blanket 0 Single Well ❑ 11. Well Name and Number: ConocoPhillips Alaska Inc. Bond No. 5952180 NCIU A -14 3. Address: 6. Proposed Depth: 12. Field /Pool(s): P.O. Box 100360 Anchorage, AK 99510 -0360 MD: 12277 TVD: 7916 North Cook Inlet 4a. Location of Well (Governmental Section): 7. Property Designation: Surface: `1302' FNL 1019' FWL SEC 6 T11N R9W ' ADL 17589 / ADL 37831' Tertiary System Gas Pool ' Top of Productive Horizon: 8. Land Use Permit: 13. Approximate Spud Date: 4303' FNL 2661' FEL SEC 31 T12N R9W N/A 7/15/2008 Total Depth: 9. Acres in Property: 14. Distance to Nearest 4001' FNL 1045' FEL SEC 30 T12N R9W 3326 (ADL 37831) Pro rt : 844' D 1 589) . 4b. Location of Well (State Base Plane Coordinates): 10. KB Elevation 15. Distance to Nearest Well 4 Surface: x- 332038 y- 2586677 t Zone- 4 (Height above GL): 116 , feet Within Poo: � C 10A)4•a"c� 16. Deviated wells: Kickoff depth: 5D9 1 et 17. Maximum Anticipated Pressures in psig (see 20 AAC 25.035) G•i2 t& Maximum Hole Angle: A k4' Mtegrees Downhole: 3744 psi • Surface: 2600 psi 18. Casing Program: Specifications Top - Setting Depth - Bottom Cement Quantity, c.f. or sacks Hole Casing Weight Grade Coupling Length MD TVD MD TVD (including stage data) NA 30" 354 46 46 400 400 Existing 12 1/4" 9 5/8" 40# L -80 BTCM 4557 46 46 4603 3449 2047 sx 12 ppg Lightweight 8 3/4" 7" 26# L -80 BTCM 12231 46 46 12277 7916 560 sx 10.5 ppg Lightweight 4 1/2" 12.6# L -80 IBTM 4846 46 46 4892 3599 Production Tubing 19. PRESENT WELL CONDITION SUMMARY (To be completed for Redrill and Re -Entry Operations) Total Depth MD (ft): Total Depth TVD (ft): Plugs (measured): Effect. Depth MD (ft): Effect. Depth TVD (ft): Junk (measured): Casing Length Size Cement Volume MD TVD Conductor /Structural Surface Intermediate Production Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): 20. Attachments: Filing Fee Q BOP Sketch isi Drilling Program e Time v. Depth Plot ❑ Shallow Hazard Analysis ❑ Property Plat 0 Diverter Sketch 0 Seabed Report ❑ Drilling Fluid Program 0 20 AAC 25.050 requirements 0 21. Verbal Approval: Commission Representative: Date 22. I hereby certify that the foregoing is true and correct. Contact P. Hayden elhir Printed Name /Ad' C. Alvord op j, 4 Title Drilling Team Lead Signature i.- aZ-_____ Phone 7 4 �' _ / f, Date ,j4. - f,, -, Commission Use Only Permit to Drill / API Nuber. ,, Permit Approval See cover letter for other Number: �� p m 50- f 3 r -. 20/ Z ? " Date: . a IA 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: E Other: \.. Samples req'd: Yes❑ Nolg Mud log req'd: Yes No[] _« + - z l H measures: Yes No[✓] Directional svy req'd: Yes[' No `ate St Vtip5 , _$..w.\E Ov Itt 1'4 4 6,,, APPROVED BY THE COMMISSION 2' Q DATE: . COMMISSIONER Form 10 -4 1 Revised 12/2005 Submit in Duplicate ConocoPhillips Alaska, Inc Post Office Box 100360 Conoco Phillips Anchorage, Alaska 99510 -0360 C p Telephone 907 - 276 -1215 June 10, 2008 Alaska Oil and Gas Conservation Commission 333 West 7 Avenue, Suite 100 RECENED Anchorage, Alaska 99501 JUN 1 0 2008 Re: Application for Permit to Drill: NCIU A -14, Planned spud 7/15/08 NCIU A -15, PI slapia+ at/ t'$ �' iss iott NCIU A -16, Planned spuel*WFtii Dear Sir or Madam: ConocoPhillips Alaska, Inc. hereby applies for Permits to Drill three offshore development gas wells from the Tyonek platform in the Cook Inlet. The wells are designed to penetrate the Beluga sands, log, evaluate and be completed as gravel pack gas producers. Please note that due to the fact that we are drilling from a platform we are unable to meet the requirement set out in 20 AAC 25.035 (c) (2) (C) (ii) that the diverter vent line extend to a point at least 75 ft beyond the drill rig substructure. While drilling on diverter the vent line will extend beyond the rig substructure and the platform structure but will not meet the above requirement. In addition we propose to test the BOPE to 3500 psi — during the drilling phase of this program, raising this to 5000 psi when completion operations begin. The higher completion test pressure is due to the planned high formation treatment pressures. Please find attached for the review of the Commission Forms 10 -401 and the information required by 20 ACC 25.005 for these wells. If you have any questions or require further information, please contact Philip Hayden at 265 -6481 or Chip Alvord at 265 -6120. Si r y, Philip Hayden, Drilling Engineer cc: NCIU A -14 Well File NCIU A -15 Well File NCIU A -16 Well File Chip Alvord ATO -1570 Mark Chambers ATO -1566 John Braden ATO -1392 Marta Czarneski Kenai LNG plant ORIGINAL Application for Peep Drill, Wells NCIU A -14, A -15, A -16 Revision No.O Saved: 9- Jun -08 Permit It - NCIU Wells A -14, A -15, A -16 66 +'t Application for Permit to Drill Document MaxWell Mpxializ$ well Value Table of Contents 1. Well Name 2 Requirements of 20 AAC 25.005 (f) 2 2. Location Summary 2 Requirements of 20 AAC 25.005(c)(2) 2 Requirements of 20 AAC 25.050(b) 3 3. Blowout Prevention Equipment Information 3 Requirements of 20 AAC 25.005(c)(3) 3 4. Drilling Hazards Information 3 Requirements of 20 AAC 25.005 (c)(4) 3 5. Procedure for Conducting Formation Integrity Tests 5 Requirements of 20 AAC 25.005 (c)(5) 5 6. Casing and Cementing Program 5 Requirements of 20 AAC 25.005(c)(6) 5 7. Diverter System Information 7 Requirements of 20 AAC 25.005(c)(7) 7 8. Drilling Fluid Program 7 Requirements of 20 AAC 25.005(c)(8) 7 9. Abnormally Pressured Formation Information 8 Requirements of 20 AAC 25.005 (c)(9) 8 10.Seismic Analysis 8 Requirements of 20 AAC 25.005 (c)(10) 8 11.Seabed Condition Analysis 8 Requirements of 20 AAC 25.005 (c)(11) 8 12. Evidence of Bonding 8 Requirements of 20 AAC 25.005 (c)(12) 8 Tyonek 2008 PERMIT IT.doc Page 1 of 19 O R L Printed. 9- Jun -08 • Application for Per. Drill, Wells NCIU A -14, A -15, A -16 Revision No.0 Saved: 9- Jun -08 13. Proposed Drilling Program 9 Requirements of 20 AAC 25.005 (c)(13) 9 14. Discussion of Mud and Cuttings Disposal and Annular Disposal 11 Requirements of 20 AAC 25.005 (c)(14) 11 15.Attachments 11 1. Well Name Requirements of 20 AAC 25.005 (f Each well must be identified by a unique name designated by the operator and a unique API number assigned by the commission under 20 AAC 25.040(b). For a well with multiple well branches, each branch must similarly be identified by a unique name and API number by adding a suffix to the name designated for the well by the operator and to the number assigned to the well by the commission. The wells for which this Application is submitted will be designated as: NCIU A -14 NCIU A -15 • NCIU A -16. 2. Location Summary Requirements of 20 AAC 25.005(c)(2) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application; (2) a plat identifying the property and the property's owners and showing (A)the coordinates of the proposed location of the well at the surface, at the top of each objective formation, and at total depth, referenced to governmental section lines. (B) the coordinates of the proposed location of the well at the surface, referenced to the state plane coordinate system for this state as maintained by the National Geodetic Survey 117 the National Oceanic and Atmospheric Administration; (C) the proposed depth of the well at the top of each objective formation and at total depth; Well A -14 A -15 A -16 RKB Elevation (ft AMSL) 116 116 116 1302' FNL, 1311' FNL, 1304' FNL, Section Lines 1019' FWL, 1018' FWL, 1016' FWL, Location at Section 6, Section 6, Section 6, Surface T11 N, R9W, T11 N, R9W T11 N, R9W ASP Zone 4 2586677 N, 2586668 N, 2586675 N, NAD 27 332038 E 332037 E 332035 E Coordinates 4303' FNL, 2904' FNL, 4988' FNL, Section Lines 2661 FEL, 2752' FEL, 1100' FEL, Section 31, Section 6, Section 36, T12N, R9W T11 N, R9W T12N, R10W Location at ASP Zone 4 2588937 N, 2585057 N, 2588302 N, Top Cook NAD 27 333410 E 333274 E 329942 E Inlet Coordinates True Vertical 3599 3591 3566 Depth (ft) Measured 4892 4458 4784 Depth (ft) Tyonek 2008 PERMIT IT.doc rft Page Printed: 9-Jun-08 08 Application for Pe,. Drill, Wells NCIU A -14, A -15, A -16 Revision No.O Saved: 9- Jun -08 4001' FNL, 4874' FNL, 4104' FNL, 1045' FEL, 1318' FEL, 2217' FEL, Section Lines Section 30, Section 6, Section 36, T12N, R9W T11 N, R9W T12N, R1 OW Location at ASP Zone 4 2594495 N, 2583067 N, 2589202 N, TD NAD 27 335092 E 334684 E 328838 E Coordinates True Vertical 7916 7741 7616 Depth (ft) Measured 12277 9285 9298 Depth (ft) and (D) other information required by 20 AAC 25.050(b); Requirements of 20 AAC 25.050(b) Ifa well is to be intentionally deviated, the application for a Permit to Drill (Form 10 -401) must (1) include a plat, drawn to a suitable scale, showing the path of the proposed wellbore, including all adjacent wel /bores within 200 feet of any portion of the proposed well; Please see Attachment 1 for the Directional Plans and (2) for all wells within 200 feet of the proposed wellbore (A) list the names of the operators of those wells, to the extent that those names are known or discoverable in public records, and show that each named operator has been furnished a copy of the application by certified mail; or (B) state that the applicant is the only affected owner. The Applicant is the only affected owner. 3. Blowout Prevention Equipment Information Requirements of 20 AAC 25.005(c)(3) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (3) a diagram and description of the blowout prevention equipment (ROPE) as required by 20 AAC 25.035, 20 AAC 25.036, or 20 AAC 25.037, as applicable; An API 13 -5/8" x 5,000 psi BOP stack (RSRRA) will be utilized to drill and complete all three wells. Please see Attachment 2 for details on this equipment. It is our intention to test the BOPE to 3500 psi during the drilling phase of operations and increase this to 5000 psi during completion. The higher completion test pressure is due to the high treatment pressures of the completion operations (reverse circulating after screen out of the gravel pack). 4. Drilling Hazards Information Requirements of 20 AAC 25.005 (c)(4) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (4) information on drilling hazards, including (A) the maximum downho/e pressure that may be encountered, criteria used to determine it, and maximum potential surface pressure based on a methane gradient; The expected reservoir pressures in the Cook Inlet sands in the area of interest are expected to be as low as 0.1 psi /ft, or 2 ppg EMW (equivalent mud weight). In the Beluga sands the expected pore pressure ranges from 0.312 to 0.44 psi /ft (6 to 8.5 ppg EMW). These pressures are based on actual field pressure measurements taken in existing wells. Maximum Anticipated Surface Pressure and Casing Design: The following information is used for calculation of the maximum anticipated surface pressures for the planned well: O R 1 G 1 4. a T 2008 PERMIT IT.doc JA Printed: J n08 Printe: 9Jun -08 • Application for Pern•Drill, Wells NCIU A -14, A -15, A -16 Revision No.O Saved: 9- Jun -08 Casing Size Casing Setting Depth Maximum Pore Pore Pressure MASP Drilling Pressure Gradient 30" 400' MD / 400' TVD 8.6 ppg 180 NA 9 -5/8" 3600' TVD 9.0 ppg 1685 206 psi 7" 8000' TVD 9.0 ppg 3744 2600 psi Expected Maximum Mud Weights: • 12 -1/4" surface hole to 3600' TVD (maximum): 10.0 ppg MW, pore pressures of up to 9.0 ppg may be present. • 8 -3/4" production hole to 8000' TVD (maximum): 9.6 ppg. The pore pressure is not expected to be above 9 ppg from offset drilling data and depletion due to production Procedure for Calculating Maximum Anticipated Surface Pressure: MASP is determined as the lesser of 1) surface pressure at breakdown of the formation at the casing seat with a gas gradient to the surface, or 2) formation pore pressure at the next casing point Tess a gas gradient to the surface as follows: 1) MASP = [(FG x 0.052) — 0.11] x D Where: MASP = Maximum Anticipated Surface Pressure FG = Fracture Gradient at the casing seat in lb/gal 0.052 = Conversion factor from lb/gal to psi /ft 0.11 = Gas Gradient in psi /ft (above 10,000' TVD) D = True vertical depth to casing seat in ft from RKB OR 2) MASP = FPP — (0.11 x D) Where: FPP = Formation Pore Pressure at the next casing seat MASP Calculations 1. Drilling below 30" Conductor Casing MASP = [(FG x 0.052) — 0.11] x D = [(12.0 x 0.052) — 0.11] x 400' = 206 psi OR MASP = FPP — (0.11 x D) = 1685 — (0.11 x 3600') = 1289 psi 2. Drilling below 9 -5/8" Surface Casing MASP= [(FG x 0.052) — 0.11] x D = [(16 x 0.052) — 0.11] x 3600' = 2600 psi OR MASP = FPP — (0.11 x D) = 3744 — (0.11 x 8000') R ! ; - ,1 Tyonek 2008 PERMIT IT.doc n LJ f ��1 � te dJ 8 ' Printed: : 9- Jun n-08 Application for Pe. Drill, Wells NCIU A -14, A -15, A -16 Revision No.O Saved: 9- Jun -08 = 2864 psi (8) data on potential gas zones; All the wells are planned to be gas producers. There should be no gas zones above the top of the Cook Inlet formation. and (C) data concerning potential causes of hole problems such as abnormally geo-pressured strata, lost circulation zones, and zones that have a propensity for differential sticking; Well Proximity Risks: Due to the close well spacing of the wells on the platform and the congestion immediately underneath the conductors there are several well proximity risks. The following tabulates the proximity risks and some of the mitigating measures to be used when drilling these three wells: Drilling Does plan Well(s) at Status of Close Approach Wireline Tubing & Annuli Well: pass Major Risk Wells at Risk Depth (ft TVD) plugs set annuli Monitoring Risk? in tubing bled down A -16 Yes None NA NA NA NA NA A -15 No A -09 Producing 467 Yes Yes Yes A -10A Producing 468 Yes Yes Yes A -14 No A -11 P&A'd 743 No No Yes A -16 Surface Pipe 425 -500 NA NA Yes In addition to the above the probability of collision is reduced by: 1. A high accuracy gyro will be used when drilling the surface hole of all three wells in order to closely monitor their trajectories 2. Wells with proximity risks have been resurveyed using a high accuracy gyro to verify their position with respect to the planned well paths. Wells resurveyed are: a. A -09 b. A -10A c. A -11 d. A -13 3. . Rig site anti- collision diagrams (traveling cylinders) will be prepared 4. Close approach will be discussed and highlighted in the well plan, at pre -spud meetings, and rig site planning, daily ops and tour meetings For other drilling hazards please see Attachment 3. 5. Procedure for Conducting Formation Integrity Tests Requirements of 20 AA C 25.005 (c)(5) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (5) a description of the procedure for conducting formation integrity tests, as required under 20 AAC25.030(f); All wells will be completed with 9 5/8" intermediate casing landed above the Cook Inlet. The casing shoe will be drilled out and a formation integrity test will be performed in accordance with the "Formation Integrity Test Procedure" that ConocoPhillips Alaska placed on file with the Commission. 6. Casing and Cementing Program Requirements of 20 AAC 25.005(c)(6) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: • OR !c' Tyonek 2008 PERMIT IT.doc � d Printed: 9-Jun-08 Application for PeDrill, Wells NCIU A -14, A -15, A -16 Revision No.O Saved: 9- Jun -08 (6) a complete proposed casing and cementing program as required by 20 AMC 25.030, and a description of any slotted liner, pre - perforated liner, or screen to be installed; Casing Design Performance Properties Size Hole Weight Grade Conn. Internal Collapse Tensile Strength Yield Joint Body 30" NA 9 -5/8" 12.25 40 ppf L -80 BTCM 5750 psi 3090 947 M 916 M 7" 8.75 26 ppf L -80 BTCM 7240 psi 5410 641 M 604 M Casing Setting Depth Rational: 30" @ 400' TVD RKB Conductor casing (platform leg pile) provides sufficient anchor for diverter system and subsequent wellhead. 9 -5/8" © 3450' TVD RKB Surface casing to provide good anchor for BOPE and sufficient fracture gradient and well control while drilling 8 -3/4" hole through the reservoir sands 7" @ 7600 - 8000' TVD RKB Production casing is near the bottom of the Beluga sands to provide pressure integrity and zonal isolation. Cementing Program: 9 5/8" Surface Casing Cement from surface hole TD to surface with a lightweight 12 ppg slurry. Assumed 100% excess annular volume. Slurry Density 12.0 Yield (ft /sack) 2.1 Volumes ft /ft 400 ft 30" Conductor 4.08 12 1 /4" Open hole (add 100% excess) 0.3132 Shoe track 0.4257 System: Type I Cement + 0.9% bwoc BA -90 + 0.05% bwoc Static Free + 25% bwoc LW -6 + 0.6% bwoc CD -32 + 0.1% bwoc FL -52 + 1 gal /100sk FP -6L + 0.4% bwoc Sodium Metasilicate + 5% bwoc MPA -1 + fresh water 7" Production Cement from production hole TD to 500' MD above the Top of the Cook Inlet formation with lightweight 10.5 ppg cement. Assume 40% excess annular volume. Slurry Density 10.5 Tyonek 2008 PERMIT IT.doc ", vvv Ili fff YYY ! 1 Page 6 of 19 Printed: 9- Jun -08 Application for Per Drill, Wells NCIU A -14, A -15, A -16 Revision No.O Saved: 9- Jun -08 Yield (ft /sack) 2.99 Volumes ft /ft 9 5/8" Cased hole 0.1585 8 3 /4" Open hole (add 40% excess) 0.1503 Shoe track 0.2148 System: Class G Cement + 15% bwoc BA -90 + 0.05% bwoc Static Free + 1% bwoc CD -32 + 1.2% bwoc FL -52 + 1 gals /100 sack FP -6L + 0.6% bwoc Sodium Metasilicate + 22% bwoc LW -7 -6 + Fresh Water If there are problems with lost circulation during drilling, logging or tripping, consideration will be made to including a hydraulic opening stage tool in the casing string to help ensure cement coverage of the Cook Inlet formation. 7. Diverter System Information Requirements of 20 AAC 25.005(c)(7) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (7) a diagram and description of the diverter system as required by 20 AAC 25.035, unless this requirement is waived by the commission under 20 AAC 25.035(h)(2); A 21 -1/4 ", 2000 psi annular with a 16" diameter diverter line will be the diverter system used in the drilling of these wells. Please note that due to the fact that we are drilling from a platform we are unable to meet the requirement set out in 20 AAC 25.035 (c) (2) (C) (ii) that the diverter vent line extend to a point at least 75 ft beyond the drill rig substructure. While drilling on diverter the vent line will extend beyond the rig substructure and the platform structure but will not meet the above requirement. Please see Attachment 2 for details of the diverter arrangement. 8. Drilling Fluid Program Requirements of 20 AAC 25.005(c)(8) An app /ication for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (8) a drilling fluid program, including a diagram and description of the drilling fluid system, as required by 20 AAC 25.033; Drilling Fluid Program Surface Interval Fluid Properties Funnel API Fluid Drill Mud Wt. Yield Point Interval (lb/gal) ; Viscosity (Ib /1O0ft Loss pH Solids MBT (cp) (m1/30min) ( %) 0 — 150' lVD above Cook 8.8 — 10 50 - 90 30 - 40 NC — <10 +/- 9.5 < 7% <35 Inlet 0 R I • ! N A Tyonek 2008 PERMIT IT.doc Pa ge 7 of 19 Printed: 9- Jun -08 Application for Perr" Drill, Wells NCIU A -14, A -15, A -16 Revision No.O Saved: 9- Jun -08 Production Interval Fluid Properties API Fluid Mud Wt. Yield Point Solids Interval 6 RPM Loss (PP0) (Ib/100ft2) (m1/30min) pH ( %) Surface Casing 9.2 — 9.6 10 18 - 25 <6 9.0 — 9.5 <5 to TD Surface Hole: A standard high viscosity fresh water / gel spud mud is recommended for the surface interval. Keep flow line viscosity at ± 200 sec /qt while drilling and running casing. Reduce viscosity prior to cementing. Maintain mud weight < 9.6 ppg by use of solids control system and dilution where necessary. Intermediate Hole Section: The Production Interval mud system will be an inhibitive water based mud system. The primary inhibitors are NaCI &_KCI, which will be maintained at 10% and 2% by wt respectively, and a proprietary shale inhibitor designed to enhance the inhibition of of the salts as well as provide inhibition on it's own. Other components of the system are Well Bore Strengthening materials designed to prevent lost circulation in low pressure depleted zones of the upper hole section while drilling to TD for long string casing. The system also includes additives for aiding in the stabilization of coal seams and minimizing fluid invasion to prevent reservoir damage. If well control becomes an issue, enough barite to increase the mud weight by one pound per gallon will be on location at all times. Drilling fluid practices will be in accordance with appropriate regulations stated in 20 AAC 25.033. Please see Attachment 4 for diagrams and descriptions of the fluid system of Kuukpik 5. 9. Abnormally Pressured Formation Information Requirements of 20 AAC 25.005 (c)(9) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (9) for an exploratory or stratigraphic test well, a tabulation setting out the depths of predicted abnormally geo-pressured strata as required by 20 AAC 25.033(0; Not applicable: Application is not for an exploratory or stratigraphic test well. 10. Seismic Analysis Requirements of 20 AAC 25.005 (c)(10) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (10) for an exploratory or stratigraphic test well, a seismic refraction or reflection analysis as required by 20 AAC 25.061(a); Not applicable: Application is not for an exploratory or stratigraphic test well. 11.Seabed Condition Analysis Requirements of 20 AAC 25.005 (c)(11) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (11) for a well drilled from an offshore platform, mobile bottom - founded structure, jack -up rig, or floating drilling vessel, an analysis of seabed conditions as required by 20 AAC 2.5.061(6); Not applicable: The wells are being drilled from the Tyonek platform. The 30" conductors are preinstalled and there are no plans for conducting work on the sea bed. 12. Evidence of Bonding Requirements of 20 AAC 25.005 (c)(12) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: Tyonek 2008 PERMIT IT.doc OR Page 8 of 19 Printed: 9- Jun -08 • Application for Per Drill, Wells NCIU A -14, A -15, A -16 Revision No.O Saved: 9- Jun -08 (12) evidence showing that the requirements of 20 AAC 25.025 {Banding }have been met; Evidence of bonding for ConocoPhillips Alaska, Inca is on file with the Commission. 13. Proposed Drilling Program Requirements of 20 AAC 25.005 (c)(13) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: The proposed drilling program is listed below. Please refer also to Attachment 5, Well Schematics. General Procedure: 1. Mobilise Kuukpik Rig 5 over well room #2. 2. Skid to the relevant well(s) and with wireline, set downhole plugs in existing wells that fail to pass Major Risk for anti - collision. 3. Skid rig substructure over well to be drilled. 4. Install diverter on existing 30" conductor & function test same. Notify regulatory agencies 48 hours prior to test. 5. Spud well and drill 12 1/4" hole to the surface casing point at N 150ft TVD above the Cook Inlet sands. Run MWD / LWD logging tools (GR /RES) in drill string as required for directional monitoring and formation data gathering. 6. Condition hole for casing, trip out. 7. Run 9 5/8" 40# L80 BTCM casing string to TD and land same. 8. RU false rotary and PU & RIH with cement stinger. Cement surface casing through cement stinger. • Employ lightweight cement slurry to ensure cement returns to surface. Returns will be monitored during the cement job to make sure the casing is cemented to surface. 9. POOH with cement stinger & ND diverter. 10. Skid to the relevant well(s) and recover downhole plugs with wireline. 11. Repeat steps 2 to 10 for all three surface hole sections. 12. After cementing the third surface casing ND the diverter. 13. Skid to the next well and nipple up BOP's. Test BOP's. Notify all regulatory agencies 48 hours prior to test 14. Make up 8 3 /4" bit and BHA and RIH to top of float equipment. • Pressure test casing to 3000 psi for 30 minutes • Record results and fax to town 15. Drill float equipment and approximately 20' of new hole • Perform LOT (or FIT if gradient reaches 16 ppg equivalent) • Record results and fax to town 16. Drill 8 3 /4" hole to TD. Run MWD / LWD (GR / RES / DENS / POROSITY) logging tools in drill string as required for directional monitoring and formation data gathering. POOH with drilling assembly. • Condition hole and mud for logging operations. 17. Log 8 3 /4" open hole with electric line tools (SP /SBL, DSI, FMI, RSWC, MDT). Tyonek 2008 PERMIT IT.doc O RIGINAL. Page 9of19 Printed: 9- Jun -08 Application for Perral Drill, Wells NCIU A -14, A -15, A -16 Revision No.O Saved: 9- Jun -08 18. Run and cement 7 " casing per program to TD. Cement casing to bring cement +/- 500' above Cook Inlet sand. • If there are signs of lost circulation prior to running casing, a Halliburton HES stage cementing tool may be used. 19. RIH with a 4 1 /2" kill string and land the tubing hanger in the wellhead. Test the casing to 3000 psi. Set BPV in the tubing hanger. ND the BOPs and NU a dry tree. 20. Repeat steps 13 to 19 for all three production hole sections. 21. Skid to the next well. 22. ND the dry tree, NU the BOPs & test. Retrieve the BPV. Pull the kill string. 23. Run in hole with casing cleanup assembly on drillpipe. 24. Clean casing and pickle drillpipe. 25. Displace well to clean filtered brine. 26. Test casing to 5000 psi. 27. Rig up eline and run cement bond log GR / CCL. 28. Pick up and run in hole with tubing frac string (4 -1/2" tubing). 29. Set tubing in slips, close pipe rams, and rig up electric line 30. Perforate with wireline tools 31. Fracture Stimulate 1 zone 32. Sand Back 33. Repeat perforating and fracturing 2 -3 times as needed 34. Clean out proppant 35. POOH with tubing frac string 36. Pick up tubing conveyed perforating guns on drillpipe. 37. Perforate with large hole perforations- 4 -5/8" guns 38. Run Conventional gravel pack equipment with 2 -7/8" inner string to gravel pack lower interval. 39. Pump high rate water pack (HRWP). 40. Run inner string to isolate pack. 41. Continue with conventional / multizone gravel packing operations as planned for the relevant well. 42. Run Upper completion per completion schematics. (Latch into anchor, shear PBR, space out, etc.) 43. Land tubing and test tubing hanger. 44. Test inner annulus to 2500 psi for 30 minutes. (Note: This will test our tubing integrity.) 45. Pressure up on IA to shear SOV at 3000 psi. 46. Set BPV and ND BOP. 47. Nipple up tree and test same. 48. Repeat steps 21 to 47 for all three wells. 49. RDMO. !! Tyonek 2008 PERMIT IT.doc a a Page J8 n Printed: 9-Jun-08 Application for Pei Ilk Drill, Wells NCIU A -14, A -15, A -16 Revision No.O Saved: 9- Jun -08 14. Discussion of Mud and Cuttings Disposal and Annular Disposal Requirements of 20 AAC 25.005 (c)(14) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (14) a general description of how the operator plans to dispose of drilling mud and cuttings and a statement of whether the operator intends to request authorization under 20 AAC 25.080 for an annular disposal operation in the well.; Waste fluids generated during the drilling process will be disposed of by discharge to the Inlet. The mud has been formulated and tested to meet the requirements of EPA NPDES permit number AKG -31 -5000. ConocoPhillips Alaska may in the future request authorization for the use of this well for annular disposal operations. 15.Attachments • Attachment 1 Directional Plans • Attachment 2 BOPE and Diverter • Attachment 3 Drilling Hazards Summary • Attachment 4 Fluid System • Attachment 5 Well Schematics ORIGIN Tyonek 2008 PERMIT IT.doc Page 11 of 19 . #r Printed: 9- Jun -08 • Application for Pe•Drill, Wells NCIU A -14, A -15, A -16 Revision No.O Saved: 9- Jun -08 Attachment 1. Directional Plans ORIGINAL fg g 6' ASP ZONE 4, NAD83, FEET NAD83 GEOGRAPHIC MLLW DESCRIPTION € 8 (POINT NO.) NORTHING ; EASTING LATITUDE LONGITUDE ELEVATION NCIU WELL TAG NO. 36 31 T 12 N 31 32 */. 1 s WELL HOUSE NO. 1 y (n S 1001 2586492 1472018 61 04 34.38 150 57 03.71 72.0 CONDUCTOR 1 1 6 N 5 X 4 0 1002 2586489 1472017 61 04 34.34 150 57 03.72 73.8 83 N 4 • " . - 1003 2586485 1472019 61 04 34.31 150 57 03.67 74.1 Al2 M � e 1004 2586485 1472023 61 04 34.31 150 57 03.59 73.8 B1 1005 2586487 1472027 61 04 34.33 150 57 03.52 72.0 CONDUCTOR 5' m • ,k I g 1008 2586491 1472027 61 04 34.37 150 57 03.52 73.7 82 \\ 1007 2586495 1472025 61 04 34.41 150 57 03.57 72.1 CONDUCTOR 7 1206' �1008 2586495 1472021 61 04 34.41 150 57 03.65 73.7 A13 HOl15E 2O. Z 200 2001 1 2586437 1472060 81 04 33.84 150 57 02.83 71.9 CONDUCTOR 1 2002 I 2588433 1472059 61 04 03.38 150 57 02.84 71.9 CONDUCTOR 2 ESD 600 -50 2003 i 2586430 1472062 61 04 33.77 150 57 02.79, 71.8 CONDUCTOR 3 2004 2586429 1472066 61 04 33.77 150 57 02.71 1 73.4 AN 6 2005 2586431 1472069 61 04 33.79 150 57 02.65 71.9 CONDUCTOR 5 2006 25864.35 1472089 61 04 34.83 150 57 02.64 73.3 A10 ESD 600 -51 2007 2586439 1472067 61 04 33.86 150 57 0289 73.3 All 2008 2586439 I 1472063 81 04 33.87 150 57 0277 71.9 CONDUCTOR 8 I WELL HOUSE NO. 3 _. ._ ____ ......_ .._.m....., Lq I A13 A7 , W 3001 2586488 +472128 .. "_�." 61 04 34.36 150 57 01.47 73.0 Al 01 7 Al 3002 2588484 € 1472127 61 04 34.32 150 57 01.48 73.1 AS _ + 02 3803 2586481 1472130 181 04 34.29 150 57 01.43 73.1 48 I B3 5 AB A4AT 3004 2586480 ( 1472133 1 61 04 34.28 150 57 01.35 73.0 A4 I 412 81 3005 2588483 1472137 61 04 34.31 150 57 01.29 73.0 A2 I 3006 2586487 1472137 1 61 04 34.34 150 57 01.28 73.0 AS 3007 2588490 1472135 61 04 34.38 150 57 01.33 1 73.0 A3 i 3008 2586490 1472131 61 04 34.38 150 57 01.41 , 73.3 A7 1 6 6 J 50 2586540 1472069 61 04 34.86 150 57 02.69 72.7 ESD VALVE 900 -50 12 . 7 8 51 2586501 ! 1472011 _ 61 04 34.48 150 57 03.86 72.6 ESD VALVE 600-51 WELL HOUSE 2 100 2586572 1472123 81 04 35.18 150 57 01.58 115.3 TOP CENTER HELIPAD SCALE: 1"=1320'= MILE 8 All -101' MUD LINE + A10 2 GENERAL NOTES: 3 �5 SURVEY NOTES: 1. SECTION LINES AND TIES ARE BASED 1. GEOGRAPHIICS ARE NAD83. ZONE 4, NAD83, US SURVEY FEET. ON PROTRACTED VALUES. 2. ELEVATIONS ARE IN FEET, BASED ON MLLW, REFERENCED TO DRAWING NO. MPD -TY04 -2021, SHEET 1 OF 1, REV 2. SCALE: 1 " =30' LEGEND: 3. ALL AS BUILTS ARE TO THE CENTER OF EXISTING STRUCTURE. 4. WELL CONDUCTOR ARE VERTICALLY AS BUILT TO THE TOP OF WELL A 1 /4" STEEL LID. TACK WELDED TO THE TOP OF THE CONDUCTOR. IP' IP 5. WELLS ARE VERTICALLY AS BUILT TO THE TOP OF THE WELL CONDUCTOR LOWEST HORIZONTAL FLANGE ON THE WELL. • ESD (EMERGENCY SHUT GENERAL NOTES: OFF VALVE) 1. NO WELLS EXIST IN WELL HOUSE NO 4 AND IT WAS NOT AS BUILT FORM: BSIZE DRAWN: DESIGN: ECM NO: ` TYONEK TYONEK MODULE: UNIT: TY CHECKED: APPROVAL CC NO:' - ConocoPhillips - - Alaska, Inc. 3 -11 -08 ISSUED PER DC0001APD MGO FNS SCALE: DATE: CADD FILENAME: JOB NO SUB JOB NO: DRAWING NO:. PART: REV: DATE REVISION BY CHK JOB PROJ as noted 3 - - NGED-304-M-310 001 OF -- 1 ConocoPhillips (Alaska) Inc. -Expl :: North Cook Inlet Unit North Cook Inlet Unit Plan: NCI A -14 - 2008 PIan:NCI A -14 Plan: A-14wp15 Sperry Drilling Services Combo Report 09 June, 2008 Well Coordinates: 2,586,439.27 N, 1,472,063.07 E (61° 04' 33.87" N, 150° 57 02.77" W) Water Depth: 101.00 ft • Local Coordinate Origin: Centered on Well Plan: NCI A -14 - Slot 2008 Viewing Datum: Plan: NCI A -14 @ 116.00ft (Kuupik 5) • TVDs to System: N •[ North Reference: True Unit System: API - US Survey Feet New Geodetic Scale Factor Applied Version: 2003.16 Build: 42F M HALLIBURTON ... Sperry Drilling Servicaers Project: North Cook Inlet Unit REFERENCE INFORMATION SECTION DETAILS Site: North Cook Inlet Unit Co-ordinate (NIP) Reference: Well Plan: NCI A -14 - Slot 2008, True North Well: Plan: NCI A -14 Vertical (TVD) Reference: Plan: NCI A -14 S 116.00ft (Kuupik 5) Sec MD Inc Azi ND +N/ - +E/ - DLeg TFace VSec Target Measured Depth Reference: Plan: NCI A -14 5 116.006 (Kuupik 5) 1 217.00 0.00 0.00 217.00 0.00 0.00 0.00 0.00 0.00 Wellbore: Plan: NCI A -14 Calculation Method: Minimum Curvature 2 450.00 0.00 0.00 450.00 0.00 0.00 0.00 0.00 0.00 Plan: A- 14wp15 3 550.00 2.00 330.00 549.98 1.51 -0.87 2.00 330.00 1.11 4 700.00 2.00 150.00 699.95 1.51 -0.87 2.67 180.00 1.11 5 900.00 3.00 110.00 899.77 •3.30 5.79 0.98 -81.19 -1.06 WELL DETAILS: Plan: NCI A - 14 1 6 2236.45 40.00 20.00 2129.57 405.17 193.27 3.00 -93.57 447.20 7 2937.78 58.75 32.76 2585.22 874.37 435.33 3.00 31.74 971.48 Water Depth: 101.00 - 8 7272.83 58.75 32.76 4833.85 3991.06 2440.95 0.00 0.00 4593.36 +N / - +E / - Northing Pasting Latittude Longitude Slot'' 9 8525.17 51.16 3.45 5563.00 4943.31 2765.17 2.00 - 115.74 5598.84 A- 14wp09 Beluga I Drilling Target 10.00 0.00 2586439.27 1472063.07 61° 4' 33.866 N 150° 57 2.770 W 20081 10 11192.84 51.16 3.45 7236.00 7017.41 2890.14 0.00 0.00 7585.22 A- 14wp09 Beluga U Drilling Target -700- 11 12277.12 51.16 3.45 7916.00 7860.44 2940.94 0.00 0.00 8392.59 FORMATION TOP DETAILS CASING DETAILS 0- NDPath MDPath Formation ND MD Name Size 3599.00 4892.21 Top Sterling - - - SHL: 1302.01 FNL, 1019.29 FWL - SEC 6 - T11 N - RO9W 3449.00 4603.03 9 5/8" 9-5/8 3734.00 5152.47 CI -A - C) 7916.00 12277.12 7" 7 3957.00 5582.38 CI 700- 4232.00 6112.54 CI -5 - T 4610.00 6841.28 Baluga -A 70 6265.00 9644.54 Beluga -O 111111.11•I, 7566.00 11719.03 Base Beluga 1400- - 1400 ONINI"lle 9 -5/8" @ 4510.44 FNL, 2224.83 FWL - SEC 31 - T12N - RO9W 2100- �' `'� -2100 2 - + -1 • 2800- -2800 N 0 - v co , g 5/8" 5 t 3500- Top Sterling ' p A - 14wp09 Beluga I Drilling Target 1 ) iZ J - -3500 - a) 0 c OOO 4200 - CI -1 _ , - 4200 y a) _ - CI -5 - A - o 0 - = - I 4900- Baluga -A A- 14wp09 Beluga U Drilling Target ■ -4900 5600 - -5600 BHL Co3 12277.12' MD, 7916' TVD; 4001.77' FNL, 3959.44' FWL - SEC - 30 - T12 - RI 6300 -" -. - -0300 - Beluga -Q - 7000- -7000 7700- Base Beluga -7700 _ V' - 8400 - I l I I I I I I I I I i I I I i I I I l I I I I I I I I i I I I I I I l I l I t I i l I I I I l I t l I I I I I I I i l I i I I I l I I I I I I I I I I I I I I I i I i i I I l I I I I i I I I I - 8400 -1400 -700 0 700 1400 2100 2800 3500 4200 4900 5600 6300 7000 7700 8400 9100 9800 1050 Vertical Section at 20.51° (1400 ft/in) COnOCOPhi!l ps • Project: North Cook Inlet Unit REFERENCE INFORMATION WELL DETAILS: Plan: NCI A -I4 Site: North Cook Inlet Unit Co- ordinate (N /E) Reference: Well Plan: NCI A -14 - Slot 2008, True North Well: Plan: NCI A -14 Vertical (TVD) Reference: Plan: NCI A -14 t$ Water De 116.00ft (Kuupik 5) Depth: 101.00 Measured Depth Reference: Plan: NCI A -14 0 116.008 (Kuupik 5) +N / - +E/ - Northing Easting Latiittude Longitude Slot Wellbore: Plan: NCI A -14 Calculation Method: Minimum Curvature 0.00 0.00 2586439.27 1472063.07 61' 4' 33.866 N 150° 57' 2.770 W 2008 Plan: A- 14wp15 CASING DETAILS TVD MD Name Size 3449.00 4603.03 9 5/8" 9-5/8 7916.00 12277.12 7" 7 7857-7_ ' 11573 - - - - - - - 7857 7750 BI-II. @ 12277,12' MD, 7916' TVD; 4001.77' FNL, 3959.44' FWL - SEC 30 - T12 - RO9W _ 7500— —7500 c00 7143 — ._j89% coat —7143 6786 -, .... 1A_l 4u5009 Beluga U Drilling Target _ 7000 6786 6429 — —6429 6750 6071 _ 6500 —6071 5714 6250 —5714 5357 — 6000 — 5357 O /// •95tbconf. - 5000— / ,w _ . . ........... A- 14wp09 Beluga I Drilling Target —5000 ' ti, 75.S00 » _ CA - j 4643- -4643 a o _ (7) s 2so - i 4286 — V J —4286 2 3929 _ s -3929 G - y _ 3571 — i -3571 tv La 503214_ —32I4 rn - a� so - 2857— -2857. 2500— —2500 3JSG 9.5/8" @ 4510.44 FNL, 2224.83 FWL - SEC 31 - T12N - RO9W _ 2143 — - _ )'�00 _ 2143 1786 _ 3ZS 2 -1786 1429 — , -1429 1071— 2� T M Azimuths to True North -1071 = s'O Magnetic North: 19.24° - 714— -3s SHL: 1302. OI FNL, 1019.29FWL- SEC 6- TIIN -RO9W Magnetic Field —714 _ - _ _ _ - - D Strength: 55653.8snT - - Z.2 - - - - - 357 — - Da e: 1/16/2008 -357 Model: BGGM2007 e 11111111IIIIi111 Ii IIII[ IIIi -. r 1l1111i1111 Bile I111l II Ii 1Ii II!iiii Ii II111t H 1 I IIIlill 11Illlll111i1111I11 I I II II 1 Iiiii II I Ii IIII 1 I I II IiiiIii 11111111 till lifIlliiripIITI( - -1786 -1429 -107I -714 -357 -i 357 714 1071 1429 1786 2143 2500 2857 3214 3571 3929 4286 4643 5000 5357 5714 6071 6429 6786 7143 7500 7857 8214 8571 8929 9286 9643 10000 West( - )/East( +) (1250 ft/in) '- ConocoPhillips ConocoPhillips (Alaska) Inc. -Expl HALLIBURTON North Cook Inlet Unit Plan Report for Plan: NCI A -14 - A- 14wp15 Measured TVD below Vertical Local Coordinates Map Coordinates Dogleg Build Turn Vertical Horizontal Depth Inclination Azimuth System Depth Northing Easting Northing Easting Rate Rate Rate Section Departure (ft) ( °) ( °) (ft) (ft) (ft) (ft) (ft) (ft) ( ° /100ft) ( ° /100ft) ( °I100ft) (ft) (0.00) 217.00 0.00 0.00 101.00 217.00 0.00 N 0.00 W 2,586,439.27 1,472,063.07 0.00 0.00 0.00 0.00 0.00 SHL: 1302.01 FNL, 1019.29 FWL - SEC 6 - T11 N - R09W 300.00 0.00 0.00 184.00 300.00 0.00 N 0.00 W 2,586,439.27 1,472,063.07 0.00 0.00 0.00 0.00 0.00 400.00 0.00 0.00 284.00 400.00 0.00 N 0.00 W 2,586,439.27 1,472,063.07 0.00 0.00 0.00 0.00 0.00 450.00 0.00 0.00 334.00 450.00 0.00 N 0.00 W 2,586,439.27 1,472,063.07 0.00 0.00 0.00 0.00 0.00 500.00 1.00 330.00 384.00 500.00 0.38 N 0.22 W 2,586,439.65 1,472,062.86 2.00 2.00 0.00 0.28 0.44 550.00 2.00 330.00 433.98 549.98 1.51 N 0.87 W 2,586,440.79 1,472,062.22 2.00 2.00 0.00 1.11 1.75 600.00 0.67 330.00 483.97 599.97 2.52 N 1.45 W 2,586,441.81 1,472,061.65 2.67 -2.67 0.00 1.85 2.91 CD 700.00 2.00 150.00 583.95 699.95 1.51 N 0.87 W 2,586,440.79 1,472,062.22 2.67 1.33 180.00 1.11 5.24 800.00 2.36 125.84 683.88 799.88 1.20 S 1.67 E 2,586,438.04 1,472,064.72 0.98 0.36 -24.16 -0.54 9.04 900.00 3.00 110.00 783.77 899.77 3.30 S 5.79 E 2,586,435.89 1,472,068.81 0.98 0.64 -15.84 -1.06 13.71 �.�.� 1,000.00 4.11 63.18 883.60 999.60 2.58 S 11.45 E 2,586,436.52 1,472,074.48 3.00 1.11 -46.82 1.59 19.91 ( J ) 1,100.00 6.54 43.59 983.17 1,099.17 3.16 N 18.57 E 2,586,442.16 1,472,081.68 3.00 2.43 -19.59 9.47 29.18 1,200.00 9.30 35.05 1,082.21 1,198.21 13.90 N 27.14 E 2,586,452.78 1,472,090.40 3.00 2.77 -8.54 22.53 42.96 1,300.00 12.18 30.45 1,180.44 1,296.44 29.62 N 37.13 E 2,586,468.35 1,472,100.62 3.00 2.88 -4.60 40.75 61.60 >1. 1,400.00 15.11 27.60 1,277.61 1,393.61 50.27 N 48.51 E 2,586,488.82 1,472,112.31 3.00 2.92 -2.85 64.08 85.18 1,500.00 18.05 25.66 1,373.45 1,489.45 75.79 N 61.26 E 2,586,514.16 1,472,125.42 3.00 2.95 -1.94 92.45 113.72 1,600.00 21.02 24.25 1,467.68 1,583.68 106.12 N 75.34 E 2,586,544.27 1,472,139.94 3.00 2.96 -1.41 125.79 147.15 1,700.00 23.99 23.18 1,560.05 1,676.05 141.16 N 90.71 E 2,586,579.09 1,472,155.82 3.00 2.97 -1.07 164.00 185.42 1,800.00 26.97 22.33 1,650.32 1,766.32 180.83 N 107.33 E 2,586,618.51 1,472,173.01 3.00 2.98 -0.85 206.98 228.43 1,900.00 29.95 21.63 1,738.23 1,854.23 225.02 N 125.15 E 2,586,662.43 1,472,191.47 3.00 2.98 -0.69 254.61 276.08 • 2,000.00 32.93 21.06 1,823.53 1,939.53 273.60 N 144.13 E 2,586,710.73 1,472,211.14 3.00 2.98 -0.58 306.76 328.24 2,100.00 35.92 20.57 1,906.01 2,022.01 326.45 N 164.20 E 2,586,763.28 1,472,231.98 3.00 2.99 -0.49 363.29 384.77 2,200.00 38.91 20.14 1,985.42 2,101.42 383.41 N 185.33 E 2,586,819.92 1,472,253.93 3.00 2.99 -0.43 424.04 445.52 2,236.45 40.00 20.00 2,013.57 2,129.57 405.17 N 193.27 E 2,586,841.56 1,472,262.20 3.00 2.99 -0.39 447.20 468.68 2,300.00 41.63 21.51 2,061.66 2,177.66 444.00 N 208.00 E 2,586,880.17 1,472,277.48 3.00 2.57 2.38 488.74 510.22 2,400.00 44.24 23.70 2,134.87 2,250.87 506.86 N 234.21 E 2,586,942.64 1,472,304.60 3.00 2.60 2.19 556.79 578.33 2,500.00 46.88 25.69 2,204.89 2,320.89 571.70 N 264.05 E 2,587,007.04 1,472,335.38 3.00 2.64 1.99 627.98 649.72 2,600.00 49.55 27.52 2,271.52 2,387.52 638.35 N 297.46 E 2,587,073.19 1,472,369.75 3.00 2.67 1.83 702.11 724.27 2,700.00 52.25 29.20 2,334.59 2,450.59 706.62 N 334.33 E 2,587,140.91 1,472,407.61 3.00 2.70 1.69 778.97 801.87 2,800.00 54.97 30.77 2,393.91 2,509.91 776.33 N 374.57 E 2,587,210.02 1,472,448.85 3.00 2.72 1.57 858.36 882.37 09 June, 2008 - 15:37 Page 2 of 9 COMPASS ConocoPhillips (Alaska) Inc. -Expl HALLIBURTON North Cook Inlet Unit Plan Report for Plan: NCI A -14 - A- 14wp15 Measured TVD below Vertical Local Coordinates Map Coordinates Dogleg Build Turn Vertical Horizontal Depth Inclination Azimuth System Depth Northing Easting Northing Easting Rate Rate Rate Section Departure (ft) (°) ( °) (ft) (ft) (ft) (ft) (ft) (ft) ( ° /100ft) (°/100ft) ( ° /100ft) (ft) (57.71) 2,900.00 57.71 32.23 2,449.33 2,565.33 847.28 N 418.07 E 2,587,280.33 1,472,493.37 3.00 2.74 1.46 940.06 965.60 2,937.78 58.75 32.76 2,469.22 2,585.22 874.37 N 435.33 E 2,587,307.17 1,472,511.02 3.00 2.75 1.40 971.48 997.71 3,000.00 58.75 32.76 2,501.49 2,617.49 919.11 N 464.12 E 2,587,351.48 1,472,540.45 0.00 0.00 0.00 1,023.46 1,050.91 3,100.00 58.75 32.76 2,553.36 2,669.36 991.00 N 510.38 E 2,587,422.69 1,472,587.76 0.00 0.00 0.00 1,107.01 1,136.41 3,200.00 58.75 32.76 2,605.23 2,721.23 1,062.90 N 556.65 E 2,587,493.90 1,472,635.06 0.00 0.00 0.00 1,190.56 1,221.90 • 3,300.00 58.75 32.76 2,657.10 2,773.10 1,134.79 N 602.91 E 2,587,565.11 1,472,682.36 0.00 0.00 0.00 1,274.11 1,307.40 3,400.00 58.75 32.76 2,708.98 2,824.98 1,206.69 N 649.18 E 2,587,636.32 1,472,729.66 0.00 0.00 0.00 1,357.66 1,392.89 3,500.00 58.75 32.76 2,760.85 2,876.85 1,278.58 N 695.44 E 2,587,707.53 1,472,776.96 0.00 0.00 0.00 1,441.21 1,478.39 3,600.00 58.75 32.76 2,812.72 2,928.72 1,350.48 N 741.71 E 2,587,778.74 1,472,824.26 0.00 0.00 0.00 1,524.76 1,563.88 CD 3,700.00 58.75 32.76 2,864.59 2,980.59 1,422.37 N 787.97 E 2,587,849.95 1,472,871.56 0.00 0.00 0.00 1,608.30 1,649.38 -D 3,800.00 58.75 32.76 2,916.46 3,032.46 1,494.27 N 834.24 E 2,587,921.16 1,472,918.86 0.00 0.00 0.00 1,691.85 1,734.87 3,900.00 58.75 32.76 2,968.33 3,084.33 1,566.16 N 880.50 E 2,587,992.37 1,472,966.17 0.00 0.00 0.00 1,775.40 1,820.37 -• .e 4,000.00 58.75 32.76 3,020.20 3,136.20 1,638.06 N 926.77 E 2,588,063.58 1,473,013.47 0.00 0.00 0.00 1,858.95 1,905.86 '�.: J 4,100.00 58.75 32.76 3,072.07 3,188.07 1,709.95 N 973.03 E 2,588,134.79 1,473,060.77 0.00 0.00 0.00 1,942.50 1,991.36 «+ 4,200.00 58.75 32.76 3,123.94 3,239.94 1,781.85 N 1,019.30 E 2,588,206.01 1,473,108.07 0.00 0.00 0.00 2,026.05 2,076.85 4,300.00 58.75 32.76 3,175.81 3,291.81 1,853.74 N 1,065.56 E 2,588,277.22 1,473,155.37 0.00 0.00 0.00 2,109.60 2,162.35 >16 4,400.00 58.75 32.76 3,227.69 3,343.69 1,925.64 N 1,111.83 E 2,588,348.43 1,473,202.67 0.00 0.00 0.00 2,193.15 2,247.84 p+..� 4,500.00 58.75 32.76 3,279.56 3,395.56 1,997.53 N 1,158.09E 2,588,419.64 1,473,249.97 0.00 0.00 0.00 2,276.69 2,333.34 d 4,600.00 58.75 32.76 3,331.43 3,447.43 2,069.43 N 1,204.36E 2,588,490.85 1,473,297.28 0.00 0.00 0.00 2,360.24 2,418.83 4,603.03 58.75 32.76 3,333.00 3,449.00 2,071.61 N 1,205.76E 2,588,493.01 1,473,298.71 0.00 0.00 0.00 2,362.78 2,421.42 9 -5/8" @ 4510.44 FNL, 2224.83 FWL - SEC 31 - T12N - R09W - 9 5/8" • 4,700.00 58.75 32.76 3,383.30 3,499.30 2,141.32 N 1,250.62 E 2,588,562.06 1,473,344.58 0.00 0.00 0.00 2,443.79 2,504.33 4,800.00 58.75 32.76 3,435.17 3,551.17 2,213.22 N 1,296.89 E 2,588,633.27 1,473,391.88 0.00 0.00 0.00 2,527.34 2,589.82 4,892.21 58.75 32.76 3,483.00 3,599.00 2,279.51 N 1,339.55 E 2,588,698.93 1,473,435.50 0.00 0.00 0.00 2,604.38 2,668.66 Top Sterling 4,900.00 58.75 32.76 3,487.04 3,603.04 2,285.11 N 1,343.16E 2,588,704.48 1,473,439.18 0.00 0.00 0.00 2,610.89 2,675.32 5,000.00 58.75 32.76 3,538.91 3,654.91 2,357.01 N 1,389.42E 2,588,775.69 1,473,486.48 0.00 0.00 0.00 2,694.44 2,760.81 5,100.00 58.75 32.76 3,590.78 3,706.78 2,428.90 N 1,435.69E 2,588,846.90 1,473,533.78 0.00 0.00 0.00 2,777.99 2,846.31 5,152.47 58.75 32.76 3,618.00 3,734.00 2,466.63 N 1,459.96 E 2,588,884.27 1,473,558.60 0.00 0.00 0.00 2,821.83 2,891.17 CI -A 5,200.00 58.75 32.76 3,642.65 3,758.65 2,500.80 N 1,481.95E 2,588,918.11 1,473,581.08 0.00 0.00 0.00 2,861.54 2,931.80 5,300.00 58.75 32.76 3,694.52 3,810.52 2,572.70 N 1,528.22 E 2,588,989.32 1,473,628.39 0.00 0.00 0.00 2,945.09 3,017.30 09 June, 2008 - 15:37 Page 3 of 9 COMPASS ConocoPhillips (Alaska) Inc. -Expl HALLMURTON North Cook Inlet Unit Plan Report for Plan: NCI A -14 - A- 14wp15 Measured TVD below Vertical Local Coordinates Map Coordinates Dogleg Build Turn Vertical Horizontal Depth Inclination Azimuth System Depth Northing Easting Northing Easting Rate Rate Rate Section Departure (ft) (°) ( °) (ft) (ft) (ft) (ft) (ft) (ft) ( °/100ft) ( °/100ft) ( ° /100ft) (ft) (58.75) 5,400.00 58.75 32.76 3,746.40 3,862.40 2,644.59 N 1,574.48 E 2,589,060.54 1,473,675.69 0.00 0.00 0.00 3,028.63 3,102.79 5,500.00 58.75 32.76 3,798.27 3,914.27 2,716.49 N 1,620.75 E 2,589,131.75 1,473,722.99 0.00 0.00 0.00 3,112.18 3,188.29 5,582.38 58.75 32.76 3,841.00 3,957.00 2,775.72 N 1,658.86 E 2,589,190.41 1,473,761.96 0.00 0.00 0.00 3,181.01 3,258.72 CI -1 5,600.00 58.75 32.76 3,850.14 3,966.14 2,788.38 N 1,667.01 E 2,589,202.96 1,473,770.29 0.00 0.00 0.00 3,195.73 3,273.78 5,700.00 58.75 32.76 3,902.01 4,018.01 2,860.28 N 1,713.28 E 2,589,274.17 1,473,817.59 0.00 0.00 0.00 3,279.28 3,359.28 • 5,800.00 58.75 32.76 3,953.88 4,069.88 2,932.17 N 1,759.54 E 2,589,345.38 1,473,864.89 0.00 0.00 0.00 3,362.83 3,444.77 5,900.00 58.75 32.76 4,005.75 4,121.75 3,004.07 N 1,805.81 E 2,589,416.59 1,473,912.19 0.00 0.00 0.00 3,446.38 3,530.27 6,000.00 58.75 32.76 4,057.62 4,173.62 3,075.96 N 1,852.07 E 2,589,487.80 1,473,959.50 0.00 0.00 0.00 3,529.93 3,615.76 6,100.00 58.75 32.76 4,109.49 4,225.49 3,147.86 N 1,898.34 E 2,589,559.01 1,474,006.80 0.00 0.00 0.00 3,613.48 3,701.26 6,112.54 58.75 32.76 4,116.00 4,232.00 3,156.88 N 1,904.14 E 2,589,567.94 1,474,012.73 0.00 0.00 0.00 3,623.96 3,711.98 CI -5 ,--- 6,200.00 58.75 32.76 4,161.36 4,277.36 3,219.75 N 1,944.60 E 2,589,630.22 1,474,054.10 0.00 0.00 0.00 3,697.02 3,786.75 C ) 6,300.00 58.75 32.76 4,213.23 4,329.23 3,291.65 N 1,990.87 E 2,589,701.43 1,474,101.40 0.00 0.00 0.00 3,780.57 3,872.25 6,400.00 58.75 32.76 4,265.11 4,381.11 3,363.54 N 2,037.13 E 2,589,772.64 1,474,148.70 0.00 0.00 0.00 3,864.12 3,957.74 6,500.00 58.75 32.76 4,316.98 4,432.98 3,435.44 N 2,083.40 E 2,589,843.85 1,474,196.00 0.00 0.00 0.00 3,947.67 4,043.24 6,600.00 58.75 32.76 4,368.85 4,484.85 3,507.33 N 2,129.66 E 2,589,915.07 1,474,243.30 0.00 0.00 0.00 4,031.22 4,128.73 t -'-® 6,700.00 58.75 32.76 4,420.72 4,536.72 3,579.23 N 2,175.93 E 2,589,986.28 1,474,290.61 0.00 0.00 0.00 4,114.77 4,214.23 6,800.00 58.75 32.76 4,472.59 4,588.59 3,651.12 N 2,222.20 E 2,590,057.49 1,474,337.91 0.00 0.00 0.00 4,198.32 4,299.72 6,841.28 58.75 32.76 4,494.00 4,610.00 3,680.80 N 2,241.29 E 2,590,086.88 1,474,357.43 0.00 0.00 0.00 4,232.80 4,335.01 Baluga -A 6,900.00 58.75 32.76 4,524.46 4,640.46 3,723.02 N 2,268.46 E 2,590,128.70 1,474,385.21 0.00 0.00 0.00 4,281.87 4,385.22 • 7,000.00 58.75 32.76 4,576.33 4,692.33 3,794.91 N 2,314.73 E 2,590,199.91 1,474,432.51 0.00 0.00 0.00 4,365.42 4,470.71 7,100.00 58.75 32.76 4,628.20 4,744.20 3,866.81 N 2,360.99E 2,590,271.12 1,474,479.81 0.00 0.00 0.00 4,448.96 4,556.21 7,200.00 58.75 32.76 4,680.07 4,796.07 3,938.70 N 2,407.26 E 2,590,342.33 1,474,527.11 0.00 0.00 0.00 4,532.51 4,641.70 7,272.83 58.75 32.76 4,717.85 4,833.85 3,991.06 N 2,440.95 E 2,590,394.19 1,474,561.56 0.00 0.00 0.00 4,593.36 4,703.97 7,300.00 58.52 32.19 4,731.99 4,847.99 4,010.64 N 2,453.41 E 2,590,413.58 1,474,574.30 2.00 -0.86 -2.11 4,616.06 4,727.17 7,400.00 57.68 30.05 4,784.84 4,900.84 4,083.31 N 2,497.29 E 2,590,485.60 1,474,619.23 2.00 -0.84 -2.14 4,699.49 4,812.06 7,500.00 56.87 27.87 4,838.91 4,954.91 4,156.90 N 2,538.03 E 2,590,558.59 1,474,661.03 2.00 -0.80 -2.18 4,782.70 4,896.19 7,600.00 56.11 25.66 4,894.12 5,010.12 4,231.33 N 2,575.58 E 2,590,632.47 1,474,699.65 2.00 -0.77 -2.22 4,865.57 4,979.57 7,700.00 55.38 23.40 4,950.41 5,066.41 4,306.52 N 2,609.90 E 2,590,707.14 1,474,735.06 2.00 -0.73 -2.25 4,948.01 5,062.22 09 June, 2008 - 15:37 Page 4 of 9 COMPASS ConocoPhillips (Alaska) Inc. -Expl HALLIBURTON North Cook Inlet Unit Plan Report for Plan: NCI A -14 - A- 14wp15 Measured TVD below Vertical Local Coordinates Map Coordinates Dogleg Build Turn Vertical Horizontal Depth Inclination Azimuth System Depth Northing Easting Northing Easting Rate Rate Rate Section Departure (ft) ( °) ( °) (ft) (ft) (ft) (ft) (ft) (ft) ( ° /100ft) ( ° /1001t) ( °/100ft) (ft) (54.70) 7,800.00 54.70 21.11 5,007.72 5,123.72 4,382.35 N 2,640.94 E 2,590,782.51 1,474,767.20 2.00 -0.68 -2.29 5,029.92 5,144.18 7,900.00 54.06 18.78 5,065.97 5,181.97 4,458.75 N 2,668.67 E 2,590,858.49 1,474,796.03 2.00 -0.64 -2.33 5,111.19 5,225.46 8,000.00 53.46 16.41 5,125.09 5,241.09 4,535.62 N 2,693.05 E 2,590,934.99 1,474,821.53 2.00 -0.59 -2.37 5,191.73 5,306.12 8,100.00 52.92 14.01 5,185.01 5,301.01 4,612.87 N 2,714.06 E 2,591,011.92 1,474,843.66 2.00 -0.55 -2.40 5,271.44 5,386.18 8,200.00 52.42 11.57 5,245.66 5,361.66 4,690.40 N 2,731.67 E 2,591,089.18 1,474,862.38 2.00 -0.50 -2.44 5,350.23 5,465.69 III 8,300.00 51.97 9.10 5,306.96 5,422.96 4,768.12 N 2,745.85 E 2,591,166.68 1,474,877.69 2.00 -0.45 -2.47 5,427.98 5,544.70 8,400.00 51.58 6.61 5,368.84 5,484.84 4,845.93 N 2,756.59 E 2,591,244.32 1,474,889.56 2.00 -0.39 -2.50 5,504.63 5,623.26 8,500.00 51.24 4.09 5,431.23 5,547.23 4,923.74 N 2,763.88 E 2,591,322.01 1,474,897.98 2.00 -0.34 -2.52 5,580.05 5,701.42 8,525.17 51.16 3.45 5,447.00 5,563.00 4,943.31 N 2,765.17 E 2,591,341.57 1,474,899.55 2.00 -0.31 -2.54 5,598.84 5,721.04 A- 14wp09 Beluga I Drilling Target CD 8,600.00 51.16 3.45 5,493.93 5,609.93 5,001.49 N 2,768.67 E 2,591,399.68 1,474,903.90 0.00 0.00 0.00 5,654.56 5,779.33 8,700.00 51.16 3.45 5,556.64 5,672.64 5,079.24 N 2,773.36 E 2,591,477.35 1,474,909.71 0.00 0.00 0.00 5,729.02 5,857.22 73 8,800.00 51.16 3.45 5,619.36 5,735.36 5,156.99 N 2,778.04 E 2,591,555.02 1,474,915.53 0.00 0.00 0.00 5,803.48 5,935.11 8,900.00 51.16 3.45 5,682.07 5,798.07 5,234.74 N 2,782.73 E 2,591,632.69 1,474,921.34 0.00 0.00 0.00 5,877.94 6,013.00 9,000.00 51.16 3.45 5,744.78 5,860.78 5,312.49 N 2,787.41 E 2,591,710.35 1,474,927.15 0.00 0.00 0.00 5,952.40 6,090.89 9,100.00 51.16 3.45 5,807.50 5,923.50 5,390.24 N 2,792.10 E 2,591,788.02 1,474,932.97 0.00 0.00 0.00 6,026.86 6,168.78 9,200.00 51.16 3.45 5,870.21 5,986.21 5,467.99 N 2,796.78 E 2,591,865.69 1,474,938.78 0.00 0.00 0.00 6,101.33 6,246.67 9,300.00 51.16 3.45 5,932.93 6,048.93 5,545.74 N 2,801.47E 2,591,943.36 1,474,944.59 0.00 0.00 0.00 6,175.79 6,324.56 f 9,400.00 51.16 3.45 5,995.64 6,111.64 5,623.49 N 2,806.15 E 2,592,021.03 1,474,950.41 0.00 0.00 0.00 6,250.25 6,402.45 9,500.00 51.16 3.45 6,058.35 6,174.35 5,701.24 N 2,810.84 E 2,592,098.70 1,474,956.22 0.00 0.00 0.00 6,324.71 6,480.34 9,600.00 51.16 3.45 6,121.07 6,237.07 5,778.99 N 2,815.52 E 2,592,176.36 1,474,962.03 0.00 0.00 0.00 6,399.17 6,558.23 9,644.54 51.16 3.45 6,149.00 6,265.00 5,813.61 N 2,817.61 E 2,592,210.96 1,474,964.62 0.00 0.00 0.00 6,432.34 6,592.92 Beluga -Q 9,700.00 51.16 3.45 6,183.78 6,299.78 5,856.73 N 2,820.21 E 2,592,254.03 1,474,967.85 0.00 0.00 0.00 6,473.63 6,636.12 9,800.00 51.16 3.45 6,246.50 6,362.50 5,934.48 N 2,824.89 E 2,592,331.70 1,474,973.66 0.00 0.00 0.00 6,548.09 6,714.01 9,900.00 51.16 3.45 6,309.21 6,425.21 6,012.23 N 2,829.58E 2,592,409.37 1,474,979.47 0.00 0.00 0.00 6,622.55 6,791.90 10,000.00 51.16 3.45 6,371.92 6,487.92 6,089.98 N 2,834.26 E 2,592,487.04 1,474,985.29 0.00 0.00 0.00 6,697.02 6,869.79 10,100.00 51.16 3.45 6,434.64 6,550.64 6,167.73 N 2,838.95 E 2,592,564.70 1,474,991.10 0.00 0.00 0.00 6,771.48 6,947.68 10,200.00 51.16 3.45 6,497.35 6,613.35 6,245.48 N 2,843.63 E 2,592,642.37 1,474,996.91 0.00 0.00 0.00 6,845.94 7,025.58 10,300.00 51.16 3.45 6,560.07 6,676.07 6,323.23 N 2,848.32 E 2,592,720.04 1,475,002.73 0.00 0.00 0.00 6,920.40 7,103.47 10,400.00 51.16 3.45 6,622.78 6,738.78 6,400.98 N 2,853.00E 2,592,797.71 1,475,008.54 0.00 0.00 0.00 6,994.86 7,181.36 09 June, 2008 - 15 :37 Page 5 of 9 COMPASS f ConocoPhillips (Alaska) Inc. -Expl HALL .BURTON North Cook Inlet Unit Plan Report for Plan: NCI A -14 - A- 14wp15 Measured TVD below Vertical Local Coordinates Map Coordinates Dogleg Build Turn Vertical Horizontal Depth Inclination Azimuth System Depth Northing Easting Northing Easting Rate Rate Rate Section Departure (ft) ( °) ( °) (ft) (ft) (ft) (ft) (ft) (ft) ( °1100ft) ( °/100ft) ( °/100ft) (ft) (51.16) 10,500.00 51.16 3.45 6,685.49 6,801.49 6,478.73 N 2,857.69 E 2,592,875.38 1,475,014.35 0.00 0.00 0.00 7,069.32 7,259.25 10,600.00 51.16 3.45 6,748.21 6,864.21 6,556.48 N 2,862.37 E 2,592,953.04 1,475,020.17 0.00 0.00 0.00 7,143.78 7,337.14 10,700.00 51.16 3.45 6,810.92 6,926.92 6,634.23 N 2,867.06 E 2,593,030.71 1,475,025.98 0.00 0.00 0.00 7,218.25 7,415.03 10,800.00 51.16 3.45 6,873.64 6,989.64 6,711.98 N 2,871.74 E 2,593,108.38 1,475,031.79 0.00 0.00 0.00 7,292.71 7,492.92 10,900.00 51.16 3.45 6,936.35 7,052.35 6,789.73 N 2,876.43 E 2,593,186.05 1,475,037.61 0.00 0.00 0.00 7,367.17 7,570.81 4111 11,000.00 51.16 3.45 6,999.06 7,115.06 6,867.48 N 2,881.11 E 2,593,263.72 1,475,043.42 0.00 0.00 0.00 7,441.63 7,648.70 11,100.00 51.16 3.45 7,061.78 7,177.78 6,945.23 N 2,885.80 E 2,593,341.38 1,475,049.23 0.00 0.00 0.00 7,516.09 7,726.59 11,192.84 51.16 3.45 7,120.00 7,236.00 7,017.41 N 2,890.14 E 2,593,413.49 1,475,054.63 0.00 0.00 0.00 7,585.22 7,798.90 A- 14wp09 Beluga U Drilling Target 11,200.00 51.16 3.45 7,124.49 7,240.49 7,022.98 N 2,890.48 E 2,593,419.05 1,475,055.05 0.00 0.00 0.00 7,590.55 7,804.48 •-•• 11,300.00 51.16 3.45 7,187.21 7,303.21 7,100.73 N 2,895.16 E 2,593,496.72 1,475,060.86 0.00 0.00 0.00 7,665.01 7,882.37 11,400.00 51.16 3.45 7,249.92 7,365.92 7,178.48 N 2,899.85 E 2,593,574.39 1,475,066.67 0.00 0.00 0.00 7,739.48 7,960.26 •••11,500.00 51.16 3.45 7,312.63 7,428.63 7,256.23 N 2,904.53 E 2,593,652.06 1,475,072.49 0.00 0.00 0.00 7,813.94 8,038.15 11,600.00 51.16 3.45 7,375.35 7,491.35 7,333.98 N 2,909.22 E 2,593,729.72 1,475,078.30 0.00 0.00 0.00 7,888.40 8,116.04 > 11,700.00 51.16 3.45 7,438.06 7,554.06 7,411.73 N 2,913.90 E 2,593,807.39 1,475,084.11 0.00 0.00 0.00 7,962.86 8,193.93 11,719.03 51.16 3.45 7,450.00 7,566.00 7,426.53 N 2,914.80 E 2,593,822.18 1,475,085.22 0.00 0.00 0.00 7,977.03 8,208.76 Base Beluga 11,800.00 51.16 3.45 7,500.78 7,616.78 7,489.48 N 2,918.59E 2,593,885.06 1,475,089.93 0.00 0.00 0.00 8,037.32 8,271.82 11,900.00 51.16 3.45 7,563.49 7,679.49 7,567.23 N 2,923.27E 2,593,962.73 1,475,095.74 0.00 0.00 0.00 8,111.78 8,349.72 12,000.00 51.16 3.45 7,626.20 7,742.20 7,644.98 N 2,927.96 E 2,594,040.40 1,475,101.55 0.00 0.00 0.00 8,186.24 8,427.61 12,100.00 51.16 3.45 7,688.92 7,804.92 7,722.73 N 2,932.64 E 2,594,118.07 1,475,107.37 0.00 0.00 0.00 8,260.70 8,505.50 12,200.00 51.16 3.45 7,751.63 7,867.63 7,800.47 N 2,937.33 E 2,594,195.73 1,475,113.18 0.00 0.00 0.00 8,335.17 8,583.39 ill 12,277.12 51.16 3.45 7,800.00 • 7,916.00 7,860.44 N 2,940.94 E. 2,594,255.63 1,475,117.66 0.00 0.00 0.00 8,392.59 8,643.46 4 BHL @ 12277.12' MD, 7916' TVD; 4001.77' FNL, 3959.44' FWL - SEC 30 - T12 - R09W - 7" 09 June, 2008 - 15:37 Page 6 of 9 COMPASS ConocoPhillips (Alaska) Inc. -Expl HALLIBURTON North Cook Inlet Unit Plan Report for Plan: NCI A -14 - A- 14wp15 Plan dnnotafionc Measured Vertical Local Coordinates Depth Depth +N/ -S +E/ -W Comment (ft) (ft) (ft) (ft) 217.00 217.00 0.00 0.00 SHL: 1302.01 FNL, 1019.29 FWL - SEC 6 - T11N - R09W 4,603.03 3,449.00 2,071.61 1,205.76 9 -5/8" @ 4510.44 FNL, 2224.83 FWL - SEC 31 - T12N - R09W 12,277.12 7,916.00 7,860.44 2,940.94 BHL @ 12277.12' MD, 7916' TVD; 4001.77' FNL, 3959.44' FWL - SEC 30- T12 -RO9W Vertical Section Information S Angle Origin Origin Start Type Target Azimuth Type +N/_S +E/ - TVD ( °) (ft) (ft) (ft) TD No Target (Freehand) 20.51 Slot 0.00 0.00 217.00 Survey tool program From To Survey /Plan Survey Tool (ft) (ft) 217.00 1,000.00 A- 15wp15 GYD -GC -SS 1,000.00 12,276.71 A- 15wp15 MWD +SCC �y Casing Details ..�^•'"` Measured Vertical Casing Hole p-�-� Depth Depth Name Diameter Diameter t (ft) (ft) ( ") (") 4,603,03 3,449.00 9 5/8" 9 -5/8 12 -1/4 12,277.12 7,916.00 7" 7 7 -1/2 formation Details Measured Vertical Dip Depth Depth TVDSS Name Lithology Dip Direction (ft) (ft) (ft) (°) ( °) 4,892.21 3,599.00 3,483.00 Top Sterling 0.00 0.00 5,152.47 3,734.00 3,618.00 CI -A 0.00 0.00 5,582.38 3,957.00 3,841.00 C1-1 0.00 0.00 6,112.54 4,232.00 4,116.00 CI -5 0.00 0.00 6,841.28 4,610.00 4,494.00 Baluga -A 0.00 0.00 9,644.54 6,265.00 6,149.00 Beluga -Q 0.00 0.00 11,719.03 7,566.00 7,450.00 Base Beluga 0.00 0.00 09 June, 2008 - 15:37 Page 7 of 9 COMPASS ConocoPhillips (Alaska) Inc. -Expl HALLIBURTON North Cook Inlet Unit Plan Report for Plan: NCI A -14 - A- 14wp15 Tarr9atg Target Name Dip Dip - hit/miss target Angle Dir. TVD +N / -S +E/ -W Northing Easting - Shape (0) (0) (ft) (ft) (ft) (ft) (ft) Latitude Longitude A- 14wp09 Beluga U 0.00 0.00 7,236.00 7,017.41 2,890.14 2,593,413.49 1,475,054.63 61° 5' 42.965 N 50° 56' 3.983 W - plan hits target - Circle (radius 150.00) A- 14wp09 Beluga I [ 0.00 0.00 5,563.00 4,943.31 2,765.17 2,591,341.57 1,474,899.55 61° 5' 22.541 N 50° 56' 6.535 W - plan hits target - Circle (radius 150.00) • S 09 June, 2008 - 15:37 Page 8 of 9 COMPASS ConocoPhillips (Alaska) Inc. -Expl HALLIBURTDN North Cook Inlet Unit North Reference Sheet for North Cook Inlet Unit - Plan: NCI A -14 - PIan:NCI A -14 All data is in US Feet unless otherwise stated. Directions and Coordinates are relative to True North Reference. Vertical Depths are relative to Plan: NCI A -14 @ 116.00ft (Kuupik 5). Northing and Easting are relative to Plan: NCI A - 14 - Slot 2008 Coordinate System is US State Plane 1983, Alaska Zone 4 using datum North American Datum 1983, ellipsoid GRS 1980 Projection method is Transverse Mercator (Gauss- Kruger) Central Meridian is 150° 0' 0.000 W °, Longitude Origin:0° 0' 0.000 E °, Latitude Origin:0° 0' 0.000 N° False Easting: 1,640,416.67ft, False Northing: 0.00ft, Scale Reduction: 0.99993224 Grid Coordinates of Weil: 2,586,439.27 ft N, 1,472,063.07 ft E Geographical Coordinates of Well: 61° 04' 33.87" N, 150° 57' 02.77" W • Grid Convergence at Surface is: -0.83° Based upon Minimum Curvature type calculations, at a Measured Depth of 12,277.12ft the Bottom Hole Displacement is 8,392.59ft in the Direction of 20.51° (True). Magnetic Convergence at surface is: - 20.07° (16 January 2008, , BGGM2007) T Magnetic Model: 800M2007 M Date: 16-Jan-08 Declination: 19.24 Inclination /Dig 73.90° Field Strength: 55654 Grid North is 0.83° West of True North (Grid Conergeno) )neticNorth is 19.24° East of True North (MagneticDedination) netic North is 20.07" East of Grid North (Magnetic Convergence) To convert a True Direction to a Grid Direction, Add 0.83° onvert a Magnetic Direction to a True Direction, Acid 1924° East convert a Magnetic Diredion to a Grid Direction, Add 20.07° 09 June, 2008 - 15:37 Page 9 of 9 COMPASS ConocoPhillips (Alaska) Inc. -Expl North Cook Inlet Unit North Cook Inlet Unit Plan: NCI A -14 PIan:NCI A -14 A- 14wp15 Sperry Drilling Services Clearance Summary „. Anticollision Report 09 June, 2008 Tray. Cylinder North Proximity Scan on Current Survey Data (North Reference) Reference Design: North Cook Inlet Unit - Plan: NCI A -14 - PIan:NCI A -14 - A- 15wp15 Well Coordinates: 2,586,439.27 N, 1,472,063.07 E (61° 04' 33.87" N, 150 57' 02.77" W) Datum Height: Plan: NCI A -14 @ 116.00ft (Kuupik 5) Scan Range: 0.00 to 12,277.12 ft. Measured Depth. Scan Radius is 1,406.01 ft . Clearance Factor cutoff is Unlimited. Max Ellipse Separation is Unlimited Geodetic Scale Factor Applied Version: 2003.16 Build: 42F Scan Type: GLOBAL FILTER APPLIED: All wellpaths within 200'+ 100 /1000 of reference Scan Type: 25.00 HALLIBURT ©N Sperry Drilling Services SURVEY PROGRAM I ConocoPhillips (Alaska) Inc. -Expl Date: 2008-06-09T00:00:00 Validated: Yes Version: 3 Engineering MD, interval: 25.00 Calculation Method: Minimum Curvature 217.00 To 12277.12 Depth From Depth To Survey/Plan Tool Error System: ISCWSA Centre Distance: 1406.01 217.00 1000.00 A- 14wp15 (PIan:NCI A -14) GYD -GC -SS Scan Method: Tray. Cylinder North Plan: A- 14wp15 (Plan: NCI A- 14 /PIan:NCI A -1 1000.00 12276.71 A- 14wp15 (Plan:NCI A -14) MVeD +SCC Error Surface: Elliptical Conic 200 Warning Method: Rules Based 1NCIU A -1 From Colour To MD = ° . •• � -..,...4.,.....4 4 . 4, ,, . • �. �. . ' 'I ll f ff j fl t e le�he�q � .- �_ � ` NCIU A -10 A -1 �� ° lR � / ht�h��e ! NCIU :� �� 217 250 s `, 3 e \ � V` � ` , � \'� pli",,,r. � �'. \\ � ; ` 250 500 300 r � Al 1,. ��o _ 300 __ ®� ,- 60 500 750 I�e,`,►�`�\k� � a \��: ° `�� .� , A / \. .I`� %( 750 i y •►ms P♦� ♦� �. y. ��i� c� ,� � f r);.ai r ® �xtia,� gr, , i► , ?i► •� J �.. NCIU A� y ��, i�, r l 1 1 , i �ywif .. w , � ! � f < ° y ' :• 270 b ~, ' e a '@ u i� 1 a y am / 1500 1750 -%_, / " ° a „ j J W PP x L C.IU A- 11� +�{ � 1 �'� ' � j * �•.•,•• f itly •A 4 [ ui t�AktP � . \ � ��/�, 2000 2500 ^ E t' jj 4 6 ' 9P ia► `��' � , r " I�� /�• 27 1'►� ' • . a;,-;H ' s t144- ♦ L- 90 4 A ,i �j ''F ,,, .i ` \ \\ 2500 3000- .-t,-; . ° r , -. '; � � •. .yam\ ∎ ` .r. �,�t ,. ° r , ,p .. 'r, ' •. ,. d r ` 0 9a o iii * , $1 .1 , �` \� � �d 0 r � 3 + 1 / ,I I ( „ 1 3000 3500 ., ,„.1, giN oft, r a s. v ` / * * * 1 A `� i i ; -� `� / ....I::: > /�• \ a ,I Ai!** . • � � • a z:,.. 1y �A r*� ` . N , ,` e,r •. MNN �I Aa► \ : �. , ` q 1A _ . I 120 3500 4000 " 1:#1 1.1l; I∎a/nr' i z , ∎ l a / 8 ID `7� . N� / 410, � 't �� 4 a� A 240 � `0A- 0 �/ % 4000 4500 -l i -4 - roc � � � . � � a. I � y�. .j „ \ a ®p.; `.% 44 1P - r � •� w� /�4♦� Iw ri eP- 1 .. '�� jD s ►i * �ot / o i re 4 -- ,•* s - � / 4500 5000 r.... , '!♦ - .44 �1 s a�,! 1 . "s ay '• 4I- .'1 `b i 5000 6000 . � c* I ! � �. f a �� of*, �� +IS ° . 1: � � . ti ` �� . � N %' ` � : t � � VP 1r t, 6000 7000 NCI 9v-t ' � \ �i � 4' .� 1s � _ i \ • � , r� � � , NC yang- / '\ ��' I . `� , ► e� i� ..c„- �` � T ��IU A -0 7000 8000 4 A � i i�.I I :'a t', / i 10 /� .. �OL1.0 4 4 -..1 � ,� 240 . '` _ r, , X y1 <i jo , ��` 4 ?Op..- t�0 4 ,„ - r , z / .,� NCIU A-16 8000 9000 c- ' Y O 4 ,• ` + i��` 1 i , � �� '••• / ravellin Cylinder Azimuth (TFO +AZI) [ s Centre to Centre Separation 20 IOW 9000 10000 \ 1 �� ra l , ." ``'47' ' i ��.�' i �. - 1 0000 12000 w ;�o . ��' � � N' �� / 12000 14000 ® v 4 >!�4 � . • 14000 16000 , NCIUA ° ^ S ` / �� i :,,' � 16000 -_ 18000 { 'NCIU A-"� NC �� 9 18000 20000 1 ,. i` 20000 25000 ` jra11 A -1'" NCIU A-0# 180 SECTION DETAILS O Sec MD Inc Azi TVD +N / -S +E / -W DLeg TFace VSec Target 1 217.00 0.00 0.00 217.00 0.00 0.00 0.00 0.00 0.00 2 450.00 0.00 0.00 450.00 0.00 0.00 0.00 0.00 0.00 3 550.00 2.00 330.00 549.98 1.51 -0.87 2.00 330.00 1.11 4 700.00 2.00 150.00 699.95 1.51 -0.87 2.67 180.00 1.11 NAD 27 ASP Zone 4 : WELL DETAILS: Plan: NCI A - ...... 5 900.00 3.00 110.00 899.77 -3.30 5.79 0.98 -81.19 -1.06 6 2236.45 40.00 20.00 2129.57 405.17 193.27 3.00 -93.57 447.20 Water Depth: 101.00 7 2937.78 58.75 32.76 2585.22 874.37 435.33 3.00 31.74 971.48 +N/ +E/ NOrthin Easting Latittude LOn nude SIOt 8 7272.83 58.75 32.76 4833.85 3991.06 2440.95 0.00 0.00 4593.36 9 9 9 w� 9 8525.17 51.16 3.45 5563.00 4943.31 2765.17 2.00 - 115.74 5598.84 A- 14wp09 Beluga I Drilling Target 0.00 0.00 2586439.27 1472063.07 61° 4' 33.866 N 150° 57' 2.770 W 2008 ax 192.84 51.16 3.45 7236.00 7017.41 2890.14 0.00 0.00 7585.22 A- 14wp09 Beluga U Drilling Target REFERENCE INFORMATION w� 1112277.12 51.16 3.45 7916.00 7860.44 2940.94 0.00 0.008392.59 Co- ordinate (N /E) Reference: Well Plan: NCI A -14 - Slot 2008, True North 1 Vertical (TVD) Reference: Plan: NCI A -14 0 116.00tt (Kuupik 5) ••+� Section (VS) Reference: Slot - 2008(0.00N, 0.00E) r Measured Depth Reference: Plan: NCI A -14 0 116.00ft (Kuupik 5) 1 Calculation Method: Minimum Curvature ConocoPhillips (Alaska) Inc. -Expl HALLIBLJRTON North Cook Inlet Unit Anticollision Report for Plan: NCI A -14 - A- 14wp15 Tray. Cylinder North Proximity Scan on Current Survey Data (North Reference) Reference Design: North Cook Inlet Unit - Plan: NCI A -14 - PIan:NCI A -14 - A- 15wp15 Scan Range: 0.00 to 12,277.12 ft. Measured Depth. Scan Radius is 1,406.01 ft . Clearance Factor cutoff is Unlimited. Max Ellipse Separation is Unlimited Measured Minimum @Measured Ellipse @Measured Clearance Summary Based on Site Name Depth Distance Depth Separation Depth Factor Minimum Separation Warning Comparison Well Name - Wellbore Name - Design (ft) (ft) (ft) (ft) ft North Cook Inlet Unit NCIU A -01 - N COOK INLET UNIT A -01 - N COOK INI 1,517.09 47.11 1,517.09 23.43 1,500.00 1.989 Clearance Factor Pass - Major Risk • NCIU A -02 - N COOK INLET UNIT A -02 - N COOK INI 225.00 85.73 225.00 84.14 225.00 53.986 Centre Distance Pass - Major Risk NCIU A -02 - N COOK INLET UNIT A -02 - N COOK INI 699.76 88.95 699.76 79.77 700.00 9.689 Clearance Factor Pass - Major Risk NCIU A -03 - N COOK INLET UNIT A -03 - N COOK INI 1,120.91 34.76 1,120.91 18.00 1,125.00 2.074 Clearance Factor Pass - Major Risk NCIU A -04 - N COOK INLET UNIT A -04 - N COOK INI 1,153.15 65.61 1,153.15 47.84 1,150.00 3.692 Clearance Factor Pass - Major Risk NCIU A -05 - N COOK INLET UNIT A -05 - N COOK INI 225.00 88.30 225.00 86.05 225.00 39.347 Centre Distance Pass - Major Risk NCIU A -05 - N COOK INLET UNIT A -05 - N COOK INI 2,666.50 114.13 2,666.50 47.95 2,600.00 1.725 Clearance Factor Pass - Major Risk NCIU A -06 - N COOK INLET UNIT A -06 - N COOK INI 1,147.84 36.63 1,147.84 19.94 1,150.00 2.194 Clearance Factor Pass - Major Risk CD NCIU A -07 - N COOK INLET UNIT A -07 - N COOK INI 1,251.37 46.30 1,251.37 26.62 1,250.00 2.352 Clearance Factor Pass - Major Risk 73 NCIU A -08 - N COOK INLET UNIT A -08 - N COOK INI 1,128.85 61.72 1,128.85 44.30 1,125.00 3.544 Centre Distance Pass - Major Risk NCIU A -08 - N COOK INLET UNIT A -08 - N COOK INI 1,153.65 61.81 1,153.65 43.96 1,150.00 3.463 Clearance Factor Pass - Major Risk G) NCIU A -09 - N COOK INLET UNIT A -09 - N COOK INI 217.60 10.99 217.60 9.56 175.00 7.678 Centre Distance Pass - Major Risk ......-. NCIU A -09 - N COOK INLET UNIT A -09 - N COOK INI 743.09 14.48 743.09 4.53 700.00 1.455 Clearance Factor Pass - Major Risk = NCIU A -10 - N COOK INLET UNIT A -10 - N COOK INI 467.67 5.50 467.67 2.52 425.00 1.849 Clearance Factor Pass - Minor 1/50 NCIU A -10 - N COOK INLET UNIT A -10A - N COOK If 467.67 5.50 467.67 2.52 425.00 1.849 Clearance Factor Pass - Minor 1 /50 y ' NCIU A -11 - N COOK INLET UNIT A -11 - N COOK INI 217.70 4.37 217.70 2.46 175.00 2.285 Centre Distance Pass - Minor 1/200 NCIU A -11 - N COOK INLET UNIT A -11 - N COOK INI 742.79 6.19 742.79 1.99 700.00 1.475 Clearance Factor Pass - Minor 1/200 • NCIU A -12 - N COOK INLET UNIT A -12 - N COOK INI 625.03 60.52 625.03 51.42 625.00 6.649 Centre Distance Pass - Major Risk NCIU A -12 - N COOK INLET UNIT A -12 - N COOK INI 649.37 60.68 649.37 51.13 650.00 6.358 Clearance Factor Pass - Major Risk NCIU A -13 - N COOK INLET UNIT A -13 - N COOK INI 234.00 70.81 234.00 68.62 250.00 32.383 Centre Distance Pass - Major Risk NCIU A -13 - N COOK INLET UNIT A -13 - N COOK INI 633.70 72.47 633.70 63.57 650.00 8.146 Clearance Factor Pass - Major Risk NCIU A -13 - N COOK INLET UNIT A -13PB1 - N COOP 234.00 70.81 234.00 68.62 250.00 32.383 Centre Distance Pass - Major Risk NCIU A -13 - N COOK INLET UNIT A -13PB1 - N COOP 657.89 72.82 657.89 62.58 675.00 7.109 Clearance Factor Pass - Major Risk NCIU A -13 - N COOK INLET UNIT A -13PB2 - N COOP 234.00 70.81 234.00 68.62 250.00 32.383 Centre Distance Pass - Major Risk NCIU A -13 - N COOK INLET UNIT A -13PB2 - N COOP 657.89 72.82 657.89 62.58 675.00 7.109 Clearance Factor Pass - Major Risk NCIU A -13 - N COOK INLET UNIT A -13PB3 - N COOP 234.00 70.81 234.00 68.62 250.00 32.383 Centre Distance Pass - Major Risk NCIU A -13 - N COOK INLET UNIT A -13PB3 - N COOP 657.89 72.82 657.89 62.58 675.00 7.109 Clearance Factor Pass - Major Risk NCIU A -13 - N COOK INLET UNIT A -13PB4 - N COOP 234.00 70.81 234.00 68.62 250.00 32.383 Centre Distance Pass - Major Risk 09 June, 2008 - 15:43 Page 2 of 6 COMPASS 1 ConocoPhillips (Alaska) Inc. -Expl HALLIBURTQN North Cook Inlet Unit Anticollision Report for Plan: NCI A -14 - A- 14wp15 Tray. Cylinder North Proximity Scan on Current Survey Data (North Reference) Reference Design: North Cook Inlet Unit - Plan: NCI A -14 - PIan:NCI A -14 - A- 15wp15 Scan Range: 0.00 to 12,277.12 ft. Measured Depth. Scan Radius is 1,406.01 ft . Clearance Factor cutoff is Unlimited. Max Ellipse Separation is Unlimited Measured Minimum @Measured Ellipse @Measured Clearance Summary Based on Site Name Depth Distance Depth Separation Depth Factor Minimum Separation Warning Comparison Well Name - Wellbore Name - Design (ft) (ft) (ft) (ft) ft NCIU A -13 - N COOK INLET UNIT A -13PB4 - N COOF 657.89 72.82 657.89 62.58 675.00 7.109 Clearance Factor Pass - Major Risk NCIU A -13 - N COOK INLET UNIT A -13PB5 - N COOF 234.00 70.81 234.00 68.62 250.00 32.383 Centre Distance Pass - Major Risk • NCIU A -13 - N COOK INLET UNIT A -13PB5 - N COOF 657.89 72.82 657.89 62.58 675.00 7.109 Clearance Factor Pass - Major Risk NCIU A -13 - N COOK INLET UNIT A -13PB6 - N COOF 234.00 70.81 234.00 68.62 250.00 32.383 Centre Distance Pass - Major Risk NCIU A -13 - N COOK INLET UNIT A -13PB6 - N COOF 657.89 72.82 657.89 62.58 675.00 7.109 Clearance Factor Pass - Major Risk NCIU A -13 - N COOK INLET UNIT A -13PB7 - N COOT 234.00 70.81 234.00 68.62 250.00 32.383 Centre Distance Pass - Major Risk t NCIU A -13 - N COOK INLET UNIT A -13PB7 - N COOF 657.89 72.82 657.89 62.58 675.00 7.109 Clearance Factor Pass - Major Risk NCIU B -01 - N COOK INLET UNIT B -01 - N COOK INI 658.16 56.38 658.16 48.03 675.00 6.756 Centre Distance Pass - Major Risk NCIU B -01 - N COOK INLET UNIT B -01 - N COOK INI 1,080.67 57.29 1,080.67 42.79 1,100.00 3.951 Clearance Factor Pass - Major Risk NCIU B -01 - N COOK INLET UNIT B -01A - N COOK It 658.16 56.38 658.16 48.03 675.00 6.756 Centre Distance Pass - Major Risk � ^^, NCIU B -01 - N COOK INLET UNIT B -01A - N COOK IF 1,080.67 57.29 1,080.67 42.79 1,100.00 3.951 Clearance Factor Pass - Major Risk CTS 0--- -- NCIU B -02 - N COOK INLET UNIT B -02 - N COOK INI 609.40 59.71 609.40 52.00 625.00 7.751 Centre Distance Pass - Major Risk am ,, NCIU B -02 - N COOK INLET UNIT B -02 - N COOK INt 658.04 60.06 658.04 51.63 675.00 7.126 Clearance Factor Pass - Major Risk NCIU B -02 - SUNFISH 3 - SUNFISH 3 609.40 59.71 609.40 52.44 625.00 8.211 Centre Distance Pass - Major Risk --- NCIU B -02 - SUNFISH 3 - SUNFISH 3 658.04 60.06 658.04 52.06 675.00 7.512 Clearance Factor Pass - Major Risk r---- NCIU B -03 - N COOK INLET UNIT B -03 - N COOK INI 234.00 68.54 234.00 66.41 250.00 32.164 Centre Distance Pass - Major Risk NCIU B -03 - N COOK INLET UNIT B -03 - N COOK INI 358.99 69.77 358.99 65.62 375.00 16.812 Clearance Factor Pass - Major Risk NCIU B -03 - N COOK INLET UNIT B -03PB1 - N COOF 234.00 68.54 234.00 66.41 250.00 32.164 Centre Distance Pass - Major Risk NCIU B -03 - N COOK INLET UNIT B -03PB1 - N COOF 358.99 69.77 358.99 65.62 375.00 16.812 Clearance Factor Pass - Major Risk III Plan: NCI A -15 - PIan:NCI A -15 - A- 15wp14 425.00 9.81 425.00 5.57 425.00 2.316 Centre Distance Pass - Major Risk Plan: NCI A - 15 - Plan:NCI A - 15 - A - 15wp14 824.80 11.75 824.80 1.44 825.00 1.139 Clearance F Riek Plan: NCI A - 16 - PIan:NCI A - 16 - A - 16wp14 425.00 4,01 425.00 1.51 425.00 1.912 Centre Diatanas P - Minor 1/200 Plan: NCI A - 16 - PIan:NCI A - 16 - A - 16wp14 499.99 4.18 499.99 1:80 500.00 1.624 Clearance Factor Pas - MOW 11200 09 June, 2008 - 15:43 Page 3 of 6 COMPASS ConocoPhillips (Alaska) Inc. -Expl HALLIBURTDN North Cook Inlet Unit Anticollision Report for Plan: NCI A -14 - A- 14wp15 Survey tool aroaram From To Survey /Plan Survey Tool (ft) (ft) 217.00 1,000.00 A- 15wp15 GYD -GC -SS 1,000.00 12,276.71 A- 15wp15 MWD +SCC Ellipse error terms are correlated across survey tool tie -on points. Calculated ellipses incorporate surface errors. Separation is the actual distance between ellipsoids. • Distance Between centres is the straight line distance between wellbore centres . Clearance Factor = Distance Between Profiles / (Distance Between Profiles - Ellipse Separation). All station coordinates were calculated using the Minimum Curvature method . • D 1 09 June, 2008 - 15:43 Page 4 of 6 COMPASS ConocoPhillips (Alaska) Inc. -Expl HALLIBURTDN North Cook Inlet Unit Anticollision Report for Plan: NCI A -14 - A- 14wp15 Direction and Coordinates are relative to True North Reference. Vertical Depths are relative to Plan: NCI A -14 @ 116.00ft (Kuupik 5). Northing and Easting are relative to Plan: NCI A -14 - Slot 2008. Coordinate System is US State Plane 1983, Alaska Zone 4. Central Meridian is - 150,00 °, Grid Convergence at Surface is: -0.83 °. Ladder I -I-- t +CIU A -04, N COOK INLET UNIT A -04, N COOK INLE -$- hCILI B -02, SUNFISH 3, SUNFISH 3 VO • -g- hCIU B -02, N COOK INLET UNIT B -02, N COOK INLE -- I + - - -- - - -- I - $ UT hCIA-07,NCOOKINLETUNITA-07,NCOOKINLE I lil rj r I I hCIUA-05,N COOK INLET UNIT A-05,N COOK INLE 1 11` " .ti. 1 I,. I P an: NCI A -16, PIan:NCI A -16, A- 16wp14 V1 11 1 t , . I � I I I "� 1200 11,:r 1 �._ �. t CIUA- 01 , N COOK INLET UNIT A- 01,N COOK INLE O I Pi: 1 f ,k 1 I I _.- BRU 243 -34 Rig, BRU 243 -34 Rig, B RU 243-34 Rig Survey © I " . 1 i i .$ - t+ CIUA-03,NCOOKINLETUNITA-03,NCOOKINLE - -- I � IA -- - - - -- I 1_ _)_ I I 1 - {} hCIU.A -O6, N COOK INLET UNIT A -06, N COOK IN LE' 1 l I 1 , + , 1 1 1i 1 I I -0- hCIU 8.03, N COOK INLET UNIT B -03, N COOK INLE T 7 f,> r I I ' hCIU B -0`s, N COOK INLET UNIT B- 03PB1, N COOK I It -'.+� �1 800 it r -$- .LIU B-01, N COOK INLET UNIT B -01, N COOK INLE ' i i, 1 f.' 'N !} 1 - i i -i_ hCIU B -01, N COOK INLET UNIT 0-01A, N COOK INLE1 .,.` (f) I 1 1 I I -9..t- CILI A-09,N COOK INLET UNIT A-09,N COOK INLE r1 1 I`�. 1 I 1 I (� l y i ____ _____ I _ hCUA- 10 ,NCOOKINLETUNITR•10A,NCOOKINL.1 y � i �l't l I .4-. hCILI A -10, N COOK INLET UNIT A -10, N COOK INLE o� - +j r"-- �� r I r I I _X- P an: NCI A -15, PIan:NCIA- 16,A- 15wp14V3 I " 1 I 1 � ._I �- h UNIT A -11, N COOK INLET NIT A -11, N COOK INLE 400- Iff , � ..1 r I • 15? i 'r1 1 , i ; . . f I I • I I 4_NCIU -02,N COOK INLET UNIT A- 02,NCOOKINLE I � , I I I I -e- hCIU A -08. N COOK INLET UNIT A -08, N COOK INLE T . � 1 �. .. I c1 I ��',' ??. F'__ -- __ 1 I 1 _ -. - h CIUA -13,N COOK INLET UNIT A-13, N COOK INLE 0 ' + - " J - 1I , I - r h CIU A -13, N COOK INLET UNIT A- 13P84, N COOK I II 1 I I $ r I 1 I .CIU A -13, N COOK INLET UNIT A•13PB5, N COOK 111 I ( t --- .CIU A -13, N COOK INLET UNIT A- 13P97, N COOK 111 (] 1500 u�� L15 a jQ�Q � (�� -4- hCIU A -13, N COOK INLET UNIT A- 13PB2, N COOK 111 -$- hCIU A -13, N C00K INLET UNIT A- 13PB6, N COOK 141 Measured Depth (1500 ftlin) -g- hCIU A -13, N COOK INLET UNIT A- 13PB1, N COOK I ...... I.1'lll 4-1'4„ M r.n rI k MI FT IIIJIT S1113111 IJ r Il rI k 1.,,L 09 June, 2008 - 15:43 Page 5 of 6 COMPASS ConocoPhillips (Alaska) Inc. -Expl HALLIBURTON North Cook Inlet Unit Anticollision Report for Plan: NCI A -14 - A- 14wp15 Clearance Factor Plot: Measured Depth versus Separation(Clearance) Factor T ' f t f t I I } � � � AT � ~ � r NCIU A -04, N COOK INLET UNIT A -04, N COCK INLET UN ■ - +. ( .; I vU - I NCIU 0•G2, SUNFISH 3, SUNFISH 3 10130 _ ' i , 1111. +. ._.._._�_ _1111__.- 1 ! l :M -i �1 NCIU 0-02, N COOK INLET UNIT 0-02, N COOK INLET UN C 11 J ' I NCIU A -07, N COOK INLET UNIT A-07, N COOK INLET UN 44 E r 11 A•OS, N COOK INLET UNIT A -05, N COOK INLET UN I + 1i' s _ --_ -_ l_ 1,1CIU lan: NCIA- 16,Plan:NCIA- 16,A- 16wp14VI . i - ' . � I. ! NCIU A:01, N COOK INLET UNIT A -01, N COOK INLET UN - '1 r I I RU 243-34 Rig, BRU 243-34 Rig, BRU 243-34 Rig Surveys ` _ , „ _� ._ _ -_ 0 �' L NCIU A -03, h1 CGOK INLET UNIT A -03, N COOK INLET UN S - g'1, I r. o _ 1 �� I CIU A -06, N COOK INLET UNIT A -O6, N COOK INLET UN ra _ 1111 ._ - +!' , : ' - ___.. NCIU 0 -03, N COOK INLET UNIT B -03, N COOK INLET UN _y1 %. +l + �; �+ __ -_� __ _1111.. _� NCIU B -03, N COOK INLET UNIT B- 03PB1, N COOK INLET 111 c�' ' + I ( t NCIU 0-01, N COOK INLET UNIT 0-01, N COOK INLET UN ca - - t _ i I NCIU 0.01, N COOK INLET UNIT 0.O1A, N COOK INLET UI -1• c a n ! ) -- - - - -- a ' ! I + ......_.� - - - -- . � - - - --- --- .�. ---- - -1111 __ - _________.. -___ NCIU A -0 0 , N COOK I N L ET UNIT A -0 9 , N COOK I N L ET U N 's NCIU A -10, N COOK INLET UNIT A -10A, N COOK INLET UI .. - _ i ' ;' �''�"/ � - It, II I I NCIU A -10, N COOK INLET UNIT A -10, N COOK INLET UN V [�i7 t 7 5 - ' -- 1 ' E; I - - i._---- -- _ L __. Plan: NCI A-15, I N C I A- 1 P a n: , V3 _ V 1� * 1 5 A• 15wp14 .»� t + NCIU A -11, N COOK INLET UNIT A -11, N COOK INLET UN : 'y p c�- I NCIU A -02, N COOK INLET UNIT A -02, N COOK INLET UN _ � - - _ r1� f �+ t� _11-11. _ 1111 __ ` .._ r- NCIU A -OS, N COOK INLET UNIT A -GH, N COOK INLET UN %" t I - n 1111 NCIU A -13, N COOK INLET UNIT A -13, N COOK INLET UN I 2:5 ; I - } T JCIU A -13 COOK INLET UNIT A -1 zPBS, N COOK INLET • NCIU A-13, N COOK INLET UNIT A•13PB7, N COOK INLET - ... .. .... ? I . ' -II- NCIU A•13, N COOK INLET UNIT A- 13P02, N COOK INLET 0P0 i i i i 1 1 1 1 iiii I I I i i i i i I I I I I I I+ +` I I+ I I+ I I I I I I I I`+ I I I I ++ I ` NCIU A-13, N COOK INLET UNIT A- 13PB6, N COOK INLET 0 730 1500 2250 .3000 .3750 4500 .32 50 6000 6710 7500 '3::.50 0000 , NCIU A•13, N COOK INLET UNIT A•13P01, N COOK INLET Measured Depth (1 500 11.4n) 4. NCIU A -13, N COOK INLET UNIT A- 13P03, N COOK INLET 09 June, 2008 - 15:43 Page 6 of 6 COMPASS • Application for Pe. Drill, Wells NCIU A-14, A-15, A-16 Revision No.0 Saved: 9-Jun-08 Attachment 2. BOPE & Diverter nr)Ir‘INIA1 4 • Revised 5 -08 Rig Floor 21" Bottom of Rota Table 8' 14" : ottom of Rota Beams i 51" Flow Nipple I I 1 ' 45" 13 5/8" Annular 1 I I N 121" 10'1" 34 1/4" 13 5/8" Double Gate L J 24" 13 5/8" Mud Cross i o ° J 0 o 1 8 M 17 3/4" 13 5/8" Single Gate I I M 8" 36" Sub Base Skid 24" Kuukpik Skid Base 82" Phillips Sub Skid Base 8 I 6" Pin Rails - Drill Deck 154" from wellhead to drill deck 2 " 3" To Shaker 3" Panic To Gasbuster 3 1/8" _ 2 1/16" �-O a 2 1/16" O 2 1/16" + 2 1/16" + i ^ ._./ 3 1/8" O O V / L . el 1 01 IC) 2 1/16" dh2 1/16" Manual Choke 111 Automatic Choke 2 1/16" Inlet Pressure Sensor 3" i 3" 5,000 PSI Choke Manifold Kuukpik Drilling Rig 5 RED = 3 1/18" 5,000 PSI VALVES AND LINES BLUE = 2 1/16" 5,000 PSI VALVES Kuukpik Drilling Rig 5 Choke Manifold Drawn By: L Ross Date: 8/1/04 • • Revised 5-08 Rig Floor 1 21" Bottom of Rotary Table _ , 7.5" 1 14" ottom of Rotary Beams $ 8 1 1 20" Annular I 50.5" I L g I } Diverter opening center line 1 $ Diverter Spool o Diverter Line Openir g 1 o f 72" [ 8 2 ro 0 8 m I ■ ■ ' I ' 8 �r 1 21 1/4" 2,000 Flange 8 36" Sub Base Skid i gi Li 24" Kuukpik Skid Base 82" Phillips Sub Skid Base i ■ 1 B 0 ................4 _ __________ ___ - _ - _.... ........._._................... o ! m o i o o 0 I,o c 0 o o I � Lo i 1 j 6" Pin Rails I I Drill Deck 208" from Wellhead to drill deck OR • Application for Pel, Drill, Wells NCIU A -14, A -15, A -16 Revision No.0 Saved: 9- Jun -08 Attachment 3. Drilling Hazards Summary 12 -1/4" Hole / 9 -5/8" Casing Interval Event Risk Level Mitigation Strategy / Contingency Collision with existing platform High Re -survey existing wells with high accuracy gyro, wells set downhole plugs in wells that do not pass Major Risk and present possibility of uncontrolled flow, pressure surveys in existing wells, existing well monitoring & shut -in plan Clay Balling Medium Maintain planned mud parameters, Increase mud weight, use weighted sweeps, reduce fluid viscosity, control ROP. Running sands & gravel Moderate Maintain planned mud parameters, Increase mud weight /viscosity, Use weighted sweeps, monitor fill on connections Abnormal Pressure in Surface Low Diverter drills, increased mud weight. Offset drilling Formations does not indicate abnormal pressures in the surface hole. Hole swabbing/Tight hole on Moderate Circulate hole clean prior to trip, proper hole filling trips (use of trip sheets), pumping out of hole as needed Stuck surface casing Low Clean the hole before running casing, pump high density high viscosity sweeps, wiper trip Lost circulation Low Keep hole clean. If losses occur — reduce pump rates and mud rheology, use LCM, controlled running speeds 8 -3/4" Hole / 7" Casing Interval Event Risk Level Mitigation Strategy / Contingency Insufficient or Low Importance of LOT communicated to all parties, undetermined LOT all parties familiar with LOT procedure. Test will be carried out until leak off is observed or to an FIT of 18 ppg MW equivalent High ECD / Tight hole on Moderate Condition mud & clean hole prior to trips. trips/ Swabbing Reduced trip speeds. Monitor ECDs with PWD tool. Hole cleaning best practices. Backream out on trips as a last resort, proper hole filling (use of trip sheets) Differential sticking High Keep hole clean, periodic wiper trips, keep pipe moving /rotating with pumps on whenever possible Unstable coals High Communicate warning signs & expectations, follow best practices, PU immediately when detected, control drill one to two feet at a time. Keep surge and swab effects under control. Sloughing shale, tight hole High Increased mud density to control the shales and fluid composition according to plan, controlled trip speeds, sweeps, ECD monitoring. $ Application for Pere Drill, Wells NCIU A -14, A -15, A -16 Revision No.O Saved: 9- Jun -08 Event Risk Level Mitigation Strategy / Contingency Lost circulation High Pretreat mud before drilling low pressured sections, keep hole clean — use PWD to monitor hole cleaning, reduced trip speeds. If losses occur — reduce pump rates and mud rheology, use LCM Abnormal Reservoir Low Well control drills, increased mud weight, offset Pressure well data does not indicate abnormal pressures in the area. Hydrogen Sulfide gas Low H2S drills, detection systems, alarms, standard well control practices, mud scavengers JR • Application for Pe. Drill, Wells NCIU A -14, A -15, A -16 Revision No.0 Saved: 9- Jun -08 Attachment 4. Fluid System • N • • • --------41-14 . : Volume Tank - ,,-- Suction Tank 1 1 R 1 : 1■ g 1 Mud Tanks With Mud Flow I Mud Tanks With Tank Compartments and Agitators 1 r_T ,, Volume Tank Suction Tank "k R- + 1 Deg000er Tank Cente: rook. Skicii,;n Tank ! ■ 00 BOLO 100 BBLS '/o ,,,,,- 0«551.S Till Took STOOLS TO-OSLO 520 OSLO Activt, V.Iwne 025<101.9 Trip Tank 30551.5 Till lark ,. . HI 1 • 1 F r d Gun Lines in an 1111111 ', : -. Volume e Suction Tank d5 Upper Building With Solids Equipment 000000 C : H Chwpica: BBI ',, ) , Centrifuge i '.,, . --a-11 7 --1 Kuukpik Drilling Rig 5 Rig 015<1 Syster, MSolids El,,..tipmen,FlowNolumes Drawinsp Mud System on Leg 2 Tyonek Platform Drawn By: L Ross Tyonek Piatfvm Date: 6/15/03 . . nr). Ir‘ it, 4 Pi 1 0 Application for POto Drill, Wells NCIU A -14, A -15, A -16 Revision No.O Saved: 9- Jun -08 Attachment 5. Well Schematics Conductor (Exisitingl: i fi 30" set @ - 400 ft s { NCIUA-14 SCSSSV with 14" SS control line to surface ¢ r a + /- 400'MD $ r ore ✓ r f r i 4. .. ? ; A j J i 'f TOC 600' i r TOC +/_ 4391' MD / 3339' TVD above top Cook Inlet i i f Surface Casing: + r 9 -5/8 ", 40 #, L -80, BTCM 1 Set @ 4603' MD / 3449' TVD al a, v (150' TVD above Cook Inlet) $ / • � Ilk r i Halliburton HES HO stage tool (8 +/- 4900' MD — CONTINGENCY IF THERE ARE LOST CIRCULATION 0 0 0I PROBLEMS-- 4-¼" Camco KGB -2 GLM w/ 1" DCK2 shear valve R f • -:I t SC -2 Packer wl Millout Extension 0 ■ WNW!'. S 5 Formaton: SC -1L Isolation Packer r SC -1L Isolation Packer _ =_ j v 3 Zone MZ Pack SC -1L Isolation Packer v Model FS Sump Packer $ - +�7 SC -2 Packer w/ Alternate Bore f i 1 p1 5, v 5 Conventional j Gravel Pack Beluga A i s i SC -2 Packer w/ Alternate Bore i Lower Beluga ± 1 1 require 4 r Conventional will re q i Gravel Pack Fracs followed 5 ; i 0 SC -2 Packer w/ Alternate Bore by HRWPs $ ___ ____ y Bi Conventional $ Gravel Pack Model FS Sump Packer $ a Production Casing; 51 I • 7 ", 26.00 #, L -80, BTCM i Set @ 12277' MD / 7916' TVD G.- i ORIGINAL • • TRANSMITTAL LETTER CHECKLIST WELL NAME /VGA L-C. '4 — /4 PTD# 0.0e-0 �Cv I Development, Service Exploratory Strati ra hic Test r'Y g P Non -Con entional Well FIELD: &OA frtki POOL: ✓ 4. S .°'O1 Circle 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 (If last two digits in Permit No. , API No. 50- - 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(0, 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 t• in --.mpliance with 20 AAC EXCEPTION 25.055. Approval to perforate a d • roduc- / in'ect is contingent upon issuance f a cone io • • approving a spacing exception. rrs�t j�Ad%e assumes the liability of any protest to the spacing4xception that may occur. DRY DITCH All dry ditch sample sets submitted to the Commission must be in SAMPLE no greater than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals through target zones. Non - Conventional Please note the following special condition of this permit: Well production or production testing of coal bed methane is not allowed for (name of well) until after (Companv 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: 1/112008 WELL PERMIT CHECKLIST Field & Pool NORTH COOK INLET, TERTIARY GAS - 564570 Well Name: N COOK INLET UNIT A -I4 Program DEV Well bore seg ❑ PTD#: 2080960 Company CONOCOPHILUPS ALASKA INC Initial Class/Type DEV / PEND GeoArea 820 Unit 11450 On /Off Shore Off Annular Disposal ❑ Administration 1 Permit fee attached NA _ 2 Lease nurnberappropriate - - Yes - - - 3 Unique well_ name and number _ Yes 4 Well located in a definedpool Yes NORTH COOK INLET, TERTIARY GAS P001 -- 564570, governed by CO 68. - 5 Well located proper distance from drilling unit boundary No SPACING EXCEPTION REQUIRED: Well does _not conform to the "cluster spacing" pattern required by Rule 2 6 Welltocated proper distance from other wells No of CO 68, Exception currently_ being drafted by_ Commission staff, and will be in place prior to spud. 7 Sufficient acreage_avaiiable in_drilling unit No _ 8 If deviated, is_wellbore plat included Yes 9 Operator only affected party Yes - 10 Operator has_ appropriate bond in force Yes 11 Permit can be issued without conservation order No Exception currently being drafted by _Commission staff_ and will be in placepriorto spud. Appr Date 12 Permit can be issued without administrative approval Yes - - SFD 6/12/2008 13 Can permit be approved before 15-day waft Yes 14 Well located within area arid strata authorized by Injection Order # (put 10# in_comments)(For NA 1111k 15 All wells- within 1(4_mile_area_of review identified (For service well only) NA 16 Pre - produced injector; duration of pre production less than 3 months_ (For SWAGS well only) _ _ NA 17 Nonconven, gas_conforms to AS31.0503Q(j,1-.A),(j.2.A -D) _ NA Engineering 18 Conductor string_provided _ Yes - - 19 Surface casing_ protects all_known USDWs _ Yes AEO 4 exempts all aquifers below 29Q' rnd in well NClli A-12. Surface csg planned at 3449' tvd. _ 20 CMT_vol. adequate to circulate_on conductor & surf csg _ Yes - 21 CMT vot adequate to tie -in Jong string to surf csg _ No 22 CMT will coverall known_productive horizons Yes 23 Casing designs adequate for C,_T, SA_ permafrost Yes 24 Adequate tankage or reserve pit Yes Wastes to be discharged as allowed. _Class 2 disposal well available if needed. 25 If _a re-drill, has a10-403 for abandonment been approved NA 26 Adequate wellbore separation_proposed Yes Proximity analysis performed. Traveling cylinder path calculated. Gyros likely in surface hole. 27 f di verterrequired, does it meet regulations Yes Diverter line is short, but extends beyond_ platform edge. _ Appr Date 28 Drilling fluid_ program schematic_& eq_uiplist adequate _ Yes Maximum expected formation pressure up to 9.0 ppg in virgin Beluga._ Planned MW up to 9.6ppg. - TEM 7/1/2008 29 BOPEs,_do theymeet regulation Yes 0., 30 BOPE_press rating appropriate; test to_(put psig in comments) Yes - MASP calculated at 2600 psi. 3500 psi drilling test _proposed and 5000 psi for completions. • W.T.S\ 31 Chokernanifold complies w /APt -RP -53 (May 84) - Yes 32 Work will occur without operation shutdown No 3 wells will be batch drilled resulting in some SD time on all wells. 33 Is presence of H2S gas probable _ No H2S is not reported in Cook Inlet gas production. - 34 Mechanical condition of wells within AOR verified (For service well only) NA _ - Geology 35 Perrnit can be issued w/o hydrogen sulfide measures Yes _ H2S not anticipated in this gas pool. 36 Data_presented on potential overpressure_zones Yes _ Reservoir pressure in ov_erlyingCook inlet sands may be 2 ppg,EMW,_but Appr Date 37 Seismic analysis of shallow gas zones NA _ expected to be 6.9 - 9.0 in Beluga; will be drilled with 9.6 ppg mud. SFD 6/12/2008 38 Seabed condition survey(if off-s hore) _ _ NA _ 39 Contact name /phone for weekly_progress reports [exploratory only] NA Geologic Engineering Pu. ' New, extended -reach well designed to tap additional reserves trapped in isolated channel sand bodies. Reservoirs open to Commissioner: Date: Commissioner: Date Com Date / i wellbore will lie more than 4000' from nearest exterior boundary of the N Cook Inlet Unit. "46 1/Thoc:9 Well History File APPENDIX Information of detailed nature that is not • particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. l i No special effort has been made to chronologically • organize this category of information. • • NCIU A- 14.tapx Sperry -Sun Drilling Services LIS Scan Utility $Revision: 3 $ LisLib $Revision: 4 $ Tue Dec 09 17:26:21 2008 Reel Header Service name LISTPE Date 08/12/09 Origin STS Reel Name UNKNOWN Continuation Number 01 Previous Reel Name UNKNOWN Comments STS LIS Writing Library. Scientific Technical Services Tape Header Service name LISTPE Date 08/12/09 Origin STS Tape Name UNKNOWN Continuation Number 01 Previous Tape Name UNKNOWN Comments STS LIS Writing Library. Scientific Technical Services Physical EOF Comment Record TAPE HEADER North Cook Inlet MWD /MAD LOGS WELL NAME: NCIU A -14 API NUMBER: 508832012500 OPERATOR: ConocoPhillips Alaska, Inc LOGGING COMPANY: Sperry Sun TAPE CREATION DATE: 09- DEC -08 JOB DATA MWD RUN 2 MWD RUN 3 MWD RUN 4 JOB NUMBER: MW- 000574471 MW- 000574471 MW- 000574471 LOGGING ENGINEER: S. LATZ S. LATZ A. MENEZES OPERATOR WITNESS: S. HEIM D. MORRIS S. HEIM SURFACE LOCATION SECTION: 6 TOWNSHIP: 11N RANGE: 9W FNL: 1302 FSL: FEL: FWL: 1019 ELEVATION (FT FROM MSL 0) KELLY BUSHING: .00 DERRICK FLOOR: 120.58 GROUND LEVEL: .00 WELL CASING RECORD Page 1 zr- NCIU A- 14.tapx OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 1ST STRING 12.250 30.000 447.0 2ND STRING 8.750 9.625 4747.0 3RD STRING PRODUCTION STRING REMARKS: 1. ALL DEPTHS ARE BIT DEPTHS UNLESS OTHERWISE NOTED. THESE DEPTHS ARE MEASURED DEPTH (MD). 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTH (TVD). 3. MWD RUN 1 WAS DIRECTIONAL ONLY - NO DATA PRESENTED. 4. MWD RUN 2 COMPRISED DIRECTIONAL, DUAL GAMMA RAY (DGR) UTILIZING GEIGER - MUELLER TUBE DETECTORS, DRILLSTRING DYNAMICS SENSOR (DDSr), AND ELECTROMAGNETIC WAVE RESISTIVITY PHASE -4 (EWR4). 5. MWD RUN 3 -4 COMPRISED DIRECTIONAL, DUAL GAMMA RAY (DGR) UTILIZING GEIGER - MUELLER TUBE DETECTORS, ELECTROMAGNETIC WAVE RESISTIVITY PHASE -4 (EWR4), DRILLSTRING DYNAMICS SENSOR (DDSr) COMPENSATED THERMAL NEUTRON (CTN), AZIMUTHAL LITHO DENSITY (ALD), AND PRESSURE WHILE DRILLING (PWD). 6. MWD DATA IS DEPTH SHIFTED TO THE PDC GR LOG (USIT) OF 29 -NOV -2008 PROVIDED BY RICHARD ELGARICO OF CONOCOPHILLIPS ALASKA, INC. LOG HEADER AND REMARKS SECTIONS RETAIN ORIGINAL DRILLER'S DEPTH REFERENCE. 7. MWD RUNS 1 -4 REPRESENT NCIU A -14 WITH API #: 50- 883 - 20125 -00. THIS WELL REACHED A TOTAL DEPTH OF 11501 FT MD, 7482 FT TVD. SROP = SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRC = SMOOTHED GAMMA RAY COMBINED. SEXP = SMOOTHED PHASE SHIFT - DERIVED RESISTIVITY (EXTRA SHALLOW SPACING). SESP = SMOOTHED PHASE SHIFT - DERIVED RESISTIVITY (SHALLOW SPACING). SEMP = SMOOTHED PHASE SHIFT - DERIVED RESISTIVITY (MEDIUM SPACING). SEDP = SMOOTHED PHASE SHIFT - DERIVED RESISTIVITY (DEEP SPACING). SFXE = SMOOTHED FORMATION EXPOSURE TIME. TNPS = SMOOTHED THERMAL NEUTRON POROSITY (SANDSTONE MATRIX). CTFA = SMOOTHED AVERAGE OF FAR DETECTOR'S COUNT RATE. CTNA = SMOOTHED AVERAGE OF NEAR DETECTOR'S COUNT RATE. SBD2 = SMOOTHED BULK DENSITY - COMPENSATED (LOW -COUNT RATE BIN). SCO2 = SMOOTHED STANDOFF CORRECTION (LOW -COUNT RATE Page 2 4IP 411 NCIU A- 14.tapx BIN) . SNP2 = SMOOTHED NEAR - DETECTOR -ONLY PHOTOELECTRIC ABSORPTION FACTOR LOW -COUNT RATE BIN). PARAMETERS USED IN POROSITY LOG PROCESSING: HOLE SIZE: CALIPER CORRECTED (8 3/4" NOMINAL) AVG OFFSET: FIXED (.3" NOMINAL) MUD WEIGHT: 9.4 - 9.9 PPG MUD SALINITY: 23,000 - 33,000 PPM CHLORIDES MUD TYPE: WATER BASED FORMATION WATER SALINITY: 345 PPM CHLORIDES FLUID DENSITY: 1.0 G /CC MATRIX DENSITY: 2.65 G /CC LITHOLOGY: SANDSTONE ALL DATA CURVES ARE SMOOTHED TO A STEP OF 0.5 FT, WITH A WINDOW OF 0.6 FT, EXCEPT FOR ROP AND GAMMA RAY. THESE CURVES ARE SMOOTHED WITH A 1.1 FT WINDOW. GAP FILL IS SET TO 5 FT FOR ALL CURVES. File Header Service name STSLIB.001 Service Sub Level Name Version Number 1 0 0 Date of Generation 08/12/09 Maximum Physical Record 65535 File Type LO Previous File Name STSLIB.000 Comment Record FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE START DEPTH STOP DEPTH RPM 2400.0 11440.5 RPD 2400.0 11440.5 GR 2400.0 11448.5 RPS 2400.0 11440.5 RPX 2400.0 11440.5 FET 2400.0 11440.5 ROP 2451.5 11496.5 FCNT 4728.0 11398.5 NCNT 4728.0 11398.5 NPHI 4728.0 11398.5 DRHO 4728.0 11412.0 RHOB 4728.0 11412.0 PEF 4728.0 11412.0 BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) EQUIVALENT UNSHIFTED DEPTH BASELINE DEPTH GR 3334.0 3353.5 3404.0 3425.5 Page 3 4 NCIU A- 14.tapx 3493.0 3507.0 3501.0 3516.5 4036.0 4045.5 4103.0 4112.0 4308.5 4316.5 4360.5 4367.0 4389.5 4397.0 4396.5 4405.0 4410.0 4418.0 4424.5 4432.5 4435.5 4442.0 4442.0 4450.5 4574.0 4581.5 4580.5 4586.5 4654.0 4664.0 4664.5 4673.0 4674.5 4681.5 4712.0 4720.5 4735.0 4744.5 4817.5 4825.0 4949.5 4956.0 4958.5 4966.5 4969.0 4975.5 5027.0 5031.0 5041.0 5044.0 5071.0 5077.0 5075.0 5079.5 5224.0 5230.5 5258.0 5263.5 5443.0 5449.5 5472.0 5479.0 5503.0 5507.5 5662.0 5668.5 5794.0 5800.0 5922.0 5927.0 5991.0 5997.5 6190.5 6198.0 6197.0 6202.5 6262.0 6265.5 6432.0 6435.5 6571.5 6575.5 6662.0 6667.0 6675.5 6679.5 6736.0 6739.5 6814.5 6820.5 6819.0 6824.0 6878.0 6884.0 6883.0 6887.5 6933.5 6937.5 7008.5 7012.0 7027.5 7029.5 7084.5 7086.5 7105.5 7107.5 7116.0 7117.5 7204.0 7207.5 7299.0 7300.5 7311.0 7314.5 7328.0 7330.0 7333.5 7335.0 7527.0 7530.0 7547.0 7549.5 7550.0 7554.0 7605.5 7606.0 Page 4 NCIU A- 14.tapx 7664.0 7666.5 7727.5 7730.0 7793.0 7794.5 7879.5 7883.0 7894.5 7896.5 8040.5 8043.5 8074.5 8076.0 8226.0 8227.0 8303.0 8305.0 8444.0 8448.0 8550.5 8552.0 8574.0 8570.0 8594.0 8597.0 8667.5 8665.0 8695.0 8699.0 8947.5 8948.5 8956.5 8957.5 8959.0 8962.0 8968.5 8973.0 8979.5 8980.5 8984.5 8987.5 9024.0 9026.0 9041.0 9041.5 9058.5 9060.5 9062.5 9063.5 9078.5 9080.5 9094.5 9098.0 9101.5 9101.0 9107.0 9107.5 9110.0 9111.5 9137.5 9140.0 9144.5 9146.0 9150.5 9152.0 9157.5 9161.0 9192.0 9193.5 9201.5 9200.5 9215.0 9216.0 9284.0 9283.5 9288.0 9288.5 9299.0 9297.5 9321.5 9323.5 9348.0 9350.0 9399.0 9396.5 9413.0 9412.0 9446.5 9448.0 9475.0 9474.5 9558.0 9557.0 9571.0 9572.0 9588.5 9589.0 9626.0 9626.5 9671.5 9668.5 9687.0 9687.0 9699.5 9693.0 9718.0 9719.0 9738.5 9738.0 9748.5 9753.0 MERGED DATA SOURCE PBU TOOL CODE BIT RUN NO MERGE TOP MERGE BASE MWD 2 2409.0 4756.0 MWD 3 4756.0 10232.0 MWD 4 10232.0 11501.0 Page 5 • III NCIU A- 14.tapx $ # REMARKS: MERGED MAIN PASS. $ Data Format Specification Record Data Record Type 0 1 Data Specification Block Type 0 Logging in Direction Down Optical log depth units Feet Data Refere p Reference undefined Frame Spacing 60 .AIN Max frames per record undefined Absent value -999 Depth Units Datum Specification Block sub- type...0 Name Service Order Units Size Nsam Rep Code offset channel DEPT FT 4 1 68 0 1 FCNT MWD CP30 4 1 68 4 2 NCNT MWD CP30 4 1 68 8 3 RHOB MWD G /CC 4 1 68 12 4 DRHO MWD G /CC 4 1 68 16 5 RPD MWD OHMM 4 1 68 20 6 RPM MWD OHMM 4 1 68 24 7 RPS MWD OHMM 4 1 68 28 8 RPX MWD OHMM 4 1 68 32 9 FET MWD HR 4 1 68 36 10 GR MWD API 4 1 68 40 11 PEF MWD B/E 4 1 68 44 12 ROP MWD FPH 4 1 68 48 13 NPHI MWD PU 4 1 68 52 14 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 2400 11496.5 6948.25 18194 2400 11496.5 FCNT MWD CP30 388.86 2480.53 987.981 13342 4728 11398.5 NCNT MWD CP30 95677.3 178523 127551 13342 4728 11398.5 RHOB MWD G /CC 0.534 3.491 2.29039 13369 4728 11412 DRHO MWD G /CC -2.226 0.324 0.0536474 13369 4728 11412 RPD MWD OHMM 0.13 2000 18.7163 18000 2400 11440.5 RPM MWD OHMM 0.55 881.31 15.6757 18000 2400 11440.5 RPS MWD OHMM 0.34 264.08 15.1501 18000 2400 11440.5 RPX MWD OHMM 3.02 80.43 12.7651 18000 2400 11440.5 FET MWD HR 0.24 1718.95 5.70914 18000 2400 11440.5 GR MWD API 8.17 110.76 66.602 18098 2400 11448.5 PEF MWD B/E 0.5 12.18 2.45788 13369 4728 11412 ROP MWD FPH 0.05 934.85 116.945 18091 2451.5 11496.5 NPHI MWD PU 12.67 114.52 34.9613 13342 4728 11398.5 First Reading For Entire File 2400 Last Reading For Entire File 11496.5 File Trailer Service name STSLIB.001 Service Sub Level Name version Number 1 0 0 Date of Generation 08/12/09 Maximum Physical Record 65535 Page 6 • NCIU A- 14.tapx File Type LO Next File Name STSLIB.002 Physical EOF File Header Service name STSLIB.002 Service Sub Level Name Version Number 1 0 0 Date of Generation 08/12/09 Maximum Physical Record 65535 File Type LO Previous File Name STSLIB.001 Comment Record FILE HEADER FILE NUMBER: 2 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 2 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH SEDP 2409.0 4694.0 SESP 2409.0 4694.0 SEMP 2409.0 4694.0 SFXE 2409.0 4694.0 SEXP 2409.0 4694.0 SGRC 2418.0 4702.0 SROP 2471.0 4756.0 LOG HEADER DATA DATE LOGGED: 22- AUG -08 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 74.11 DATA TYPE (MEMORY OR REAL - TIME): Memory TD DRILLER (FT): 4756.0 TOP LOG INTERVAL (FT): 2471.0 BOTTOM LOG INTERVAL (FT): 4756.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 52.4 MAXIMUM ANGLE: 59.8 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR Dual Gamma Ray 216261 EWR4 EWR Phase -4 81797 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 12.250 DRILLER'S CASING DEPTH (FT): 447.0 BOREHOLE CONDITIONS MUD TYPE: Native /Spud Mud MUD DENSITY (LB /G): 9.20 MUD VISCOSITY (S): 99.0 Page 7 • NCIU A- 14.tapx MUD PH: 9.2 MUD CHLORIDES (PPM): 380 FLUID LOSS (C3): 8.0 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): 3.100 62.0 MUD AT MAX CIRCULATING TERMPERATURE: 1.751 115.0 MUD FILTRATE AT MT: 3.500 62.0 MUD CAKE AT MT: 3.300 62.0 # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type 0 Data Specification Block Type 0 Logging Direction Down Optical log depth units Feet Data Reference Point Undefined Frame Spacing 60 .11N Max frames per record Undefined Absent value -999 Depth Units Datum Specification Block sub- type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 RPD MWD020 OHMM 4 1 68 4 2 RPM MWD020 OHMM 4 1 68 8 3 RPS MWD020 OHMM 4 1 68 12 4 RPX MWD020 OHMM 4 1 68 16 5 FET MWD020 HR 4 1 68 20 6 GR MWD020 API 4 1 68 24 7 ROP MWD020 FPH 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 2409 4756 3582.5 4695 2409 4756 RPD MWD020 OHMM 6.55 46.82 25.6409 4571 2409 4694 RPM MWD020 OHMM 5.95 45.19 24.6467 4571 2409 4694 RPS MWD020 OHMM 5.53 45.12 24.0913 4571 2409 4694 RPX MWD020 OHMM 5.14 41.42 21.1629 4571 2409 4694 FET MWD020 HR 0.29 23.02 1.55262 4571 2409 4694 GR MWD020 API 21.02 95.58 54.7435 4569 2418 4702 ROP MWD020 FPH 0.9 557.48 174.569 4571 2471 4756 First Reading For Entire File 2409 Last Reading For Entire File 4756 File Trailer Service name STSLIB.002 Service Sub Level Name Page 8 411 NCIU A- 14.tapx Version Number 1 0 0 Date of Generation 08/12/09 Maximum Physical Record 65535 File Type LO Next File Name STSLIB.003 Physical EOF File Header Service name STSLIB.003 Service Sub Level Name Version Number 1 0 0 Date of Generation 08/12/09 Maximum Physical Record 65535 File Type LO Previous File Name STSLIB.002 Comment Record FILE HEADER FILE NUMBER: 3 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 3 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH SGRC 4702.5 10192.0 CTFA 4737.0 10137.0 TNPS 4737.0 10137.0 SFXE 4737.0 10186.5 SEXP 4737.0 10186.5 SESP 4737.0 10186.5 SNP2 4737.0 10151.0 CTNA 4737.0 10137.0 SBD2 4737.0 10151.0 SEMP 4737.0 10186.5 SCO2 4737.0 10151.0 SEDP 4737.0 10186.5 SROP 4756.5 10232.0 LOG HEADER DATA DATE LOGGED: 09- NOV -08 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 74.11 DATA TYPE (MEMORY OR REAL - TIME): Memory TD DRILLER (FT): 10232.0 TOP LOG INTERVAL (FT): 4756.0 BOTTOM LOG INTERVAL (FT): 10232.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 48.9 MAXIMUM ANGLE: 58.6 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR Dual Gamma Ray 253600 EWR4 EWR Phase -4 105242 CTN Comp Thermal Neutron 185457 Page 9 NCIU A- 14.tapx ALD Azimuthal Litho Dens 146830 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 8.750 DRILLER'S CASING DEPTH (FT): 4747.0 BOREHOLE CONDITIONS MUD TYPE: Polymer MUD DENSITY (LB /G): 9.90 MUD VISCOSITY (S): 76.0 MUD PH: 9.9 MUD CHLORIDES (PPM): 29000 FLUID LOSS (C3): 4.0 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): .180 72.0 MUD AT MAX CIRCULATING TERMPERATURE: .108 125.0 MUD FILTRATE AT MT: .160 72.0 MUD CAKE AT MT: .300 72.0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format Specification Record Data Record Type 0 Data Specification Block Type 0 Logging Direction Down optical log depth units Feet Data Reference Point Undefined Frame Spacing 60 .1IN Max frames per record undefined Absent value -999 Depth Units Datum Specification Block sub- type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 FCNT MWD030 CP30 4 1 68 4 2 NCNT MWD030 CP30 4 1 68 8 3 RHOB MWD030 G /CC 4 1 68 12 4 DRHO MWD030 G /CC 4 1 68 16 5 RPD MWD030 OHMM 4 1 68 20 6 RPM MWD030 OHMM 4 1 68 24 7 RPS MWD030 OHMM 4 1 68 28 8 RPX MWD030 OHMM 4 1 68 32 9 FET MWD030 HR 4 1 68 36 10 GR MWD030 API 4 1 68 40 11 PEF MWD030 B/E 4 1 68 44 12 ROP MWD030 FPH 4 1 68 48 13 NPHI MWD030 PU 4 1 68 52 14 First Last Name Service Unit Min Max Mean Nsam Reading Reading Page 10 0 NCIU A- 14.tapx DEPT FT 4702.5 10232 7467.25 11060 4702.5 10232 FCNT MWD030 CP30 388.86 2480.53 957.878 10801 4737 10137 NCNT MWD030 CP30 95677.3 178523 125897 10801 4737 10137 RHOB MWD030 G /CC 0.534 3.491 2.25274 10829 4737 10151 DRHO MWD030 G /CC -2.226 0.324 0.0510279 10829 4737 10151 RPD MWD030 OHMM 0.13 2000 17.2535 10900 4737 10186.5 RPM MWD030 OHMM 0.55 881.31 12.8001 10900 4737 10186.5 RPS MWD030 OHMM 0.34 264.08 12.2538 10900 4737 10186.5 RPX MWD030 OHMM 3.02 80.43 9.98725 10900 4737 10186.5 FET MWD030 HR 0.24 1718.95 7.99449 10900 4737 10186.5 GR MWD030 API 8.17 108.41 67.824 10980 4702.5 10192 PEF MWD030 B/E 0.5 12.18 2.34589 10829 4737 10151 ROP MWD030 FPH 0.05 934.85 103.484 10952 4756.5 10232 NPHI MWD030 Pu 12.67 114.52 36.0733 10801 4737 10137 First Reading For Entire File 4702.5 Last Reading For Entire File 10232 File Trailer Service name STSLIB.003 Service Sub Level Name Version Number 1 0 0 Date of Generation 08/12/09 Maximum Physical Record 65535 File Type LO Next File Name STSLIB.004 Physical EOF File Header Service name STSLIB.004 Service Sub Level Name Version Number 1 0 0 Date of Generation 08/12/09 Maximum Physical Record 65535 File Type LO Previous File Name STSLIB.003 Comment Record FILE HEADER FILE NUMBER: 4 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 4 DEPTH INCREMENT: .5000 # FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH CTNA 10137.5 11403.0 TNPS 10137.5 11403.0 CTFA 10137.5 11403.0 5CO2 10151.5 11416.5 SNP2 10151.5 11416.5 SBD2 10151.5 11416.5 SEMP 10187.0 11445.0 SEXP 10187.0 11445.0 SEDP 10187.0 11445.0 SFXE 10187.0 11445.0 SESP 10187.0 11445.0 Page 11 4 NCIU A- 14.tapx SGRC 10192.5 11453.0 SROP 10232.5 11501.0 LOG HEADER DATA DATE LOGGED: 13- NOV -08 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 74.11 DATA TYPE (MEMORY OR REAL - TIME): Memory TD DRILLER (FT): 11501.0 TOP LOG INTERVAL (FT): 10232.0 BOTTOM LOG INTERVAL (FT): 11501.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 44.5 MAXIMUM ANGLE: 52.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR Dual Gamma Ray 253600 EWR4 EWR Phase -4 145654 CTN Comp Thermal Neutron 179954 ALD Azimuthal Litho Dens 10603721 $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 8.750 DRILLER'S CASING DEPTH (FT): 4747.0 BOREHOLE CONDITIONS MUD TYPE: Polymer MUD DENSITY (LB /G): 9.90 MUD VISCOSITY (S): 62.0 MUD PH: 9.9 MUD CHLORIDES (PPM): 33000 FLUID LOSS (C3): 14.0 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): .160 76.0 MUD AT MAX CIRCULATING TERMPERATURE: .095 132.0 MUD FILTRATE AT MT: .200 76.0 MUD CAKE AT MT: .360 76.0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format Specification Record Data Record Type 0 Data Specification Block Type 0 Logging Direction Down Optical log depth units Feet Data Reference Point undefined Frame Spacing 60 .11N Max frames per record undefined Absent value -999 Page 12 NCIU A- 14.tapx Depth Units Datum Specification Block sub- type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 FCNT MWD040 CP30 4 1 68 4 2 NCNT MWD040 CP30 4 1 68 8 3 RHOB MWD040 G /CC 4 1 68 12 4 DRHO MWD040 G /CC 4 1 68 16 5 RPD MWD040 OHMM 4 1 68 20 6 RPM MWD040 OHMM 4 1 68 24 7 RPS MWD040 OHMM 4 1 68 28 8 RPX MWD040 OHMM 4 1 68 32 9 FET MWD040 HR 4 1 68 36 10 GR MWD040 API 4 1 68 40 11 PEF MWD040 B/E 4 1 68 44 12 ROP MWD040 FPH 4 1 68 48 13 NPHI MWD040 PU 4 1 68 52 14 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 10137.5 11501 10819.3 2728 10137.5 11501 FCNT MWD040 CP30 533.75 2350.94 1120.15 2532 10137.5 11403 NCNT MWD040 CP30 104689 168001 134784 2532 10137.5 11403 RHOB MWD040 G /CC 1.553 2.747 2.4564 2531 10151.5 11416.5 DRHO MWD040 G /CC -0.063 0.324 0.0648028 2531 10151.5 11416.5 RPD MWD040 OHMM 7.3 44.25 13.1506 2517 10187 11445 RPM MWD040 OHMM 6.21 43.1 11.7186 2517 10187 11445 RPS MWD040 OHMM 5.58 40.68 11.3435 2517 10187 11445 RPX MWD040 OHMM 4.68 33.69 9.45857 2517 10187 11445 FET MWD040 HR 0.57 43.32 3.54422 2517 10187 11445 GR MWD040 API 54.71 110.76 83.2006 2522 10192.5 11453 PEF MWD040 B/E 1.06 5.25 2.95178 2531 10151.5 11416.5 ROP MWD040 FPH 0.28 228.84 70.2692 2538 10232.5 11501 NPHI MWD040 PU 14.03 66.65 29.9546 2532 10137.5 11403 First Reading For Entire File 10137.5 Last Reading For Entire File 11501 File Trailer Service name STSLIB.004 Service Sub Level Name Version Number 1 0 0 Date of Generation 08/12/09 Maximum Physical Record 65535 File Type LO Next File Name STSLIB.005 Physical EOF Tape Trailer Service name LISTPE Date 08/12/09 Origin STS Tape Name UNKNOWN Continuation Number 01 Next Tape Name UNKNOWN Page 13 S • NCIU A- 14.tapx Comments STS LIS Writing Library. scientific Technical Services Reel Trailer Service name LISTPE Date 08/12/09 Origin STS Reel Name UNKNOWN Continuation Number 01 Next Reel Name UNKNOWN Comments STS LIS Writing Library. Scientific Technical Services Physical EOF Physical EOF End Of LIS File Page 14 • onocoPh Alaska, Inc. FINAL WELL REPORT MUDLOGGING DATA NCIU A -14 • Provided by: Ell EPOCH Approved by: Rick A. Levinson Compiled by: Steven Pike John Lundy Dan Grunwald Date: 11/13/2008 Distribution:1 /26/09 ID ConocoPhillips 110 Alaska, Inc. NCIU A-14 TABLE OF CONTENTS 1 MUDLOGGING EQUIPMENT & CREW 2 1.1 Equipment Summary 2 1.2 Crew 2 2 WELL DETAILS 3 2.1 Well Summary 3 2.2 Hole Data 3 2.3 Daily Activity 4 3 GEOLOGICAL DATA 5 3.1 Lithostratigraphy 5 3.2 Mudlog Summary 7 3.3 Connection Gases 25 3.4 Trip (Wiper) Gases 25 3.5 Sampling Program / Sample Dispatch 26 4 PRESSURE / FORMATION STRENGTH DATA 27 4.1 Pore Pressure Discussion 27 4.2 Quantitative Methods 27 5 DRILLING DATA 28 5.1 Survey Data 28 5.2 Bit Record 32 5.3 Mud Record 32 6 MORNING REPORTS 34 Enclosures • 2 "/100' Formation Log (MD) 2 "/100' Drilling Dynamics Log 2 "/100' LWD / Lithology Log • El EPOCH 1 Conoc Phillips • Alaska, Inc. NCIU A -14 1 MUDLOGGING EQUIPMENT & CREW 1.1 Equipment Summary Parameter Equipment Type / Position Total Comments Downtime QGM Agitator (Mounted in possum belly) Ditch Flame ionization total gas & 0 g as chromatography. Effective Circulating Density From Sperry-Sun 4757' to 11501' 0 (ECD) Hook Load / Weight on bit Pason Sensors 0 Mud Flow In Pason Sensors 0 Mud Flow Out Pason Sensors 0 Mudlogging unit computer HP Compaq Pentium 4 (X2, DML & 0 system Rigwatch) Mudlo in unit DAC box In -unit data collection /distribution 0 gg g center Pit Volumes, Pit Gain /Loss Pason Sensors 0 Pump Pressure Pason Sensors 0 Pump stroke counters Pason Sensors 0 Pason Well Monitoring Pason Sensors 0 Components Rate of penetration Pason Sensors 0 • RPM Pason Sensors 0 Torque Pason Sensors 0 1.2 Crew • Unit Type Unit Number : ML030 Day Mudloggers Years s Sample Catchers Year Days Technician Days *2 S Steven Pike 5 17+ Jeff McBeth 0 14 John Lundy 18 4 John Datz 0 3 Dan Grunwald 14+ Justin Vanderburg 0 11 *1 Years experience as Mudlogger *2 Days at wellsite between spud and total depth of well EPOCH 2 ConocoPhillips Alaska, Inc NCIU A -14 • 2 WELL DETAILS 2.1 Well Summary Well: NCIU A -14 API Index #: 50- 883 - 20125 -00 Field: North Cook Inlet Surface Co- Ordinates: Lat 61:04:33.87:87 Long 150:57:02:780 Borough: Kenai Peninsula Primary Target Depth: 6742' State: Alaska TD Depth: 11501' Rig Name / Type: Kuukpik #5, Arctic Double Suspension Date: Primary Target: Beluga Sands License: Spud Date: 10/31/2008 Ground Elevation: NA Completion Date: First quarter 2009 KB Elevation: 120.58' Completion Status: Cased and cemented at Secondary Target: NONE report time Depth: Classification: TD Date: 11/13/2008 TD Formation: Beluga Fm. Days Testing: NONE Days Drilling: 14 2.2 Hole Data Maximum Depth TD Mud Dev. Casin Shoe Depth LOT Section MD TVDSS Formation Weight (Inc) Coring g/ MD TVDSS (ppg (ft) (ft) (ppg) Liner (ft) (ft) ) 8.75" 11501' -7482' NA 9.9 46.9 NA 7" Additional Comments • El EPOCH 3 Conoc Phillips Alaska, Inc. NCIU A -14 2.3 Daily Activity 10/31//2008 Arrive at the rig and begin rigging up Epoch unit, changed out tubing spool, NU and test BOP. 11/1/2008 Continue to test BOPs. 11/2/2008 Test BOPs. Pick up /make up BHA and run into hole. Test casing integrity to 3000psi. Drill out floats and shoe track and 20' new hole. Insufficient new rock fragments in sample to indicate good formation contact. Drill additional 20' new hole to 1796'. Circulate and conditions mud /displace cement contaminated mud with 9.2ppg KlaShield mud. Perform LOT to 16.6ppg EMW. 11/3/2008 Drill /directional drill from 4799' to 6088'. 11/4/2008 Drill ahead to 6741'. Circulate well for safety meeting. Drill ahead to 6930'. Circulate out high gas and condition mud. Drill ahead to 7055'. Circulate out high gas and condition mud. Drill ahead to 7251'. Circulate and work on top drive. Drill to 8284' at midnight. 11/5/2008 Drill ahead to 7885. Commence short trip to the shoe. 11/6/2008 POOH. Cut and slip drilling line, repair top drive. Trip into hole, drill ahead to 7980. 11/7/2008 Drill ahead to 8963. 11/8/2008 Drill ahead to 9217, POOH. • 11/9/2008 Drill ahead to 9780. 11/10/2008 Drilled ahead to 10232; tripping out of hole to service MWD tool. 11/11/2008 Switch out MWD tooling and service rig; begin tripping into hole. 11/12/2008 TIH to shoe; slip and cut drill line; TIH to bottom; drill ahead to 10641. 11/13/2008 Pump sweep @10806'; drill ahead to 11346'. 11/14/2008 Drill ahead to 11380; service pump #1; continue drilling ahead with pump #2 only; revise TD and end drilling @ 11501'; back ream while pulling out. 11/15/2008 Test BOPs, and service rig. 11/16/2008 Continue BOP test; slip and cut drill line; attempt wireline run, stall at —5700'; POOH and run wireline tools on drill pipe. • I EPOCH 4 Conoco Phillips Alaska, Inc. • NCIU A -14 3 GEOLOGICAL DATA 3.1 Lithostratigraphv All tops provided by the ConocoPhillips Alaska, Inc. (CPAI) well site geologist. FORMATION PROGNOSED LWD TOP MD SSTVD MD SSTVD (ft) (ft) (ft) (ft) 9 5/8" Csg. 4747' C.I. A 5104' C.I. B 5164' C.I. 1 5507' C.I. 2 5678' C.I. 3 5808' • C.I.4 5938' C.I. 5 6006' C.I. 6 6132' C.I. 7 6204' C.I. 8 6392' C.I. 9 6514' C.I. 10 6584' C.I. 11 6682' BELG -A 6742' BELG -B 6890' BELG -C 7211' BELG -D 7495' BELG -E 7711' BELG -F 7903' BELG -G 8066' BELG -H 8347' pi EPOCH 5 Conoc Phillips Alaska. Inc. • NCIU A -14 BELG-I 8598' BELG-J 8740' BELG-K 8799' BELG-L 8900' BELG-M 8938' BELG-N 9097' BELL -O 9236' BELG-P 9309' BELG -Q 9481' BELG -R 9687' BELG -S 9869' BELG -T 10130' BELG -U 10538' BELG -U base 11120' TD 11501' it El EPOCH 6 ConocoPPhillips Alaska, Inc. NCIU A -14 3.2 Mudloq Summary C.I. A Group (5104' to 5164' MD) Drill Rate (ft/hr) Total Gas (units Maximum Minimum Average Maximum Minimum Average 194 104 149 841 67 405 This interval from around 5,104 feet measured depth (MD) to about 5,164 feet MD and consists of alternating sequences of sand tuffaceous sand and tuffaceous siltstone. The tuffaceous sandstones in this formation are comprised of medium gray to light gray with slight moderate bluish green hues; predominantly poorly sorted becoming moderately to well sorted with depth; sub round to sub angular; poor to moderate sphericity; poorly to moderately consolidated; very common white tuffaceous matrix throughout; matrix supported; 50% translucent quartz; 50% multicolored volcanic clasts and carbonaceous fragments; soft to easily friable; no visible sample fluorescence was observed; no solvent cut. The sand in this section are made up of gray to medium gray with bluish green hues; upper very fine to upper fine with some lower medium; moderate to lower sphericity; subangular to subrounded with some very angular to very rounded in places; poorly consolidated; medium gray tuffaceous matrix present; dominantly grain supported; 75% vitreous to translucent to somewhat smokey quartz; 25% blue green lithics, with abundant dark colored lithic fragments; no visible sample fluorescence; no solvent cut. Peaks • Depth TG C1 C2 C3 C41 C4N C51 C5N 5143 841 164362 NA NA NA NA NA NA C.I. B Group (5164' to 5507' MD) Drill Rate (ft/hr) Total Gas (units Maximum Minimum Average Maximum Minimum Average 223 13 118 381 17 92 This interval is from around 5,164 feet MD to about 5,507 feet MD and consists of alternating sequences of tuffaceous siltstone, tuffaceous claystone, sand and very thin beds of coal dispersed throughout. The tuffaceous claystone /tuffaceous siltstone is comprised of light gray to medium gray; slightly firm to moderately hard; moderately to very indurated; very brittle to crunchy; sub blocky cuttings habit; irregular fracture; interbedded with grayish brown hard clay; smooth to clayey texture; dull earthy luster; lumpy consistency in areas; tough to very dense tenacity; silt to very fine lower quartz interbedded locally; no fluorescence present. The sand /tuffaceous sandstone is made up of medium gray to light gray with slight moderate bluish green hues; predominantly poorly sorted becoming moderately to well sorted with depth; sub round to sub angular; poor to moderate sphericity; poorly to moderately consolidated; very common white tuffaceous matrix throughout; matrix supported; 50% translucent quartz; 50% multicolored volcanic clasts and carbonaceous fragments; soft to easily friable; no visible sample fluorescence was observed; no solvent cut. 411 U q EPOCH 7 ConocoPPhillips Alaska, Inc. NCIU A -14 • The coal section is black; dense to brittle tenacity; blocky to platy to irregular cuttings habit; planar to irregular fracture; earthy luster to occasionally sub vitreous luster; smooth texture; massively bedded; common visible out gassing present. Peaks Depth TG C1 C2 C3 C41 C4N C5I C5N 5215 381 47609 NA NA NA NA NA NA C.I. 1 Group (5507' to 5678' MD) Drill Rate (ft/hr) Total Gas (units Maximum Minimum Average Maximum Minimum Average 215 11 150 244 23 67 This interval from around 5,507 feet MD to about 5,678 feet MD and consists of alternating sequences of tuffaceous claystone /tuffaceous siltstone, tuffaceous sandstone with very thin beds of coal dispersed throughout. The sand in this section is composed of gray to medium gray with bluish green hues; upper very fine to upper fine with some lower medium; moderate to lower sphericity; subangular to subrounded with some very angular to very rounded in places; poorly consolidated; medium gray tuffaceous matrix present; dominantly grain supported; 75% vitreous to translucent to somewhat smokey quartz; 25% blue green lithics, with abundant dark colored lithic fragments; no visible sample fluorescence; no solvent cut. The average siltstone in this group is comprised of medium gray to dark gray with some brownish gray hues; very slimy to pasty; crunchy to somewhat crumbly; irregular fracture; amorphous cuttings habit; very earthy to slightly dull luster; silty texture with some slightly gritty in places; thinly interbedded with thick lenses of sand and thin beds of tuffaceous siltstone and tuffaceous claystone and claystone; no visible sample fluorescence was observed; no solvent cut. Peaks Depth TG C1 C2 C3 C41 C4N C51 C5N 5516 244 47631 NA NA NA NA NA NA C.I. 2 Group (5678' to 5808' MD) Drill Rate (ft/hr) Total Gas (units) Maximum Minimum Average Maximum Minimum Average 221 10 161 988 2 124 This interval from around 5,678 feet MD to about 5,808 feet MD and consists of alternating sequences of sand, claystone and siltstone with lesser amounts of tuffaceous siltstone and conglomerate sand. The average sand in this section is composed of translucent to clear with some light gray to white; predominantly quartz grain sand with abundant dark colored lithic fragments; upper very fine to upper fine grain; moderately well sorted throughout; very well rounded to subrounded with some slightly angular to subangular; moderate to high sphericity; abundant volcanic lithics; 30 % -40% multicolored lithics dominated by light bluish green, grayish green, moderate yellow green, and very pale green; no visible sample fluorescence; no solvent cut. • El EPOCH 8 Conoco`Phillips Alaska, Inc. NCIU A -14 0 The tuffaceous siltstone in this formation is comprised of medium gray to light gray to medium dark gray with some brownish hues; crunchy to slightly crumbly; irregular fracture; easily friable to friable; dull to commonly earthy luster; silty to slight gritty texture; interbedded with thin laminae of carbonaceous material and tuffaceous siltstone throughout with thick beds of sand with intermittent beds of siltstone and claystone; no visible sample fluorescence; no solvent cut. Peaks Depth TG C1 C2 C3 C41 C4N C51 C5N 5695 988 65743 17 NA NA NA NA NA C.I. 3 Group (5808' to 5938' MD) Drill Rate (ft/hr) Total Gas (units Maximum Minimum Average Maximum Minimum Average 236 12 135 443 31 128 This interval from around 5,808 feet MD to about 5,938 feet MD and consists of increasing sand content, claystone and silt, with lesser amounts of tuffaceous siltstone and tuffaceous claystone with some minor amounts of coal seams. The coal seams in this formation consist of black with slight brownish hues present; stiff to very firm; blocky to planar fracture; massive to tabular; resinous to slightly greasy; predominantly smooth texture; moderate outgassing present; no visible sample fluorescence was observed; no solvent cut. The average siltstone in this section is comprised of medium light gray to light gray with some very light gray le and grayish brown hues; mushy to pasty; crunchy to crumbly; irregular to slightly blocky fracture; amorphous cuttings habit; earthy to dull luster; very silty to slightly gritty texture; very thin interbedded with thick beds of sand and tuffaceous siltstone and tuffaceous claystone and with some claystone; no visible sample fluorescence; no solvent cut. Peaks Depth TG C1 C2 C3 C41 C4N C51 C5N 5818 443 52582 11 NA NA NA NA NA C.I. 4 Group (5938' to 6006' MD) Drill Rate (ft/hr) Total Gas (units Maximum Minimum Average Maximum Minimum Average 230 10 133 738 52 218 This interval from around 5,938 feet MD to about 6,006 feet MD and consists of an increase in tuffaceous siltstone with a decrease in sand, siltstone and coal. The tuffaceous siltstone in this section is composed of medium gray to medium dark gray with light gray with greenish blue hues; crumbly to very slightly crunchy; irregular fracture; easily friable to friable; dull to commonly earthy luster; silty to gritty texture; interbedded with thin laminae of carbonaceous material and tuffaceous silts with some siltstone and claystone; no visible sample fluorescence was observed; no solvent cut. Peaks Depth TG C1 C2 C3 C4I C4N C51 C5N 5950 738 110268 _ 50 NA NA NA NA NA • El EPOCH 9 ConocoPhillips Alaska, Inc. NCIU A -14 1110 C.I. 5 Group (6006' to 6132' MD) Drill Rate ( ft/hr) T otal Gas (units Maximum Minimum Average Maximum Minimum Average 212 35 142 347 35 148 This interval from around 6,006 feet MD to about 6,132 feet MD and consists of decreasing amounts of tuffaceous claystone /tuffaceous siltstone and an increasing amounts of sand, coal with siltstone and claystone. The tuffaceous siltstone in this formation consists of medium gray to light gray with some grayish brown to brownish gray hues; friable; poor to moderate induration; dense to crunchy tenacity; sub tabular to irregular cuttings habit; dull earthy luster; non adhesive and cohesive; stiff consistency; thin bedding structure with silt lenses throughout; PDC bit marks present; trace carbonaceous material black to brownish red in sample; no sample fluorescence was observed; no solvent cut. The coal is composed of black to greenish black with blackish red and very dusky red hues; irregular to birds eye cuttings habit; earthy to sub vitreous luster; dominantly moderately hard to firmly friable; sub mature to mature; very common outgassing visible. Peaks Depth TG C1 C2 C3 C41 C4N C5I C5N 6091 347 64700 11 NA NA NA NA NA C.I. 6 Group (6132' to 6204' MD) Drill Rate (ft/hr) Total Gas (units Maximum Minimum Average Maximum Minimum Average 272 23 161 353 46 172 This interval from around 6,132 feet MD to about 6,204 feet MD and consists of tuffaceous sandstone, tuffaceous siltstone and tuffaceous claystone. The tuffaceous siltstone and claystone in this section is comprised of medium gray with a slight brownish secondary hue to medium and dark gray brown; firm to very firm; angular irregular to tabular to slightly rounded /eroded cuttings habit; silty to sandy /gritty texture; dull earthy luster with a slight to marked micro - sparkly appearance due to very fine volcanic and mica inclusions; trace to locally common fine to micro fine carbonaceous lamina; trace micro fine carbonaceous sediment inclusions; locally very ashy; common medium lower size ash bleb inclusions; interbedded with and grading to medium lower to fine upper grain tuffaceous sandstone; slightly cohesive /adhesive; expansive /hydrophilic; easily lost in sample preparation; non calcareous. Peaks Depth TG Cl C2 C3 C41 C4N C51 C5N 6174 353 44789 9 NA NA NA NA NA El EPOCH 10 ConocoPhillips Alaska, Inc. NCIU A -14 C.I. 7 Group (6204' to 6392' MD) Drill Rate (ft/hr) Total Gas (units) Maximum Minimum Average Maximum Minimum Average 254 35 169 416 63 221 This interval from around 6,204 feet MD to about 6,392 feet MD and consists of an increased in tuffaceous claystone and coal, with sand, tuffaceous siltstone, and lesser amounts of siltstone and claystone. The coal in this interval consists of black to very dark gray; hard to very firm; brittle; poorly fissile /shaly in part; angular platy to tabular to angular irregular fragments; hackly in the cleaner coal; dark gray fragments very silty; grades to crumbly carbonaceous material; trace fine white ash residue on some fracture and bedding surfaces; common visible slow outgassing when fresh continued for 30 min; common thin sandy to silty interbeds. The tuffaceous siltstone /claystone in this formation is composed of medium to light gray with a slight to pronounced brownish secondary hue grading to medium light gray non tuffaceous siltstone with a slight bluish secondary hue; slightly cohesive/ adhesive; hydrophilic; expansive; easily washes away in sample preparation; trace micro thin carbonaceous lamina and very fine carbonaceous inclusions; interbedded with thin to moderate beds of fine upper to medium upper sand; sands are primarily milky to smokey quartz /volcanics with common medium to dark gray and black mafic mineral/ lithic grains; orange -red chert/volcanics becoming abundant; trace bluish and green fragments; trace phlogopite mica; non calcareous. Peaks Depth TG C1 C2 C3 C41 C4N C51 C5N • 6343 416 65051 13 NA NA NA NA NA C.I. 8 Group (6392' to 6514' MD) Drill Rate (ft/hr) Total Gas (units Maximum Minimum Average Maximum Minimum Average 206 31 111 219 49 104 This interval from around 6,392 feet MD to about 6,514 feet MD and consists of increasing coal and carbonaceous shale, with lesser amounts of sand, interbedded with tuffaceous siltstone and tuffaceous claystone. The coals in this section consists of black to greenish black with blackish red and very dusky red hues; irregular to birds eye cuttings habit; earthy to sub vitreous luster; dominantly moderately hard to firmly friable; sub mature to mature; very common out gassing visible. Peaks Depth TG C1 C2 C3 C41 C4N C51 C5N 6465 219 25118 5 NA NA NA NA NA C.I. 9 Group (6514' to 6584' MD) Drill Rate (ft/hr) Total Gas (units Maximum Minimum Average Maximum Minimum Average 168 54 127 329 1 119 • EPOCH 11 Conoc Phillips Alaska Inc NCIU A -14 This interval from around 6,514 feet MD to about 6,584 feet MD and consists of increasing amounts of coal and carbonaceous shale, with tuffaceous siltstone and lesser amounts of sand. The coals in this formation are composed of black to very dark gray; hard to very firm; brittle; poorly fissile /shaly in part; angular platy to tabular to angular irregular fragments; hackly in the cleaner coal; dark gray fragments very silty; grades to crumbly carbonaceous material; trace fine white ash residue on some fracture and bedding surfaces; common visible slow out gassing when fresh continued for 30 min; common thin sandy to silty interbeds. The tuffaceous siltstone /claystone in this section are comprised of medium to light gray with a slight to pronounced brownish secondary hue grading to medium light gray non tuffaceous siltstone with a slight bluish secondary hue; slightly cohesive/ adhesive; hydrophilic; expansive; easily washes away in sample preparation; trace micro thin carbonaceous lamina and very fine carbonaceous inclusions; interbedded with thin to moderate beds of fine upper to medium upper sand; sands are primarily milky to smokey quartz /volcanics with common medium to dark gray and black mafic mineral/ lithic grains; orange -red chert/volcanics becoming abundant; trace bluish and green fragments; trace phlogopite mica; non calcareous. Peaks Depth TG C1 C2 C3 C41 C4N C51 C5N 6547 329 64638 NA NA NA NA NA NA C.I. 10 Group (6584' to 6682' MD) Drill Rate (ft/hr) Total Gas (units Maximum Minimum Average Maximum Minimum Average 411 229 60 135 272 28 123 This interval from around 6,584 feet MD to about 6,682 feet MD and consists of an increase in tuffaceous siltstone and claystone with sand and siltstone, and a decrease in coal and carbonaceous shale. The tuffaceous siltstone in this section consists of medium gray to light gray with some grayish brown to brownish gray hues; friable; poor to moderate induration; dense to crunchy tenacity; sub tabular to irregular cuttings habit; dull earthy luster; non adhesive and cohesive; stiff consistency; thin bedding structure with silt lenses throughout; PDC bit marks present; trace carbonaceous material black to brownish red in sample; no sample fluorescence was observed; no solvent cut. Peaks Depth TG C1 C2 C3 C41 C4N C51 C5N 6677 277 51902 NA NA NA NA NA NA C.I. 11 Group (6682' to 6742' MD) Drill Rate (ft/hr) Total Gas (units Maximum Minimum Average Maximum Minimum Average 266 78 145 182 74 123 This interval from around 6,682 feet measured depth (MD) to about 6,742 feet MD and consists of an increase of tuffaceous claystone and claystone interbedded with tuffaceous siltstone, sand and siltstone with minor amounts of coal. The tuffaceous siltstone /claystone in this formation consists of medium gray with a slight brownish secondary p Li EPOCH 12 Conc Phillips Alaska, Inc. NCIU A -14 hue to medium and dark gray brown; firm to very firm; angular irregular to tabular to slightly rounded /eroded cuttings habit; silty to sandy /gritty texture; dull earthy luster with a slight to marked micro - sparkly appearance due to very fine volcanic and mica inclusions; trace to locally common fine to micro fine carbonaceous lamina; trace micro fine carbonaceous sediment inclusions; locally very ashy; common medium lower size ash bleb inclusions; interbedded with and grading to medium lower to fine upper grain tuffaceous sandstone; slightly cohesive /adhesive; expansive /hydrophilic; easily lost in sample preparation; non calcareous. Peaks Depth TG C1 C2 C3 C41 C4N C51 C5N 6738 182 34193 NA NA NA NA NA NA Beluga A Group (6742' to 6890' MD) Drill Rate ( ft/hr) Total Gas (units) Maximum Minimum Average Maximum Minimum Average 357 14 113 194 23 104 This interval from around 6,742 feet MD to about 6,890 feet MD and consists of tuffaceous siltstone with some claystone and tuffaceous claystone, with very little sand and coal. The tuffaceous siltstone /claystone in this formation consists of medium gray with a slight brownish secondary hue to medium and dark gray brown; firm to very firm; angular irregular to tabular to slightly rounded /eroded cuttings habit; silty to sandy /gritty texture; dull earthy luster with a slight to marked micro - sparkly appearance due to very fine volcanic and mica inclusions; trace to locally common fine to micro fine carbonaceous lamina; trace micro fine carbonaceous sediment inclusions; locally very ashy; common medium lower size ash bleb O inclusions; interbedded with and grading to medium lower to fine upper grain tuffaceous sandstone; slightly cohesive /adhesive; expansive /hydrophilic; easily lost in sample preparation; non calcareous. Peaks Depth TG C1 C2 C3 C41 C4N C51 C5N 6830 194 38306 NA NA NA NA NA NA Beluga B Group (6890' to 7211' MD) Drill Rate (ft/hr) Total Gas (units Maximum Minimum Average Maximum Minimum Average 210 29 101 1236 38 280 This interval from around 6,890 feet MD to about 7,211 feet MD and consist mainly of tuffaceous siltstone and tuffaceous claystone with a significant increase in sand, tuffaceous sand, and coal. The sandstone /tuffaceous sandstone in this formation is comprised of medium gray brown to light and medium gray; soft to unconsolidated /disconsolidated; medium lower to fine upper grain; locally fine lower grain; moderately rounded to sub - rounded; clear to translucent white quartz/ volcanics; common medium gray to black lithic /mafic mineral grains only where loose sand is present in the sample; generally matrix supported with occasional slight grain support indicated; matrix is primarily a light to medium gray ash; no oil indicators; non calcareous. The average tuffaceous siltstone /claystone in this section is made up of medium to medium light gray with a distinct brownish secondary hue; firm to soft to very firm; irregular to sub tabular cuttings habit; silty to sandy texture; dull earthy luster with trace microsparkly appearance due to microfine volcanic and mica inclusions; generally very ashy with locally abundant fine lower to medium lower light yellowish gray ash blebs; occasional El EPOCH 13 Conoco Phillips Alaska. Inc. NCIU A -14 very thin sandy intervals grade to adjacent silty sands; interbedded with moderate to thin beds of ash supported light gray to brownish gray fine upper grain tuffaceous sandstone and occasional medium lower to coarse lower grain supported sands and occasional thin to moderate coals; trace micro thin carbonaceous lamina; trace to common heavily carbonaceous siltstone beds; non calcareous. Peaks Depth TG C1 C2 C3 C41 C4N C51 C5N 7040 1236 139545 43 NA NA NA NA NA 7104 914 68290 42 NA NA NA NA NA Beluga C Group (7211' to 7495' MD) Drill Rate (ft/hr) Total Gas (units Maximum Minimum Average Maximum Minimum Average 167 18 65 171 10 67 This interval from around 7,211 feet MD to about 7,495 feet MD and consist mainly of tuffaceous siltstone, with sand and tuffaceous sand decreasing with depth. The tuffaceous siltstone in this formation consists of dark gray to medium gray with some brownish gray and brownish black hues; very pasty to slightly mushy; brittle to crumbly tenacity; irregular fracture; amorphous to slight irregular cuttings habit; very earthy to somewhat dull luster; mostly silty to slightly ashy to gritty texture; massive interbedded with thick beds of sand, sandstone and tuffaceous sandstone; no visible sample fluorescence; no solvent cut. Peaks Depth TG C1 C2 C3 C41 C4N C5l C5N 7249 171 22641 10 NA NA NA NA NA Beluga D Group (7495' to 7711' MD) Drill Rate (ft/hr) Total Gas (units Maximum Minimum Average Maximum Minimum Average 160 19 77 96 12 41 This interval from around 7,495 feet MD to about 7,711 feet MD mostly consists of tuffaceous siltstone, with and increase of tuffaceous shale, shale and sand. The tuffaceous claystone in this section is composed of light brown to moderate yellowish brown with some very light gray to light bluish gray; mostly stiff to slightly pasty; predominantly brittle to slightly crumbly in places; mostly irregular to very slightly blocky fracture; irregular to PDC butter curl cuttings habit; very earthy to somewhat greasy luster with some slightly dull; very clayey texture with some slightly silty; very thick bedded laminae interbedded with thick beds of tuffaceous siltstone and lesser amounts of shale and sand. The shale in this formation consists of light gray to medium gray with some grayish brown; very slightly stiff to pasty; brittle to somewhat crunchy; slightly planar fracture in paces with overall irregular fracture habit; amorphous cuttings habit; very dull to somewhat earthy luster; slightly smooth to somewhat very clayey texture; very thick layers of shale interbedded with thick beds of tuffaceous shale, and tuffaceous siltstone and small lenses of sand and immature coal; no visible sample fluorescence was observed; no solvent cut. El EPOCH 14 Conoco Phillips Alaska. Inc. NCIU A -14 Peaks Depth TG C1 C2 C3 C41 C4N C51 C5N 7540 96 18406 NA NA NA NA NA NA Beluga E Group (7711' to 7903' MD) Drill Rate (ft/hr) Total Gas (units Maximum Minimum Average Maximum Minimum Average 138 30 73 244 2 47 This interval from around 7,711 feet MD to about 7,903 feet MD and consists of mostly tuffaceous siltstone, with increasing amounts of tuffaceous shale, shale and coal, while the sand decreases in concentration. The tuffaceous shale in this section is composed of medium gray to brownish gray with brownish yellow hues; slightly stiff to crumbly tenacity; irregular fracture; irregular to sub tabular cuttings habit; very earthy to somewhat dull luster; mostly silty to slightly silty to gritty texture; massive poorly fissile; dull earthy to occasionally microsparkly luster; grades to and interbedded with associated siltstones; occasional thin coals and carbonaceous shale interbeds; non to very slightly calcareous. Peaks Depth TG Cl C2 C3 C4l C4N C51 C5N 7806 244 46481 29 NA NA NA NA NA Beluga F Group (7903' to 8066' MD) Drill Rate (ft/hr) Total Gas (units Maximum Minimum Average Maximum Minimum Average 181 18 73 164 18 40 This group begins at roughly 7,903 feet MD and continues to about 8,066 feet MD. It consists of alternating sequences of tuffaceous siltstone and shale, also partly tuffaceous, along with lesser amounts of tuffaceous claystone, tuffaceous sandstone, sand, and minor coal. The tuffaceous siltstone in this interval consists of medium gray, irregularly shaped amorphous cuttings with irregular fracture surfaces; the cuttings are brittle to crumbly, with an earthy, slightly dull luster; the texture is primarily silty, varying from slightly ashy to slightly gritty; no visible sample fluorescence, and no solvent cut. The shale in this interval is light to medium gray and occurs as brittle to somewhat crunchy amorphous cuttings; slightly planar fractures are apparent in places amidst an overall irregular fracture habit; the cuttings have a very dull to somewhat earthy luster and a smooth to clayey texture; no visible sample fluorescence, and no solvent cut. The tuffaceous shale in this interval is brownish gray to dark yellowish brown and very slightly stiff to lumpy. Cuttings are amorphous and brittle to somewhat crumbly, with mostly irregular fracture surfaces and slightly planar partings. The luster is predominantly very dull to somewhat earthy, and there is a slightly smooth to very clayey texture. The shale is very thinly bedded. The sand in this interval is gray to dark gray, with some colorless grains. Grain size ranges from upper medium- to upper fine- grained, and the sand is moderately to well sorted. Grains are subangular to angular to slightly sub rounded with very high sphericity. The sand consists of 60% clear to translucent quartz with 40% black carbonaceous material and occasional dusky red lithics. Ell EPOCH 15 Conocillips Alaska, Inc. NCIU A -14 0 The coal in this interval is blackish red to black. Cuttings are very dense though somewhat brittle in places. Fracture surfaces are irregular to blocky across platy to somewhat massive cuttings. Outgassing is very common. Peaks Depth TG C1 C2 C3 C41 C4N C51 C5N 8055 164 31742 NA NA NA NA NA NA Beluga G Group (8066' to 8347' MD) Drill Rate (ft/hr) Total Gas (units Maximum Minimum Average Maximum Minimum Average 230 13 85 241 19 59 This group begins at approximately 8,066 feet MD and continues to approximately 8,347 feet MD. It primarily consists of interbedded sand and tuffaceous siltstone, with subordinate tuffaceous shale and minor coal beds. The sand in this interval is translucent to transparent and ranges from colorless to white to light gray; it's a poorly sorted medium- to very fine- grained quartz sand; grains are very angular to subangular and display moderate to high sphericity; some grain surfaces are frosted, while other surfaces are slightly polished. The tuffaceous siltstone in this interval is medium to light gray, and cuttings are soft and amorphous to firm and irregularly shaped; the cuttings have a dull, earthy luster and a silty, somewhat gritty texture; very fine carbonaceous laminae occur throughout the siltstone, oriented along bedding planes. • Peaks Depth TG C1 C2 C3 C41 C4N C51 C5N 8244' 241 46721 NA NA NA NA NA NA Beluga H Group (8347' to 8598' MD) Drill Rate (ft/hr) Total Gas (units Maximum Minimum Average Maximum Minimum Average 229 22 84 71 10 29 This group begins at approximately 8,347 feet MD and continues to approximately 8,598 feet MD. It consists of mostly tuffaceous siltstone grading into tuffaceous shale, and contains lenses of sand, which increase and become lithified with depth. A few conspicuous coals are also present. The tuffaceous siltstone in this interval is medium to light gray, and consists of soft to firm cuttings that are largely amorphous; the texture is silty and slightly gritty, and the contained sand also adds a sporadic sparkle to the otherwise dull, earthy luster; the siltstone also contains pervasive but extremely thin carbonaceous laminae. The tuffaceous shale in this interval is gray to brownish gray, and consists of slightly stiff to crumbly, somewhat tabular cuttings; it has a very earthy, somewhat dull luster; some weak fissile nature is apparent in an otherwise massive structure. 1 Peaks Depth TG C1 C2 C3 C4I C4N C51 C5N 8512' 71 13711 NA NA NA NA NA NA • CI EPOCH 16 ConotoPhillips Alaska, Inc. NCIU A -14 • Beluga I Group (8598' to 8740' MD) Drill Rate (ft/hr) Total Gas (units) Maximum Minimum Average Maximum Minimum Average 224 8 98 131 12 46 This group begins at approximately 8,598 feet MD and continues to approximately 8,740 feet MD. It primarily consists of tuffaceous siltstone, with a heavy amount of sandstone /tuffaceous sandstone at the top which decreases and transitions to sand at the base. Minor amounts of ash tuff and tuffaceous shale are also present. The tuffaceous siltstone in this interval is light to medium gray, with a slight bluish to brownish secondary hue. Cuttings have a soft to firm consistency and a silty to gritty texture underlying a dull earthy luster. Trace micro thin carbonaceous lamina are contained in cuttings. The silt/sand /clay mixture is only slightly cohesive and easily washed away in sample preparation. The clay content makes them slightly adhesive and hydrophilic, and cuttings are expansive when wet. The sand /sandstone /tuffaceous sandstone in this interval is light to very light brownish gray to light gray. Cuttings are firm to unconsolidated, and the sand is moderately to well sorted, though poorly sorted in some pieces. Grains are lower fine- to upper very fine - grained and moderately rounded to subangular. The sand composition primarily consists of clear to translucent white quartz/volcanics. Also present in trace amounts are black mafic minerals, very fine phlogopite mica flakes, and dull orange, red and yellow chert/volcanics. The remainder of the sandstone consists of trace to 10% light to medium gray and brownish gray mottled ash fragments. Tuffaceous material is primarily matrix supported but shows some visible porosity; non tuffaceous sands are generally tight or occur as loose grains. 4111 Peaks Depth TG C1 C2 C3 C41 C4N C51 C5N 8670' 131 25309 NA NA NA NA NA NA Beluga J Group (8740' to 8799' MD) Drill Rate (ft/hr) Total Gas (units) Maximum Minimum Average Maximum Minimum Average 223 40 111 236 2 67 This group begins at approximately 8,740 feet MD and continues to approximately 8,799 feet MD. It consists of tuffaceous siltstone with a considerable amount of sand and some minor tuffaceous shale and ash tuff. The tuffaceous siltstone in this interval is light to medium gray with a slight bluish to brownish secondary hue; soft to firm; silty to gritty /sandy texture; dull earthy luster with a slight micro - sparkly appearance in part; trace micro thin carbonaceous lamina; trace to common micro fine carbonaceous inclusions; slightly adhesive; non to slightly cohesive; hydrophilic; expansive when wet with fresh water; easily washes away in sample preparation; interbedded with moderate beds of fine lower to very fine upper, moderately rounded to subangular clear to translucent white quartz /volcanic sand. Peaks Depth TG C1 C2 C3 C41 C4N C51 C5N 8774' 236 45640 NA NA NA NA NA NA • HI EPOCH 17 ConocoPPhillips Alaska. Inc NCIU A -14 410 Beluga K Group (8799' to 8900' MD) Drill Rate (ft/hr) Total Gas (units Maximum Minimum Average Maximum Minimum Average 239 20 98 444 2 223 This group begins at approximately 8,799 feet MD and continues to approximately 8,900 feet MD. It primarily consists of tuffaceous siltstone, with minor amounts of ash tuff, carbonaceous shale grading into tuffaceous shale, and sand lenses. The tuffaceous siltstone in this interval is medium gray with a slight brownish secondary hue; slightly firm to soft; silty /clayey to gritty texture; dull earthy luster; grades to and interbedded with adjacent tuffaceous sandstone; abundant microscopic carbonaceous lamina; trace to occasionally common fine coal inclusions; expansive on contact with fresh water; hydrophilic; no visible sample fluorescence; no solvent cut. Peaks Depth TG C1 C2 C3 C41 C4N C51 C5N 8831' 444 85976 NA NA NA NA NA NA Beluga L Group (8900' to 8938' MD) Drill Rate (ft/hr) Total Gas (units) Maximum Minimum Average Maximum Minimum Average 276 21 63 127 28 66 This group begins at approximately 8,900 feet MD and continues to approximately 8,938 feet MD. It consists of tuffaceous siltstone interbedded with tuffaceous sandstone. It also contains minor amounts of carbonaceous shale, tuffaceous shale, and ash tuff, as well as a small amount of coal. The tuffaceous siltstone in this interval is medium gray with a slight brownish secondary hue; slightly firm to soft to firm; silty /clayey to gritty texture; dull earthy luster; grades to and interbedded with adjacent tuffaceous sandstone; abundant microfine carbonaceous \lamina; trace to occasionally common fine coal inclusions; expansive on contact with fresh water; hydrophilic; no visible sample fluorescence; no solvent cut. The tuffaceous sandstone in this interval is light grayish brown to light gray with a slight bluish secondary hue; slightly firm to soft; moderately well to well sorted; fine lower to very fine upper; moderately rounded to subrounded; clear to translucent quartz /volcanics predominates with common fine to very fine dark gray to black mafic mineral grains and trace medium gray lithic grains in the fine upper range; slight yellowish hue in some very ashy fragments; generally matrix supported in a mottled gray white to brownish and yellow ash; trace visible porosity in the tuffaceous material; none in non tuffaceous sand interbeds; trace medium tuffaceous shale; trace carbonaceous shale and partially devitrified ash flakes; no stain, odor, fluorescence or cut. Peaks Depth TG C1 C2 C3 C41 C4N C51 C5N 8900' 127 24558 NA NA NA NA NA NA Beluga M Group (8938' to 9097' MD) • El EPOCH 18 Conoc Phillips Alaska. Inc. NCIU A -14 • Drill Rate (ft/hr) Total Gas (units Maximum Minimum Average Maximum Minimum Average 264 8 85 248 3 70 This group begins at approximately 8,938 feet MD to approximately 9,097 feet MD. It consists of tuffaceous siltstone grading into tuffaceous sandstone, which decreases with depth, and tuffaceous claystone, which increases with depth. Minor amounts of tuffaceous shale and lenses of sand are also interbedded, along with a small amount of coal in the upper sandy section. The tuffaceous siltstone in this interval is medium gray with a slight brownish secondary hue; slightly firm to soft to firm; silty /clayey to gritty texture; dull earthy luster; grades to and interbedded with adjacent tuffaceous sandstone; abundant microfine carbonaceous \lamina; trace to occasionally common fine coal inclusions; expansive on contact with fresh water; hydrophilic; no visible sample fluorescence; no solvent cut. The tuffaceous sandstone in this interval is medium gray with a slight brownish secondary hue; slightly firm to soft to firm; silty /clayey to gritty texture; dull earthy luster; grades to and interbedded with adjacent tuffaceous sandstone; abundant microfine carbonaceous \lamina; trace to occasionally common fine coal inclusions; expansive on contact with fresh water; hydrophilic; no visible sample fluorescence; no solvent cut. The tuffaceous shale in this interval is grayish brown to light brown with some medium gray with some brownish gray; very slightly stiff to pasty; brittle to somewhat crunchy; slightly planar fracture in paces with overall irregular fracture; amorphous cuttings habit; very earthy to somewhat dull luster; slightly clayey to somewhat very dull texture; very thin layers of shale interbedded with thick beds of tuffaceous claystone and tuffaceous siltstone and small lenses of sand and tuffaceous sand; no visible sample fluorescence was observed; no solvent cut. Peaks Depth TG C1 C2 C3 C41 C4N C51 C5N 9092' 248 48082 NA NA NA NA NA NA Beluga N Group (9097' to 9236' MD) Drill Rate (ft/hr) Total Gas (units Maximum Minimum Average Maximum Minimum Average 219 20 104 502 20 181 This group begins at approximately 9,097 feet MD and continues to approximately 9,236 feet MD. It consists of alternating tuffaceous siltstone and tuffaceous claystone with lesser amounts of interbedded tuffaceous shale, sand lenses, and very minor coal. The tuffaceous siltstone in this interval is medium gray to light gray with some dark gray with grayish black hues; pasty to slimy; mostly crumbly to crunchy; stiff in parts; moderate cohesiveness; non adhesive; earthy fracture; sub nodular to sub patchy; dull earthy to mottled luster; silty to ashy to gritty texture; massive gradational beds of tuffaceous siltstone interbedded with tuffaceous shale and lenses of sand increasing with depth; no visible sample fluorescence was observed; no solvent cut. The tuffaceous claystone in this interval is medium gray to dark gray with some light gray to bluish gray hues; pasty to mushy; very crumbly; irregular fracture; PDC butter curl to amorphous cuttings habit; mostly dull to slightly earthy luster; very clayey to El EPOCH 19 Conoco Phillips Alaska. Inc NCIU A -14 slightly silty texture; interbedded with thick beds of tuffaceous siltstone with minor amounts tuffaceous shale and sand; no visible sample fluorescence was observed; no solvent cut. The sand in this interval is translucent to clear with some white and light gray; predominantly quartz grain matrix; upper very fine to upper fine with some lower medium in places; well rounded to subrounded with some angular; moderate to high sphericity; moderate to well sorted throughout; surface impacted features; no visible sample fluorescence; no solvent cut. Peaks Depth TG C1 C2 C3 C4I C4N C51 C5N 9138' 502 97198 NA NA NA NA NA NA Beluga 0 Group (9236' to 9309' MD) Drill Rate (ft/hr) Total Gas (units Maximum Minimum Average Maximum Minimum Average 197 21 92 173 17 78 This group begins at approximately 9,236 feet MD and continues to approximately 9,309 feet MD. It consists of equal parts sand and tuffaceous siltstone, with a slight amount of tuffaceous shale and tuffaceous at the upper end of the interval. The tuffaceous siltstone in this interval is medium gray to light gray with some dark gray with grayish black hues; pasty to slimy; mostly crumbly to crunchy; stiff in parts; moderate cohesiveness; non adhesive; earthy fracture; sub nodular to sub patchy; dull earthy to mottled luster; silty to ashy to gritty texture; massive • gradational beds of tuffaceous siltstone interbedded with tuffaceous shale and lenses of sand increasing with depth; no visible sample fluorescence was observed; no solvent cut. The sand in this interval is light gray to gray; with some translucent to clear with hues of pale green, pale purple, light blue green and grayish blue green; predominantly upper very fine to lower medium grain size; poorly sorted throughout; very angular to subangular with some subrounded; friable to poorly consolidated; light grayish white to grayish brown tuffaceous clay matrix; sand is matrix supported; 90% translucent to smokey quartz; 10% coal fragments and gray volcanic lithics; interbedded with tuffaceous siltstone and tuffaceous claystone with very thin seams of immature coal; no visible sample fluorescence was observed; no apparent solvent cut. Peaks Depth TG C1 C2 C3 C41 C4N C5l C5N 9255' 173 33573 NA NA NA NA NA NA Beluga P Group (9309' to 9481' MD) Drill Rate (ft/hr) Total Gas (units Maximum Minimum Average Maximum Minimum Average 156 10 61 768 52 129 This group begins at approximately 9,309 feet MD and continues to approximately 9,481 feet MD. It consists of roughly equal parts sand, tuffaceous siltstone, and tuffaceous shale. The lower half of the group also contains significant tuffaceous claystone, and sparse amounts of tuffaceous sand and coal. The tuffaceous siltstone in this interval is medium gray to light gray with some dark gray with grayish black hues; pasty to slimy; mostly crumbly to crunchy; stiff in parts; moderate cohesiveness; non adhesive; earthy • El EPOCH 20 Conoc Phillips Alaska, Inc. NCIU A -14 • fracture; sub nodular to sub patchy; dull earthy to mottled luster; silty to ashy to gritty texture; massive gradational beds of tuffaceous siltstone interbedded with tuffaceous shale and lenses of sand increasing with depth; no visible sample fluorescence was observed; no solvent cut. The tuffaceous shale in this interval is grayish brown to light brown with some medium gray with some brownish gray; very slightly stiff to pasty; brittle to somewhat crunchy; slightly planar fracture in paces with overall irregular fracture; amorphous cuttings habit; very earthy to somewhat dull luster; slightly clayey to somewhat very dull texture; very thin layers of shale interbedded with thick beds of tuffaceous claystone and tuffaceous siltstone and small lenses of sand and tuffaceous sand; no visible sample fluorescence was observed; no solvent cut. The sand in this interval is light gray to gray; with some translucent to clear with hues of pale green, pale purple, light blue green and grayish blue green; predominantly upper very fine to lower medium grain size; poorly sorted throughout; very angular to subangular with some subrounded; friable to poorly consolidated; light grayish white to grayish brown tuffaceous clay matrix; sand is matrix supported; 90% translucent to smokey quartz; 10% coal fragments and gray volcanic lithics; interbedded with tuffaceous siltstone and tuffaceous claystone with very thin seams of immature coal; no visible sample fluorescence was observed; no apparent solvent cut. Peaks Depth TG C1 C2 C3 C41 C4N C51 C5N 9316' 768 148756 NA NA NA NA NA NA Beluga Q Group (9481' to 9687' MD) Drill Rate (ft/hr) Total Gas (units • Maximum Minimum Average Maximum Minimum Average 166 21 62 181 8 89 This group begins at approximately 9,481 feet MD to approximately 9,687 feet MD. It consists of tuffaceous siltstone grading into tuffaceous claystone, as well as sand /tuffaceous sand, decreasing with depth, and tuffaceous shale, which increases with depth and transitions into carbonaceous shale at the base. The tuffaceous siltstone in this interval is very pale orange to grayish pink with hues of pale blue; crumbly to crunchy, displaying earthy fracture; gritty to silty texture, and massive habit in cuttings, with laminae occasionally preserved; interbedded with brownish black shale, light pinkish gray tuffaceous sandstone, and minor amounts of medium to fine quartz sand. The tuffaceous claystone in this interval is medium gray to dark gray with some light gray to bluish gray hues; pasty to mushy; very crumbly; irregular fracture; PDC butter curl to amorphous cuttings habit; mostly dull to slightly earthy luster; very clayey to slightly silty texture; interbedded with thick beds of tuffaceous siltstone with minor amounts tuffaceous shale and sand; no visible sample fluorescence was observed; no solvent cut. The sand in this interval is light gray to gray; with some translucent to clear with hues of pale green, pale purple, light blue green and grayish blue green; predominantly upper very fine to lower medium grain size; poorly sorted throughout; very angular to subangular with some subrounded; friable to poorly consolidated; light grayish white to grayish brown tuffaceous clay matrix; sand is matrix supported; 90% translucent to smokey quartz; 10% coal fragments and gray volcanic lithics; interbedded with tuffaceous siltstone and tuffaceous claystone with very thin seams of immature coal; no visible sample fluorescence was observed; no apparent solvent cut. Peaks Depth I TG C1 I C2 I C3 C41 C4N C51 C5N • El EPOCH 21 ConocoPhillips Alaska, Inc. NCIU A -14 • 9639' 181 35076 1 NA NA NA NA 1 NA NA Beluga R Group (9687' to 9869' MD) Drill Rate (ft/hr) Total Gas (units Maximum Minimum Average Maximum Minimum Average 175 21 66 319 29 88 This group begins at approximately 9,687 feet MD and continues to approximately 9,869 feet MD. It mostly consists of slightly tuffaceous sand /sandstone with interbedded tuffaceous siltstone. Minor amounts of carbonaceous shale in the top portion transition into tuffaceous shale in the lower portion. The sand in this formation is comprised of light gray to white quartz sand, upper fine to lower medium grained; grains are moderately sorted and angular to subangular, displaying moderate sphericity; sparse lower coarse angular grains are present as well; the sand is interbedded with medium to light gray tuffaceous siltstone and a lesser amount of tuffaceous shale. The tuffaceous siltstone in this section is made up of gray to medium dark gray with some light gray to grayish black hues; very pasty to somewhat mushy; crumbly to slightly crunchy; dull earthy fracture; moderate cohesive; slightly adhesive; earthy mottled luster; clayey silty ashy texture; interbedded with thin beds of tuffaceous claystone and thin beds of shale and some thick lenses of sand; no visible sample fluorescence was observed; no solvent cut. The carbonaceous shale in this formation is composed of brownish black to dark gray; occurs as tough chunks and sand -sized chips; displays irregular fracture in larger massive pieces and planar fracture in smaller platy • fragments; fissile fragments, both large and small, are evident, though larger cuttings tend to possess poor structure; interbedded with yellowish gray siltstone, medium to fine quartz sand, and minor amounts of coal and light gray to pale blue claystone. Peaks Depth TG C1 C2 C3 C41 C4N C51 C5N 9839' 319 61841 NA NA NA NA NA NA Beluga S Group (9869' to 10,130' MD) Drill Rate (ft/hr) Total Gas (units Maximum Minimum Average Maximum Minimum Average 204 15 67 168 15 66 This group begins at approximately 9,869 feet MD to approximately 10,130 feet MD. It consists of roughly equal amounts of tuffaceous siltstone and slightly tuffaceous sand /sandstone. Minor coals occur near both the top and the base. The tuffaceous siltstone in this interval is medium gray to grayish brown with some brownish gray in places; clumpy to moderate induration; crumbly to crunchy; hackly to earthy fracture; becoming very stiff in parts; moderate cohesive; non to very slightly adhesive; dull earthy luster; silty to clayey to slightly ashy textures; massive bedded with thick beds of tuffaceous claystone and thick beds of sand /sandstone no visible sample fluorescence was observed; no solvent cut. The sand in this interval is light gray to gray with some grayish brown in places; fine upper to medium upper grain size; moderate to high sphericity; moderate to moderately well sorted; predominantly sub round to sub angular; estimate very poorly to moderately consolidated; dominantly matrix supported by dull gray tuffaceous El EPOCH 22 Conocrillips Alaska, Inc. NCIU A -14 • claystone; matrix washes away readily; 90% clear to translucent quartz; 10% carbonaceous material and trace coal fragments; noticed calcite mud additive in sample; interbedded with fragile tuffaceous claystone and dense to brittle tuffaceous siltstone; no visible sample fluorescence. Peaks Depth TG 01 C2 C3 C41 C4N C51 C5N 10040' 168 32493 NA NA NA NA NA NA Beluga T Group (10,130' to 10,538' MD) Drill Rate (ft/hr) Total Gas (units Maximum Minimum Average Maximum Minimum Average 153 10 56 514 18 82 This group begins at approximately 10,130 feet MD to approximately 10,538 feet MD. It consists of roughly equal amounts of sand, tuffaceous siltstone, and tuffaceous claystone. The tuffaceous siltstone in this formation is comprised of medium gray to grayish brown with some brownish gray in places; clumpy to moderate induration; crumbly to crunchy; hackly to earthy fracture; becoming very stiff in parts; moderate cohesive; non to very slightly adhesive; dull earthy luster; silty to clayey to slightly ashy textures; massive bedded with thick beds of tuffaceous claystone and thick beds of sand /sandstone no visible sample fluorescence was observed; no solvent cut. The tuffaceous claystone in this section is made up of very light gray to gray with occasional brownish gray hues; poor to moderate induration; brittle to crumbly; irregular fracture; amorphous to sub platy cuttings habit; dull to earthy luster; overall silty texture with some slightly clayey; very thick interbedded • with thick beds of tuffaceous siltstone and thick beds of sand /sandstone; no visible sample fluorescence was observed. no solvent cut. The sand in this formation consists of medium gray to light gray with some clear to white and some translucent throughout; predominantly quartz grain sand with abundant dark colored lithic fragments; upper very fine to upper fine grain; moderate to well sorted throughout; very well rounded to subrounded with some slightly angular to subangular; moderate to high sphericity; abundant volcanic lithics; 15 % -20% multicolored lithics dominated by dark bluish green clasts; no sample fluorescence was observed, no solvent cut. Peaks Depth TG 01 C2 C3 C41 C4N C51 C5N 10280' 514 99525 NA NA NA NA NA NA 10489' 191 36951 NA NA NA NA NA NA Beluga U Group (10,538' to 11,120' MD) Drill Rate (ft/hr) Total Gas (units Maximum Minimum Average Maximum Minimum Average 664 14 85 389 20 104 This group begins at approximately 10,538 feet MD to approximately 11,120 feet MD. It consists mostly of tuffaceous siltstone and tuffaceous claystone, with lesser amounts of sand and shale. The sand increases at the top and the base, and contrary to it, the shale increases in the middle of the interval. Sparse coals also occur in the sand -rich sections near the top and the base of the group. • EPOCI-I 23 ConocoPhillips Alaska, Inc NCIU A -14 • The tuffaceous siltstone in this formation is comprised of light gray to very light gray with some brownish gray to grayish brown; clumpy to slightly mushy in places; crumbly to crunchy; mostly irregular fracture; amorphous cuttings habit with some PDC butter curl; very dull to earthy luster; overall silty texture with some slightly clayey; very thick interbedded with thick beds of tuffaceous claystone and thin beds of shale and sand; no visible sample fluorescence was observed; no solvent cut. The tuffaceous claystone in this section consists of very light gray to gray with occasional brownish gray hues; poor to moderate induration; brittle to crumbly; irregular fracture; amorphous to sub platy cuttings habit; dull to earthy luster; overall silty texture with some slightly clayey; very thick interbedded with thick beds of tuffaceous siltstone and thick beds of sand /sandstone; no visible sample fluorescence was observed. no solvent cut. Peaks Depth TG 01 C2 C3 C41 C4N C51 C5N 11119' 389 75272 NA NA NA NA NA NA Beluga U Group, Base (11,120' to 11,501' MD) Drill Rate (ft/hr) Total Gas (units Maximum Minimum Average Maximum Minimum Average 263 12 63 395 51 140 The base of the Beluga U interval occurs at approximately 11,120 feet. In this well the base is siltstone- rich and contains interbedded sand and tuffaceous shale. • Peaks Depth TG C1 C2 C3 C41 C4N C51 C5N 11178' 395 76458 III El EPOCH 24 Conoc Phillips Alaska, Inc NCIU A -14 • 3.3 Connection Gases Connection Gases 1unit = 0.05% Methane Equivalent Depth Gas over BGG Depth Gas over BGG (feet) (units) (feet) (units) 4963 177 9034 63 5055 255 9092 138 5780 32 9151 508 5845 175 9282 92 5973 700 9345 138 6045 465 9409 155 6489 110 9472 110 6552 270 9535 133 6679 125 9599 88 6743 130 9662 85 6800 75 9724 148 6870 160 9788 126 6933 190 9851 319 7245 252 9915 158 7568 45 9979 56 7695 25 10042 80 8204 70 10106 70 • 8267 127 10170 20 8394 50 10297 162 8458 53 14363 49 8521 40 10427 58 8648 37 10490 151 8711 61 10553 133 8775 114 10617 196 8838 235 11379 130 8902 444 11443 230 3.4 Trip (Wiper) Gases 1unit = 0.05% Methane Equivalent Depth Trip to Gas Downtime (feet) (feet) (units) (hours) 7885 4757 179 6 9217 4757 369 7 10232 4757 520 28 • HI EPOCI-I 25 Conoco Phillips Alaska, Inc. NCIU A -14 0 3.5 Sampling Program / Sample Dispatch Set Type / Purpose Frequency Interval Dispatched to CPAI Washed Samples 50' 4756' — 7200' Bayview Geologic Facility A Set owner: CPAI 30' 7230' -9300' 619 East Ship Creek Ave Ste 14 20' 9320' - 11501' Anchorage, AK 99501 Attn: D. Przywojski 265 -6340 Set Type / Purpose Frequency Interval Dispatched to CPAI Washed Samples 50' 4756' — 7200' Bayview Geologic Facility B Set owner: CPAI 30' 7230' -9300' 619 East Ship Creek Ave Ste 14 20' 9320'- 11501' Anchorage, AK 99501 Attn: D. Przywojski 265 -6340 * Sample frequency was locally altered according to drill rate constraints and zones of interest. • • El EPOCH 26 • ConocoPhillips Alaska, t[tc. NCIU A -14 4 PRESSURE / FORMATION STRENGTH DATA 4.1 Pore Pressure Discussion The pore pressure gradient (PPG) is estimated to have varied from 9.4 in the Sterling formation to 10.1 in the Beluga Group. The mud weight was raised from 9.2 ppg to 9.6 before drilling the Beluga sands, then raised again to 9.9 in the Beluga Fm. prior to TD. 4.2 Quantitative Methods The primary indicators used for PPG evaluation were gas trends relative to mud weight (MW) and effective circulating density (ECD), including increases in background gas (BG), appearance and trends of connection gas (CG), and magnitudes of trip gas (TG) and wiper gas (WG). Regional pore pressure trends from sonic data, provided by ConocoPhillips, and surface manifestations of hole conditions were also considered. As a reference, PPG is calculated initially with a formula provided by Epoch, and then modified using the indicators described above, and DXC and resistivity (RES) data. The formula uses DX, ECD, and BG as measured by total ditch gas: PPG = ECD — (0.6- ((.001 *TLGSU) +(0.05 *DX))) The formula has certain limitations, such that it does not allow for a PPG more than 1 ppg Tess than the ECD, and TLGSU must be differentiated from show gas and gas carried from over pressure zones, and is dependent on reliable DX data. However, the formula proved useful in helping establish a PPG range, when establishing trends, as with DXC data, with data points in shale intervals. Li EPOCH 27 Conocillips Alaska. Inc. NCIU A -14 0 5 DRILLING DATA 5.1 Survey Data Measured True Latitude Departure Vertical Dogleg Depth Incl. Azom. p Vertical (ft) (ft) Section Rate (ft) O Depth (ft) N( +), S(-) E( +), W(-) (ft) ( ° /100ft) 221.58 0.18 324.83 221.58 0.00 0.00 0.00 TIE -IN 250.00 0.29 318.75 250.00 0.09 0.07 0.06 0.40 300.00 0.45 322.22 300.00 0.34 0.28 0.22 0.32 358.00 1.04 313.19 357.99 0.88 0.80 0.54 1.03 389.00 0.88 309.75 388.99 1.23 1.19 0.73 0.55 449.00 0.29 336.02 448.99 1.66 1.60 0.99 1.06 483.00 0.11 168.62 482.99 1.71 1.63 1.03 1.17 509.00 0.09 160.40 508.99 1.66 1.62 0.99 0.09 543.00 0.11 26.29 542.99 1.67 1.60 1.00 0.54 630.00 0.79 83.98 629.98 1.80 0.96 1.35 0.85 691.00 1.18 113.26 690.97 1.60 0.03 1.51 1.02 754.00 1.69 123.92 753.95 0.83 1.40 1.26 0.91 817.00 1.80 126.65 816.92 1.28 2.96 0.77 0.22 882.00 2.22 115.17 881.89 1.43 4.92 0.39 0.89 946.00 3.89 106.07 945.79 2.56 8.13 0.45 2.71 981.00 4.77 103.43 980.69 3.22 10.69 0.73 2.58 Ili 1009.00 5.02 102.20 1008.59 3.75 13.02 1.05 0.97 1074.00 5.63 90.00 1073.31 4.35 18.98 2.57 1.97 1137.00 6.81 69.37 1135.95 3.04 25.57 6.11 3.98 1200.00 8.79 46.73 1198.38 1.58 32.57 12.89 5.74 1263.00 11.22 32.88 1260.42 10.03 39.41 23.20 5.40 1326.00 13.31 17.69 1322.00 22.09 44.94 36.44 6.08 1389.00 14.94 14.60 1383.09 36.86 49.19 51.76 2.85 1453.00 17.22 15.93 1444.58 53.95 53.87 69.41 3.61 1540.72 20.00 21.96 1527.72 80.36 63.05 97.35 3.85 1604.07 21.89 23.88 1586.88 101.20 71.88 119.97 3.19 1667.57 23.93 25.78 1645.37 123.63 82.28 144.62 3.41 1731.07 26.69 25.80 1702.77 148.07 94.09 171.65 4.34 1794.02 29.90 24.95 1758.19 175.03 106.86 201.38 5.15 1857.27 32.95 24.25 1812.15 205.01 120.59 234.27 4.85 1920.77 34.11 23.64 1865.09 237.07 134.82 269.28 1.90 1984.27 36.00 23.20 1917.06 270.54 149.31 305.70 3.01 2047.62 39.79 24.52 1967.05 306.11 165.07 344.54 6.11 2112.02 41.61 23.16 2015.87 344.52 182.03 386.46 3.15 2175.22 43.07 23.78 2062.58 383.56 198.99 428.97 2.39 2239.27 46.43 22.16 2108.07 425.07 216.56 474.01 5.54 2303.62 48.78 24.62 2151.46 468.67 235.44 521.46 4.62 2368.47 52.14 26.75 2192.74 513.72 257.13 571.25 5.76 2433.27 55.55 28.01 2230.97 560.16 281.20 623.18 5.50 2486.68 53.18 27.58 2262.08 598.56 301.45 666.24 4.48 • El EPOCH 28 ConocoPhillips Alaska, Inc. NCIU A -14 0 2577.83 54.32 28.13 2315.98 663.55 335.80 739.14 1.34 2641.28 55.66 28.50 2352.38 709.30 360.45 790.63 2.16 2705.53 58.94 30.28 2387.09 756.39 386.99 844.03 5.61 2769.63 59.75 31.69 2419.77 803.66 415.38 898.25 2.28 2832.93 59.00 30.62 2452.02 850.27 443.56 951.78 1.88 2896.83 58.41 31.05 2485.21 897.16 471.55 1005.50 1.09 2960.78 57.73 30.96 2519.03 943.68 499.50 1058.87 1.07 3024.83 57.31 31.42 2553.43 989.89 527.49 1111.96 0.89 3087.43 56.92 31.97 2587.42 1034.62 555.10 1163.53 0.95 3151.08 56.80 32.08 2622.22 1079.81 583.37 1215.75 0.25 3214.88 58.70 31.67 2656.26 1125.62 611.86 1268.65 3.04 3279.03 58.73 31.82 2689.57 1172.25 640.70 1322.42 0.19 3339.88 58.52 32.59 2721.25 1216.21 668.39 1373.30 1.14 3404.93 58.22 32.69 2755.37 1262.85 698.26 1427.45 0.47 3469.23 58.01 33.43 2789.33 1308.61 728.04 1480.74 1.04 3531.53 58.22 32.45 2822.24 1353.00 756.81 1532.40 1.38 3593.88 58.57 31.72 2854.92 1397.99 785.01 1584.42 1.15 3658.33 58.71 30.89 2888.46 1445.01 813.61 1638.48 1.12 3721.68 58.50 30.91 2921.46 1491.42 841.37 1691.67 0.34 3785.38 58.41 31.04 2954.79 1537.96 869.31 1745.05 0.23 3849.58 58.39 31.01 2988.43 1584.82 897.49 1798.82 0.05 3912.88 58.02 31.57 3021.78 1630.80 925.43 1851.67 0.96 3977.18 57.48 31.87 3056.09 1677.06 954.01 1905.01 0.91 4038.68 57.47 30.78 3089.16 1721.36 980.96 1955.95 1.47 0 4102.53 57.37 30.68 3123.54 1767.61 1008.45 2008.90 0.19 4167.27 57.15 30.68 3158.55 1814.45 1036.24 2062.50 0.34 4230.37 56.38 29.44 3193.13 1860.12 1062.67 2114.54 2.05 4292.72 56.09 29.33 3227.79 1905.29 1088.10 2165.75 0.49 4356.32 55.97 29.46 3263.33 1951.24 1113.99 2217.86 0.25 4419.92 55.60 29.05 3299.09 1997.13 1139.69 2269.85 0.80 4483.67 55.56 28.93 3335.12 2043.13 1165.18 2321.86 0.16 4547.02 55.43 29.26 3371.01 2088.75 1190.57 2373.48 0.48 4611.07 55.17 29.55 3407.47 2134.62 1216.43 2425.51 0.55 4673.77 54.76 29.56 3443.46 2179.28 1241.75 2476.21 0.66 4706.77 55.01 29.65 3462.45 2202.75 1255.08 2502.86 0.80 4767.07 55.50 29.48 3496.81 2245.84 1279.53 2551.79 0.85 4832.62 56.12 29.67 3533.65 2293.00 1306.29 2605.34 0.98 4895.52 55.96 29.50 3568.78 2338.37 1332.05 2656.86 0.35 4958.67 55.78 29.48 3604.21 2383.87 1357.79 2708.49 0.28 5018.17 55.49 29.66 3637.80 2426.59 1382.03 2756.99 0.55 5085.27 55.86 29.75 3675.63 2474.72 1409.49 2811.69 0.56 5149.57 55.93 30.09 3711.69 2520.87 1436.05 2864.22 0.44 5213.42 56.85 31.02 3747.23 2566.66 1463.08 2916.58 1.88 5277.82 56.51 31.48 3782.41 2612.66 1490.99 2969.45 0.80 5340.77 56.40 31.41 3817.19 2657.42 1518.36 3020.96 0.20 5405.72 56.83 31.96 3852.93 2703.57 1546.84 3074.17 0.97 5469.87 57.02 32.39 3887.94 2749.07 1575.47 3126.81 0.64 5530.90 57.45 32.02 3920.97 2792.50 1602.82 3177.07 0.86 • U EPOCH 29 Canc Phillips Alaska. Inc NCIU A -14 • 5594.60 57.53 32.21 3955.21 2838.00 1631.38 3229.69 0.29 5656.35 57.60 32.36 3988.33 2882.05 1659.22 3280.70 0.23 5721.45 57.51 32.73 4023.25 2928.36 1688.78 3334.43 0.50 5783.45 57.19 32.51 4056.70 2972.33 1716.92 3385.47 0.61 5848.50 56.16 32.67 4092.44 3018.12 1746.19 3438.62 1.60 5912.60 55.84 32.31 4128.29 3062.95 1774.73 3490.61 0.69 5975.50 55.41 31.89 4163.80 3106.92 1802.32 3541.46 0.87 6038.95 55.34 31.26 4199.86 3151.41 1829.66 3592.70 0.83 6102.00 54.99 31.42 4235.87 3195.61 1856.58 3643.53 0.60 6166.90 54.72 30.42 4273.23 3241.13 1883.85 3695.73 1.33 6228.70 55.15 29.27 4308.74 3285.01 1909.02 3745.64 1.67 6292.15 55.56 29.19 4344.81 3330.56 1934.50 3797.23 0.66 6357.15 56.26 29.35 4381.24 3377.51 1960.82 3850.43 1.10 6418.85 56.94 28.79 4415.21 3422.53 1985.85 3901.37 1.34 6482.10 57.85 29.31 4449.30 3469.11 2011.72 3954.06 1.60 6546.50 58.59 29.53 4483.21 3516.79 2038.61 4008.14 1.19 6610.05 58.19 29.11 4516.52 3563.98 2065.11 4061.62 0.83 6673.60 57.72 29.14 4550.24 3611.04 2091.33 4114.88 0.74 6737.40 57.54 28.83 4584.40 3658.18 2117.44 4168.18 0.50 6802.35 56.92 28.69 4619.55 3706.05 2143.72 4222.23 0.96 6863.90 56.79 29.33 4653.20 3751.12 2168.71 4273.20 0.89 6926.60 57.07 30.08 4687.42 3796.76 2194.74 4325.06 1.10 6988.40 56.47 30.36 4721.29 3841.43 2220.76 4376.01 1.03 7051.85 56.16 30.34 4756.48 3886.99 2247.44 4428.03 0.49 ii 7116.75 56.26 7180.90 55.80 30.89 4792.57 3933.41 2274.90 4481.13 0.71 31.24 4828.42 3978.98 2302.35 4533.43 0.85 7243.50 56.61 32.75 4863.24 4023.10 2329.92 4584.41 2.39 7306.40 56.72 32.87 4897.81 4067.26 2358.39 4635.76 0.24 7370.65 56.44 33.08 4933.20 4112.25 2387.58 4688.12 0.51 7435.60 56.46 33.14 4969.09 4157.59 2417.15 4740.94 0.08 7498.40 56.86 32.25 5003.61 4201.74 2445.49 4792.22 1.34 7562.85 57.60 31.80 5038.49 4247.69 2474.23 4845.33 1.29 7625.20 57.24 31.93 5072.07 4292.31 2501.96 4896.84 0.61 7688.50 56.76 31.58 5106.55 4337.45 2529.90 4948.90 0.89 7751.60 57.18 29.30 5140.95 4383.05 2556.69 5001.01 3.10 7815.40 56.94 28.58 5175.64 4429.91 2582.60 5053.97 1.02 7878.60 56.39 28.25 5210.37 4476.35 2607.73 5106.27 0.98 7942.45 57.29 28.01 5245.29 4523.49 2632.92 5159.26 1.44 8005.80 57.43 26.68 5279.45 4570.88 2657.43 5212.22 1.78 8069.35 56.58 23.97 5314.06 4619.05 2680.22 5265.33 3.82 8132.05 56.02 21.88 5348.85 4667.09 2700.54 5317.44 2.90 8196.05 55.33 19.13 5384.94 4716.59 2719.06 5370.29 3.71 8259.40 54.49 16.60 5421.37 4765.91 2734.96 5422.06 3.53 8323.55 53.75 14.02 5458.97 4816.04 2748.69 5473.81 3.45 8387.10 53.59 10.54 5496.63 4866.05 2759.58 5524.47 4.41 8450.00 52.68 5.91 5534.38 4915.83 2766.79 5573.62 6.07 8513.30 51.82 2.58 5573.14 4965.72 2770.50 5621.66 4.37 8576.92 50.11 2.43 5613.21 5015.09 2772.66 5668.65 2.70 8640.82 49.64 1.84 5654.39 5063.91 2774.48 5715.02 1.02 • U EPOCH 30 Conoc Phillips Alaska, Inc. NCIU A -14 • 8704.52 49.43 1.96 5695.73 5112.35 2776.08 5760.94 0.36 8768.37 50.07 2.76 5736.99 5161.04 2778.09 5807.25 1.39 8831.27 50.20 2.81 5777.30 5209.26 2780.44 5853.24 0.21 8894.57 49.51 2.42 5818.12 5257.60 2782.65 5899.29 1.18 8959.12 48.88 2.45 5860.30 5306.42 2784.72 5945.74 0.98 9022.07 49.05 2.75 5901.62 5353.85 2786.88 5990.92 0.46 9085.37 49.56 3.99 5942.90 5401.76 2789.70 6036.78 1.68 9149.57 50.56 3.54 5984.11 5450.88 2792.94 6083.92 1.65 9211.27 51.84 2.58 6022.77 5498.89 2795.50 6129.79 2.40 9275.27 51.34 2.32 6062.54 5549.00 2797.65 6177.46 0.85 9337.72 50.90 2.82 6101.74 5597.56 2799.82 6223.71 0.94 9401.12 50.69 3.64 6141.81 5646.61 2802.59 6270.62 1.06 9464.62 50.36 3.55 6182.18 5695.53 2805.66 6317.52 0.54 9528.22 51.13 3.07 6222.42 5744.70 2808.51 6364.56 1.35 9590.27 51.82 3.07 6261.07 5793.17 2811.11 6410.88 1.11 9654.47 52.67 2.99 6300.38 5843.85 2813.79 6459.29 1.32 9717.97 51.78 2.87 6339.28 5893.98 2816.36 6507.14 1.40 9782.57 51.52 3.65 6379.36 5944.56 2819.24 6555.52 1.04 9845.92 51.72 4.25 6418.70 5994.10 2822.66 6603.12 0.80 9910.72 50.97 3.93 6459.17 6044.58 2826.27 6651.66 1.21 9972.42 50.23 3.54 6498.33 6092.16 2829.38 6697.31 1.30 10036.32 51.44 3.96 6538.69 6141.59 2832.62 6744.75 1.95 10099.22 52.83 4.69 6577.29 6191.10 2836.37 6792.44 2.40 10192.47 51.53 4.54 6634.48 6264.52 2842.30 6863.28 1.40 1 • 1 10255.42 50.53 4.15 6674.07 6313.32 2846.00 6910.28 1.66 10313.17 50.30 4.44 6710.87 6357.70 2849.33 6953.02 0.55 10383.07 52.76 4.05 6754.35 6412.28 2853.38 7005.55 3.54 10445.67 53.27 3.80 6792.01 6462.17 2856.81 7053.48 0.88 10499.32 52.77 3.46 6824.28 6504.94 2859.52 7094.49 1.07 10560.77 51.95 3.16 6861.81 6553.51 2862.33 7140.97 1.37 10632.57 51.54 2.94 6906.26 6609.82 2865.33 7194.76 0.62 10694.22 50.86 2.62 6944.89 6657.81 2867.66 7240.52 1.17 10765.12 51.16 3.14 6989.49 6712.85 2870.43 7293.05 0.71 10828.32 50.84 3.13 7029.27 6761.89 2873.12 7339.92 0.52 10891.32 50.16 2.77 7069.34 6810.44 2875.62 7386.27 1.16 10954.77 49.63 2.46 7110.21 6858.92 2877.84 7432.45 0.91 11018.72 49.12 2.02 7151.85 6907.42 2879.74 7478.54 0.96 11082.22 48.27 1.74 7193.77 6955.09 2881.30 7523.74 1.38 11142.47 47.78 1.25 7234.06 6999.87 2882.47 7566.09 1.01 11206.27 47.32 0.96 7277.12 7046.94 2883.38 7610.49 0.80 11269.87 46.92 0.54 7320.40 7093.54 2883.99 7654.35 0.80 11333.37 46.20 0.35 7364.06 7139.64 2884.35 7697.66 1.16 11396.61 45.35 0.29 7408.17 7184.96 2884.60 7740.19 1.33 11458.82 44.49 0.10 7452.22 7228.89 2884.75 7781.39 1.41 11501.00 44.49 0.10 7482.31 7258.44 2884.80 7809.09 0.01 El EPOCH 31 • • ConocoPhillips Alaska, lac, NCIU A -14 5.2 Bit Record Jets / Depth In Total Bit Avg. WOB PP Bit Size Make Type / S# TFA MD / Footage Hrs (iRtlOhr) Wear BHA (Klbs) RPM (psi) 1 8.75" Hughes DP504/7120037 6x13 4757' 5475 76.75 75 5 -13 120 2800 #3 Christinson 2 8.75" Hughes DP504RR/7120037 6x13 10232' 1269 24.75 51.3 5 -15 145 3000 #4 Christinson 5.3 Mud Record Contractor: MI SWACO Mud Type: LSND MW ECD VIS FL Sols O/W Sd CI Ca Date Depth (ppg) (ppg) (s /qt) PV YP Gels (cc) FC ( %) Ratio ( %) pH (m1/1) (m1 /1) 11/01/08 4796 9.2 9.4 70 17 25 6/7/9 4.4 1/1 4 1/95 0.5 9.9 28000 10 11/02/08 6106 9.4 9.6 68 17 29 9/11/13 4.2 _ 1/1 4 1/95 0.5 9.9 32000 80 11/03/08 7282 9.6 9.8 75 22 29 8/10/12 4.4 1/1 5 1/94 0.5 9.6 30000 200 11/04/08 7884 9.7 9.9 66 23 30 8/9/10 4.7 1/2 5 1/94 0.5 9.6 27500 120 11/05/08 7973 9.6 9.8 67 23 31 10/12/13 4.9 1/1 5 1/94 0.5 9.7 25500 120 11/06/08 8965 9.6 9.8 59 24 23 7/9/10 4.9 1/2 5 2/94 0.5 9.7 23500 90 11/07/08 9219 9.6 9.8 68 26 30 6/8/9 15.6 1/2 5 2/94 0.6 9.7 24000 90 11/08/08 9723 9.9 10.1 74 29 32 7/9/10 4 1/2 9 2/90 0.8 9.7 24000 90 11/09/08 10232 10.0 10.2 69 26 30 5/7/9 4.7 1/2 9 2/90 0.8 9.8 30500 40 11/10/08 10232 10.0 10.2 79 27 28 6/8/9 14.6 1/2 9 2/90 0.75 9.7 31000 40 11/11/08 10642 9.9 10.1 61 24 26 6/7/9 4.6 1/2 9 2/90 0.75 9.7 26500 200 11/12/08 11374 9.9 10.1 67 23 29 9/12/14 14.2 1/2 9 2/90 0.75 9.8 31000 20 11/13/08 11501 9.9 10.1 63 23 28 9/11/13 13.9 1/2 9 2/89 0.5 9.8 29500 40 11/14/08 11501 9.9 10.1 60 19 25 7/9/11 13.6 1/2 9 2/89 0.5 9.7 32000 60 11/15/08 11501 9.9 10.1 59 19 27 7/8/10 13.6 1/2 9 2/89 0.5 9.8 32000 80 11/16/08 EPOCH 32 • 0 0 Conoco ill ps Alaska, Inc. NCIU A -14 Abbreviations MW = Mud Weight Gels = Gel Strength Sd = Sand content ECD = Effective Circulating Density WL = Water or Filtrate Loss CI = Chlorides VIS = Funnel Viscosity FC = Filter Cake Ca = Hardness Calcium PV = Plastic Viscosity Sols = Solids O/W = Oil to Water ratio YP = Yield Point El EPOCH 33 6 MORNING REPORTS El EPOCH 34 ConocoPhillips Alaska Inc. NCIU A -14 Daily Report Report for: Dave Morris Dave Nugent Date: 11/02/08 Time: 0000 Current Depth (MD): 4796' Current Circulate & condition for Current Depth 3485' Operations: LOT (TVD): 24 hr Footage (MD): 40' Note: ROP: Current: 0 Max: 891.8 Torque: Current: Max: WOB: Current 0 Max: 21K RPM: Current: Max: PP: Current: 1351 Max: 1901 Lag: Strokes: 6611 Time: 38.22 Surf -to Strokes: Time: Surf: ECD: Current: Max: Mud Properties @ xx:xx hrs /xxxx' MW: 9.2 FV: 70 PV: 17 YP: 25 FL: 4.4 GELLS 6/7/9 Sol: 4 pH: 9.9 CI 28000 Ca + +: 10 MW Change: Depth: From: To: Reason: Mud Loss event: Depth: Volume: Gas Data Ditch Gas: Current: 0 Max:244 I Depth ( MD/TVD): I 4794' Avg BG : 15 Gas Events Depth (MD/TVD) C1 C2 C3 C4I C4N C5I C5N Trip Gas None Connection None C1 C2 C3 C4I C4N C5I C5N Gases Gas Samples No. Depth ( MD/TVD) TG C1 C2 C3 C4I C4N C5I C5N None Lithologies: Current: 90% Tuffaceous siltstone; 10% silty sand Last 24 hrs: Test BOPs. Pick up /make up BHA and run into hole. Test casing integrity to 3000psi. Drill out floats and shoe track and 20' new hole. Insufficient new rock Operational Summary: fragments in sample to indicate good formation contact. Drill additional 20' new hole to 1796'. Circulate and condition mud /displace cement contaminated mud with 9.2ppg KlaShield mud. Perform LOT to 16.6ppg mwe. Calibrations: Check span and calibrate THA at 1830 hrs Failures: Gas trap briefly plugged /re- positioned. El EPOCH ConocoPhillips Alaska Inc. NCIU A -14 Daily Report Report for: Dave Morris Dave Nugent Current Depth Date: 11/03/2008 Time: 4:00 (MD): 6088' Current Current Depth Operations: drilling (TVD): 4227.99' 24 hr Footage 1289' (MD): Note: ROP: Current: 114 Max: 440 Torque: Current: Max: WOB: Current 4.4 Max: 20 RPM: Current: Max: PP: Current: 2066 Max: 2320 Lag: Strokes: 9217 Time: 41.89min Surf -to Strokes: Time: Surf: ECD: Current: Max: Mud Properties @ xx:xx hrs /xxxx' MW: 9.4 FV: 68 PV: 17 YP: 29 FL: 4.2 GELLS 9/11/13 Sol: 4 pH: 9.9 Cl 32000 Ca + +: 80 MW Change Depth: gradual From: 9.2 To: 9.4 Reason: Mud Loss event: Depth: Volume: Gas Data • Ditch Gas: Current: Max: ( MD/TVD): I Avg BG : 20 998 5695/4119tvd Gas Events Depth (MD/TVD) C1 C2 C3 C4I C4N C5I C5N Trip Gas none Connection C1 C2 C3 C4I C4N C5I C5N Gases 177u@ 4963' 24631 255u @5055' 28448 32u @5780' 4971 175u @5845' 26042 5 700u @5973' 98985 36 465u @6045' 40177 8 Gas Samples No. Depth (MD/TVD) TG C1 C2 C3 C41 C4N C5I C5N NONE Lithologies: Current: 10% Sand, 50% Tuffaceous siltstone, 10% each tuffaceous claystone, claystone, carbonaceous shale and ash. Last 24 hrs: 30% Sand, 50% Tuffaceous siltstone /claystone, 20% Coal /carbonaceous shale Operational Summary: Drill /directional drill drom 4799' to 6088'. Calibrations: Span and calibrate THA • Failures: El EPOCH ConocoPhillips Alaska Inc. NCIU A -14 Daily Report Report for: Dave Morris Dave Nygent Date: 11/04/2008 Time: 0000 Current Depth 7251 (MD): Current Circulate and condition Current Depth 4964 Operations: mud (TVD): 24 hr Footage (MD): 1196 Note: ROP: Current: 58 Max: 358 Torque: Current: 12 Max: 12 WOB: Current 22 Max: 22 RPM: Current: 84.5 Max: 108 PP: Current: 2289 Max: 2650 Lag: Strokes: 8750 Time: 41.47 Surf -to Strokes: Time: Surf: ECD: Current: Max: Mud Properties @ 1830 hrs/7060/4770 MW: 9.6 FV: 75 PV: 22 YP: 29 FL: 4.4 GELLS 8/10/12 Sol: 5 pH: 9.6 Cl 30000 Ca + +: 200 MW Change: Depth: 6930 From: 9.4 To: 9.6 Reason: gas Mud Loss event: Depth: Volume: Gas Data Ditch Gas: Current: Max: I Depth ( MD/TVD): • Avg BG : 5 45 Gas Events Depth (MD/TVD) C1 C2 C3 C4I C4N C5I C5N Trip Gas Connection C1 C2 C3 C4I C4N C5I C5N Gases 110u @6489/4453 12545 270u @6552/4486 55454 125u @6679/4553 23185 130u @6743/4586 23953 75u @6800/4618 13932 160u @6870/4657 31048 3 190u @6933/4702 11046 5 252u @7245 36675 13 /4903 Gas Samples No. Depth (MD/TVD) TG C1 C2 C3 C4I C4N C51 C5N none Lithologies: Current: 50% sand, 50% Tuffaceous siltstone, trace to common coal /carbonaceous shale and ash Last 24 hrs: 60% Tuffaceous siltstone /Shale; 40% Sand/Tuffaceous sand; Intermittent thin to moderate cols Drill ahead to 6741'. Circulate well for safety meeting. Drill ahead to 6930'. Operational Summary: Circulate out high gas and condition mud. Drill ahead to 7055'. Circulate out high gas and condition mud. Drill ahead to 7251'. Circulate and work on top drive. Drill El EPOCH to 8284' at midnight. • Calibrations: Clean and adjust gas trap as necessary to clear clay /coal plugging. Check span on THA and check run chromatograph Failures: Note Daily Charge $3235.00 O EPOCH ConocoPhillips Alaska Inc. NCIU A -14 fa Daily Report Report for: Dave Morris Scott Heim Current Depth Date: 11/05/2008 Time: 00:00 (MD): 7885 Current Current Depth Operations: Tripping out to shoe (ND): 5213 24 hr Footage (MD): 624 Note: ROP: Current: 0 Max: 160 Torque: Current: n.a. Max: 12 WOB: Current n.a. Max: 23 RPM: Current: n.a. Max: 95 PP: Current: 2252 Max: 2898 Lag: Strokes: 8765 Time: 41.67 Surf -to Strokes: Time: Surf: ECD: Current: Max: Mud Properties @ 22:00 hrs / 6497' MW: 9.7 FV: 66 PV: 23 YP: 30 FL: 4.7 GELLS 18/9/10 Sol: 5 pH: 9.6 CI 27500 Ca + +: 120 MW Change: Depth: From: To: Reason: Mud Loss event: Depth: Volume: Gas Data Ditch Gas: Current: 0 Max: 244 Depth (MD/TVD): 7806/5171 • Avg BG : 50 Gas Events Depth (MD/TVD) C1 C2 C3 C4I C4N C5I C5N Trip Gas Connection C1 C2 C3 C4I C4N C5I C5N Gases 7568 45 7695 25 Gas Samples No. Depth ( MD/TVD) TG C1 C2 C3 C4I C4N C5I C5N none Lithologies: Current: 40% tuffaceous siltstone; 20% tuffaceous claystone; 20% sand; 10% tuffaceous sandstone; 10% tuffaceous shale 60% tuffaceous siltstone; 20% sandand /or tuffaceous sandstone;10% tuffaceous Last 24 hrs: claystone; 10% tuffaceous shale; intermittent trace coal, carbonaceous shale, and ash tuff Operational Summary: Drill ahead to 7885. Commence short trip to the shoe. 411 Calibrations: none Failures: none El EPOCH ConocoPhillips Alaska Inc. NCIU A -14 • Daily Report Report for: Dave Morris Scott Heim Date: 11/06/2008 Time: 00:00 Current Depth (MD): 7980 Current Current Depth 5265 Operations: Drilling ahead (TVD): 24 hr Footage (MD): 95 Note: ROP: Current: 135 Max: 181 Torque: Current: n.a. Max: 12 WOB: Current 7 Max: 13 RPM: Current: 99 Max: 100 PP: Current: 2827 Max: 2827 Lag: Strokes: 7825 Time: 35.09 Surf-to Strokes: Time: Surf: ECD: Current: Max: Mud Properties @ 22:15 hrs / 7917' MW: 9.6 FV: 67 PV: 23 YP: 31 FL: 4.9 10/12/13 8/9/10 Sol: 5 pH: 9.7 CI Cl 25500 Ca + +: 120 MW Change: Depth: From: To: Reason: Mud Loss event: Depth: Volume: Gas Data Ditch Gas: Current: 37 I Max: 96 Depth (MD/TVD): 7927/5237 • Avg BG : 47 Gas Events Trip Gas Depth (MD/TVD) C1 C2 C3 C41 C4N C51 C5N 196 7885/5214 Connection C1 C2 C3 C41 C4N C5I C5N Gases Gas Samples No. Depth (MD/TVD) TG C1 C2 C3 C4I C4N C5I C5N none Lithologies: Current: 50% tuffaceous siltstone; 10% tuffaceous claystone; 20% sand; 20% tuffaceous shale 50% tuffaceous siltstone; 20% sandand /or tuffaceous sandstone;10% tuffaceous Last 24 hrs: claystone; 20% tuffaceous shale; intermittent trace coal, carbonaceous shale, and ash tuff Operational Summary: POOH. Cut and slip drilling line, repair top drive. Trip into hole, drill ahead to 7980. • Calibrations: none Failures: none El EPOCH ConocoPhillips Alaska Inc. NCIU A -14 • Daily Report Report for: Dave Morris Scott Heim Current Depth Date: 11/07/2008 Time: 00:00 (MD): 8963' Current Current Depth Operations: Drilling ahead (ND): 5862' 24 hr Footage (MD): 983' Note: ROP: Current: 25 ft/hr Max: 276 ft/hr Torque: Current: 14 ft-lbs Max: 12 ft-lbs WOB: Current 11 Klbs Max: 33 Klbs RPM: Current: 57 Max: 105 PP: Current: 2727 psi Max: 3071 psi Lag: Strokes: 8824 Time: 39.57 min Surf-to Strokes: Time: Surf: ECD: Current: Max: Mud Properties @ 21:00 hrs/8863' MW: 9.6 FV: 59 PV: 24 YP: 23 FL: 4.9 GELS 7/9/10 Sol: 5% pH: 9.7 Cl _ 23500 Ca + +: 90 MW Change: Depth: From: To: Reason: Mud Loss event: Depth: Volume: Gas Data Ditch Gas: Current: 38 Max: 443 Depth ( MD/TVD): 8831'/5777' • Avg BG : 52 Gas Events Depth (MD/TVD) C1 C2 C3 C4I C4N C5I C5N Trip Gas Connection C1 C2 C3 C4l C4N C5I C5N Gases 70 8204/5389 50 8267/5426 53 8394/5463 40 8458/5539 37 8521/5578 61 8648/5659 114 ( +Swab Gas) 8711/5700 235 ( +Swab Gas) 8775/5741 444 ( +Swab Gas) 8838/5781 127 ( +Swab Gas) 8902/5823 Gas Samples No. Depth ( MD/TVD) TG C1 C2 C3 C41 C4N C5I C5N Litholo ies: Current: 60% tuffaceous siltstone; 20% tuffaceous sandstone; 10% tuffaceous claystone; g 10% carbonaceous shale 40% tuffaceous siltstone; 20% sand; 20% tuffaceous claystone; Last 24 hrs: 10% shale /tuffaceous shale; minor carbonaceous shale, tuffaceous sandstone, 111/ and coal Operational Summary: Drill ahead to 8963. HI EPOCH Calibrations: none • Failures: none • • El EPOCH ConocoPhillips Alaska Inc. NCIU A -14 • Daily Report Report for: Dave Morris Scott Heim Date: 11/08/2008 Time: 00:00 Current Depth (MD): 9217' Current Short trip to shoe, Current Depth 6026' Operations: switch out drill pipe. (TVD): 24 hr Footage (MD): 254' Note: ROP: Current: n.a. Max: 264 ft/hr Torque: Current: n.a. Max: 16 ft -Ibs WOB: Current 0 Klbs Max: 19 Klbs RPM: Current: n.a. Max: 106 PP: Current: n.a. Max: 3157 psi Lag: Strokes: n.a. Time: n.a. Surf -to Strokes: Time: Surf: ECD: Current: Max: Mud Properties @ 21:00 hrs/8863' MW: 9.6 FV: 68 PV: 26 YP: 30 FL: 4.8 GELS 6/8/9 Sol: 5% pH: 9.7 Cl 24000 Ca + +: 90 MW Change: Depth: From: To: Reason: Mud Loss event: Depth: Volume: Gas Data Ditch Gas: Current: 1 Max: 993 Depth (MD/TVD): 9160'/5991' Avg BG : 132 • Gas Events Depth (MD/TVD) C1 C2 C3 C4I C4N C5I C5N Trip Gas Connection C1 C2 C3 C4I C4N C5I C5N Gases 63 9034/5908 138 ( +Swab Gas) 9092/5947 508 ( +Swab Gas) 9151/5985 Gas Samples No. Depth ( MD/TVD) TG C1 C2 C3 C4I C4N C5I C5N Lithologies: Current: 70% tuffaceous siltstone; 30% sand Last 24 hrs: 60% tuffaceous siltstone; 20% sand; 10% carbonaceous shale; minor tuffaceous clay, tuffaceous sandstone, and coal Operational Summary: Drill ahead to 9217, POOH. Calibrations: none Failures: none • El EPOCH ConocoPhillips Alaska Inc. NCIU A -14 • Daily Report Report for: Dave Morris Scott Heim Current Depth Date: 11/09/2008 Time: 00:00 (MD): 9780' Current Current Depth Operations: Drilling ahead. (TVD): 6376' 24 hr Footage (MD): 563' Note: ROP: Current: 53 ft/hr Max: 219 ft/hr Torque: Current: 16 ft -Ibs Max: 18 ft -Ibs WOB: Current 3 Klbs Max: 17 Klbs RPM: Current: 98 Max: 100 PP: Current: 2998 psi Max: 3309 psi Lag: Strokes: 9666 Time: 45.81 min Surf-to Strokes: Time: Surf: ECD: Current: Max: Mud Properties @ 21:30 hrs/9723' MW: 9.9 FV: 74 PV: 29 YP: 32 FL: 4 GELS 7/9/10 Sol: 9% pH: 9.7 Cl 24000 Ca + +: 90 MW Change: Depth: From: To: Reason: Mud Loss event: Depth: Volume: Gas Data Ditch Gas: Current: 112 Max: 1 812 Depth ( MD/TVD): 9340'/6103' • Avg BG : 99 Gas Events Depth (MD/TVD) C1 C2 C3 C4I C4N C5I C5N Trip Gas 369 9217'/6026' Connection C1 C2 C3 C4I C4N C5I C5N Gases 92 ( +Swab Gas) 9282'/6067' 138 ( +Swab Gas) 9345'/6107' 155 ( +Swab Gas) 9409'/6147' 110 ( +Swab Gas) 9472'/6187' 133 ( +Swab Gas) 9535'/6227' 88 ( +Swab Gas) 9599'/6267' 85 ( +Swab Gas) 9662'/6305' 148 ( +Swab Gas) 9724'/6343' Gas Samples No. Depth ( MD/TVD) TG C1 C2 C3 C4I C4N C5I C5N Lithologies: Current: 40% tuffaceous siltstone; 30% sand; 10% conglomeratic sand; 10% tuffaceous sandstone; 10% tuffaceous shale 40% tuffaceous siltstone; 20% tuffaceous clay; 25% sand; 5% carbonaceous Last 24 hrs: shale; 5% coal; minor tuffaceous sandstone, tuffaceous shale, and conglomeratic sand • Operational Summary: Drill ahead to 9780. Calibrations: none HI EPOCH HDOdI I • M auou :saJnI! ConocoPhillips Alaska Inc. NCIU A -14 Daily Report Report for: Dave Morris Scott Heim Current Depth Date: 11/10/2008 Time: 00:00 (MD): 10232' Current POOH Current Depth Operations: (TVD): 6657' 24 hr Footage (MD): 452' Note: ROP: Current: n.a. Max: 204 ft/hr Torque: Current: n.a. Max: 18ft -Ibs WOB: Current n.a. Max: 25 Klbs RPM: Current: n.a. Max: 101 PP: Current: n.a. Max: 3261 psi Lag: Strokes: n.a. Time: n.a. Surf-to Strokes: Time: Surf: ECD: Current: Max: Mud Properties @ 13:00 hrs /10160' MW: 9.9 FV: 76 PV: 27 YP: 27 FL: 4.5 GELS 5/7/9 Sol: 9% pH: 9.9 CI 29000 Ca" 40 MW Change: Depth: From: To: Reason: Mud Loss event: Depth: Volume: Gas Data Ditch Gas: Current: 0 Max: 319 Depth (MD/TVD): 9839'/6415' Avg BG : 66 Gas Events Depth (MD/TVD) C1 C2 C3 C4I C4N C51 C5N Trip Gas Connection C1 C2 C3 C41 C4N C5I C5N Gases 126 ( +Swab Gas) 9788'/6383' 319 ( +Swab Gas) 9851'/6422' 158 ( +Swab Gas) 9915'/6462' 56 ( +Swab Gas) 9979'/6502' 80 ( +Swab Gas) 1004216542' 70 ( +Swab Gas) 10106'/6581' 20 1017016620' Gas Samples No. Depth (MD/TVD) TG C1 C2 C3 C41 C4N C5I C5N Lithologies: Current: 40% tuffaceous siltstone; 30% tuffaceous claystone; 20% sand; 10% siltstone 40% tuffaceous siltstone; 20% tuffaceous claystone; 15% coal; 10% sand; 5% Last 24 hrs: sandstone; minor conglomeratic sandstone, tuffaceous sandstone, tuffaceous shale, and siltstone Operational Summary: Drilled ahead to 10232; tripping out of hole to service MWD tool. • Calibrations: none Failures: none HI EPOCH ConocoPhillips Alaska Inc. NCIU A -14 Daily Report Report for: Dave Morris Scott Heim Date: 11/11/2008 Time: 00:00 Current Depth (MD): 10232' Current Current Depth TIH 6657' Operations: (TVD): 24 hr Footage (MD): 0' Note: ROP: Current: n.a. Max: n.a. Torque: Current: n.a. Max: n.a. WOB: Current n.a. Max: n.a. RPM: Current: n.a. Max: n.a. PP: Current: n.a. Max: n.a. Lag: Strokes: n.a. Time: n.a. Surf -to Surf: Strokes: Time: ECD: Current: Max: Mud Properties @ 11:30 hrs/10232' MW: 9.9 FV: 74 PV: 27 YP: 27 FL: 4.6 GELS 6/8/9 Sol: 9% pH: 9.8 CI 30500 Ca + +: 40 MW Change: Depth: From: To: Reason: Mud Loss event: Depth: Volume: Gas Data Ditch Gas: Current: 0 Max: I n.a. Depth (MD/TVD): 1 9839'/6415' Avg BG : n.a. Gas Events Depth (MD/TVD) C1 C2 C3 C41 C4N C51 C5N Trip Gas Connection C1 C2 C3 C4I C4N C51 C5N Gases Gas Samples No. Depth (MD/TVD) TG C1 C2 C3 C41 C4N C5I C5N Lithologies: Current: 40% tuffaceous siltstone; 30% tuffaceous claystone; 20% sand; 10% siltstone Last 24 hrs: n.a. Operational Summary: Switch out MWD tooling and service rig; begin tripping into hole. Calibrations: none Failures: none • E EPOCH ConocoPhillips Alaska Inc. NCIU A -14 Daily Report Report for: Dave Morris Scott Heim Current Depth Date: 11/12/2008 Time: 00:00 (MD): 10641' Current Current Depth Operations: Drilling ahead (TVD): 6910' 24 hr Footage (MD): 409' Note: ROP: Current: 65 ft/hr Max: 176 ft/hr Torque: Current: 14 ft-lbs Max: 20 ft-lbs WOB: Current 6 Klbs Max: 11 Klbs RPM: Current: 79 Max: 101 PP: Current: 2937psi Max: 3224 psi Lag: Strokes: 10948 Time: 50.92 min. Surf -to Strokes: Time: Surf: ECD: Current: Max: Mud Properties @ 12:45 hrs/10296' MW: 9.9 FV: 72 PV: 28 YP: 30 FL: 4.8 GELS 6/7/8 Sol: 9% pH: 9.8 Cl 28000 Ca" 240 MW Change: Depth: From: To: Reason: Mud Loss event: Depth: Volume: Gas Data Ditch Gas: Current: 66 Max: 1 525 I Depth (MD/TVO): 1 10280'/6688' Avg BG : 98 Gas Events Depth (MD/TVD) C1 C2 C3 C4I C4N C5I C5N Trip Gas 520 10232'/6657' Connection C1 C2 C3 C41 C4N C5I C5N Gases 162 ( +Swab Gas) 10297'/6699' 49 14363'/6741' 58 10427'/6781' 151 ( +Swab Gas) 10490'/6819' 133 10553'/6857 196 10617'/6896' Gas Samples No. Depth ( MD/TVD) TG C1 C2 C3 C41 C4N C5I C5N Lithologies: Current: 40% sand; 30% tuffaceous siltstone; 10% tuffaceous sandstone; 10% tuffaceous shale; 10% carbonaceous shale 45% tuffaceous siltstone; 20% sand; 5% coal; 5% tuffaceous claystone; 5% Last 24 hrs: tuffaceous shale; 5% siltstone; minor tuffaceous sandstone, conglomeratic sand, and shale Operational Summary: TIH to shoe; slip and cut drill line; TIH to bottom; drill ahead to 10641. • Calibrations: none Failures: none El EPOCH ConocoPhillips Alaska Inc. NCIU A -14 Daily Report Report for: Scott Heim Mike Ross Date: 11/14/2008 Time: 00:00 Current Depth 11501' (MD): Current POOH Current Depth 7480 Operations: (TVD): 24 hr Footage (MD): 137' Note: TD reached at 09:00 hours. ROP: Current: n.a. Max: 126 ft/hr Torque: Current: n.a. Max: 21 ft-lbs WOB: Current n.a. Max: 10 Klbs RPM: Current: n.a. Max: 103 PP: Current: n.a. Max: 3175 psi Lag: Strokes: n.a. Time: n.a. Surf-to Strokes: Time: Surf: ECD: Current: Max: Mud Properties @ 22:00 hrs/11501' MW: 9.9 FV: 63 PV: 23 YP: 28 FL: 4.7 GELS 9/11/13 Sol: 9% pH: 9.8 Cl 329500 Ca + +: 40 MW Change: Depth: From: To: Reason: Mud Loss event: Depth: Volume: Gas Data Ditch Gas: Current: n.a. Max: 1 260 Depth (MD/TVD): 1 11492'/7474' • Avg BG : 107 Gas Events Depth (MD/TVD) C1 C2 C3 C4I C4N C51 C5N Trip Gas (none) Connection C1 C2 C3 C41 C4N C51 C5N Gases 130 11379'/7396' 230 11443'/7440' Gas Samples No. Depth (MD/TVD) TG C1 C2 C3 C4I C4N C51 C5N Lithologies: Current: 30% sand; 30% siltstone; 20% tuffaceous siltstone; 10% tuffaceous claystone; 10% shale Last 24 hrs: 30% tuffaceous siltstone; 20% sand; 20% siltstone; 20% shale; 10% tuffaceous claystone Operational Summary: Drill ahead to 11380; service pump #1; continue drilling ahead with pump #2 only; revise TD and end drilling @ 11501'; back ream while pulling out. Calibrations: None Failures: None • PI EPOCH ConocoPhillips Alaska Inc. • NCIU A -14 Daily Report Report for: Scott Heim Mike Ross Date: 11/15/2008 Time: 00:00 Current Depth 11501' (MD): Current Testing BOP's, Current Depth 7480, Operations: servicing rig. (TVD): 24 hr Footage (MD): n.a. Note: TD reached at 09:00 on 11/13/2008. ROP: Current: n.a. Max: n.a. Torque: Current: n.a. Max: n.a. WOB: Current n.a. Max: n.a. RPM: Current: n.a. Max: n.a. PP: Current: n.a. Max: n.a. Lag: Strokes: n.a. Time: n.a. Surf -to Strokes: Time: Surf: ECD: Current: Max: Mud Properties @ 22:00 hrs MW: 9.9 FV: 60 PV: 19 YP: 25 FL: 5.1 GELS 7/9/11 Sol: 9% pH: 9.7 CI 32000 Ca + +: 60 MW Change: Depth: From: To: Reason: Mud Loss event: Depth: Volume: Gas Data Ditch Gas: Current: n.a. Max: 113 Depth ( MD/TVD): (POOH) Avg BG : 57 Gas Events Depth (MD/TVD) C1 C2 C3 C41 C4N C51 C5N Trip Gas (none) Connection C1 C2 C3 C4I C4N C51 C5N Gases (none) Gas Samples No. Depth (MD/TVD) TG C1 C2 C3 C4I C4N C51 C5N Lithologies: Current: n.a. Last 24 hrs: n.a. Operational Summary: Complete tripping out of hole; recover MWD tool; test BOP's; service mud pump. Calibrations: None Failures: None • El EPOCH ConocoPhillips Alaska Inc. NCIU A -14 Daily Report Report for: Scott Heim Mike Ross Date: 11/16/2008 Time: 00:00 Current Depth 11501' (MD): Current Wireline run Current Depth 7480' Operations: (with drill pipe) (TVD): 24 hr Footage (MD): n.a. Note: TD reached at 09:00 on 11/13/2008. ROP: Current: n.a. Max: n.a. Torque: Current: n.a. Max: n.a. WOB: Current n.a. Max: n.a. RPM: Current: n.a. Max: n.a. PP: Current: n.a. Max: n.a. Lag: Strokes: n.a. Time: n.a. Surf Strokes: Time: Surf: ECD: Current: Max: Mud Properties @ 21:30 hrs MW: 9.9 FV: 59 PV: 19 YP: 27 FL: 5.3 GELS 7/8/10 Sol: 9% pH: 9.8 CI 32000 Ca + +: 80 MW Change: Depth: From: To: Reason: Mud Loss event: Depth: Volume: Gas Data Ditch Gas: Current: 0 _ Max: I n.a. I Depth (MD/TVD): Avg BG : n.a. Gas Events Depth (MD/TVD) C1 C2 C3 C4I C4N C5I C5N Trip Gas (none) Connection C1 C2 C3 C4I C4N C5I C5N Gases (none) Gas Samples No. Depth (MD/TVD) TG C1 C2 C3 C4I C4N C5I C5N Lithologies: Current: n.a. Last 24 hrs: n.a. Operational Summary: Continue BOP test; slip and cut drill line; attempt wireline run, stall at —5700'; POOH and run wireline tools on drill pipe. Calibrations: None Failures: None • E EPOCH ConocoPhillips Alaska Inc. NCIU A -14 • Daily Report Report for: Scott Heim Mike Ross Date: 11/17/2008 Time: 00:00 Current Depth 11501' (MD): Current Running MDT wireline Current Depth 7480' Operations: tool (with drill pipe) (TVD): 24 hr Footage (MD): n.a. Note: TD reached at 09:00 on 11/13/2008. ROP: Current: n.a. Max: n.a. Torque: Current: n.a. Max: n.a. WOB: Current n.a. Max: n.a. RPM: Current: n.a. Max: n.a. PP: Current: n.a. Max: n.a. Lag: Strokes: n.a. Time: n.a. Surf -to Strokes: Time: Surf: ECD: Current: Max: Mud Properties @ 21:00 hrs MW: 9.9 FV: 58 PV: 18 YP: 27 FL: 5.2 GELS 7/8/9 Sol: 9% pH: 9.7 CI 32000 Ca + +: 80 MW Change: Depth: From: To: Reason: Mud Loss event: Depth: Volume: Gas Data 411 Ditch Gas: Current: 1 Max: n.a. I Depth ( MD/TVD): Avg BG : n.a. Gas Events Depth (MD/TVD) C1 C2 C3 C4I C4N C5I C5N Trip Gas (none) Connection C1 C2 C3 C4I C4N C5I C5N Gases (none) Gas Samples No. Depth (MD/TVD) TG C1 C2 C3 C4I C4N C5I C5N Lithologies: Current: n.a. Last 24 hrs: n.a. Operational Summary: Running formation testing tool on drill pipe. Calibrations: None Failures: None HI EPOCH