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Home My WebLink About212-0681. 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 Other: ESP Swap 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): 19,544 NA Casing Collapse Conductor NA Surface 2,260psi Intermediate 3,090psi Slotted Liner NA 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: Contact Email: Contact Phone: 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 Keith Lopez 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 AOGCC USE ONLY Tubing Grade: Tubing MD (ft):Perforation Depth TVD (ft): STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0388574, ADL0391283 212-068 NIKAITCHUQ SP33-W03 3800 Centerpoint Dr, Suite 1400 Anchorage, AK 99503 50-629-23480-00-00 Hilcorp Alaska, LLC Length Size Proposed Pools: 3,572 19,527 3,571 1,083 SCHRADER BLUFF OIL SCHRADER BLUFF OIL 160' 160' 12.6# / L-80 TVD Burst 10,309' MD NA NA 10,938' 5,020psi 5,750psi 2,422' 3,589' 3,571' 3,118' 10,973' Slotted Liner 123' 20" 13-3/8" 9-5/8" 3,081' 5-1/2"8,739' Slotted Liner 907-777-8438 keith.lopez@hilcorp.com Operations Manager December 1, 2025 4-1/2" Perforation Depth MD (ft): NIKAITCHUQ SLXP Liner Hanger Packer, six oil swell packers, and NA 10,543' MD/3,566' TVD, see schematic for swell packers, and NA NA 19,527' Form 10-403 Revised 06/2023 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov By Grace Christianson at 2:16 pm, Nov 17, 2025 Digitally signed by Sara Hannegan (2519) DN: cn=Sara Hannegan (2519) Date: 2025.11.17 13:42:25 - 09'00' Sara Hannegan (2519) 325-702 DSR-11/19/25MGR21NOV25 * BOPE test to 2500 psi. 48 hour notice to AOGCC for opportunity to witness. A.Dewhurst 17NOV25 10-404 JLC 11/21/2025 11/21/25 Well: SP33-W03 and L1 PTD: 212-068 and 219-053 API: 50-629-23480-00-00 / 61-00 Well Name:SP33-W03 and L1 API Number:50-629-23480-00-00 Current Status:Producer Rig:Team Snubbing 101 Estimated Start Date:12/01/25 Estimated Duration:13 days Regulatory Contact:Darci Horner Permit to Drill Number:212-068 First Call Engineer:Keith Lopez (907) 777-8438 (O) (907) 903-5432 (M) Second Call Engineer:Ryan Rupert (907) 777-8503 (O) (907) 301-1736 (M) Current Bottom Hole Pressure: 1,400 psi @ 3,548 TVD |7.6 PPGE Max Potential Surface Pressure: 1,086 psi Gas Column Gradient (0.1 psi/ft) Max Angle: 82° Sail Angle from 3,872 MD to ESP setting depth of 10,400 MD Brief Well Summary: SP33 was drilled and completed as a single lateral Schrader Bluff Oa sand producer in June 2012. A second Oa lateral was added in May 2019. The current ESP only ran for 0.2 years before suffering a shaft part on 11/04/25. Objectives: Pull ESP completion, perform wellbore cleanout as necessary, and run new ESP completion. Notes Regarding Wellbore Condition: 9-5/8 casing was tested before adding the second lateral on 05/19/19 to 1,500 psi for 30 minutes (good test). HWO Conditions Traditional well control approach will be implemented. KWF will be a barrier at all times during HWO operations. No snubbing operations are planned during this work. Team Snubbings BOP stack will be used for this operation (see attachment). Pre-Rig Procedure (Non Sundried Work) Operations: 1. Bleed off gas cap from IA before the rig move to the well. HWO Procedure (Begin Sundried Work) 1. MIRU Team Snubbing Hydraulic Workover (HWO) Unit 101, ancillary equipment, and lines. 2. Displace corrosion inhibitor from capillary line prior to pulling ESP. 3. Kill well by bullheading the tubing string and the IA with injection water. a. Tubing volume 156 bbls. b. Annulus volume 595 bbls. c. Monitor OA annulus during kill. 4. Flow check for 30 min to ensure the well is killed. 5. Install BPV/TWC inside tubing hanger as per Vault. Well: SP33-W03 and L1 PTD: 212-068 and 219-053 API: 50-629-23480-00-00 / 61-00 6. Nipple up BOP. 7. Conduct BOP Test. a. Notify AOGCC 48 hours in advance for witness b. Test to 250psi Low /2,500psi High / 2,500psi Annular c. BOPE will be used as needed to circulate the well 8. Pull BPV/TWC from the tubing hanger per Vault procedure. 9. Call out ESP Contractor to pull ESP and pull tubing hanger. 10. RU tubing handling equipment. 11. Pump approximately 10 bbl/hour (+ pipe displacement while pulling pipe) of injection water down the annulus throughout the operations to maintain well fill. 12. POOH with 4-1/2 ESP completion assembly laying down. Record number of clamps recovered. 13. PU cleanout assembly and cleanout casing at ESP setting depth as necessary. 14. RIH with ESP completion on 4-1/2 tubing to +/- 10,400. a. Check electrical continuity every 1000. b. Note PU and SO weights on tally. 15. Land tubing hanger. Use extra caution to not damage cable. 16. Lay down landing joint. 17. Set BPV/TWC, ND BOP. 18. NU tree and test, pull BPV/TWC. 19. RDMO TS HWO 101. Attachments: 1. Current Wellbore Schematic 2. Proposed Wellbore Schematic 3. Snubbing BOP diagram (TSI) 4. HWO Fluid Flow Diagrams (TSI) 5. Snubbing stack stabilization diagram (TSI) * If risk of pressure under BPV - lubricate BPV - mgr. Nikaitchuq Field Last Completed: 9/2/2025 PTD: 212-068 (Mainbore) / 219-053 (Lateral L1) API #: 50-629-23480-00-00 (Mainbore)/61-00 (Lateral L1) Casing 20 20" 5-1/2" 5-1/2" Size ID Top Btm 13-3/8" 20"N/A Surface 160 13-3/8" 12.415" Surface 3,118' 9-5/8"8.835 Surface 10,972' 5-1/2 4.950 10,788' 19,527' 5-12"4.950 10,615' 19,520' 4-1/2" 3.958" Surface 10,245' No Top MD TVD Inc ID 1 10,185' 3,533' 83 3.725" 10,245' 3,540' 83 3.833" 10,245' 3,540' 83 NA 10,246' 3,540' 83 NA 10,271' 3,543' 84 NA 10,281' 3,544' 84 NA 1 10,286'3,545' 84 NA 10,287' 3,545' 84 NA 10,294' 3,546' 84 NA 10,301' 3,547' 84 NA 10,326' 3,549' 84 NA 10,329' 3,550' 84 NA 3 10,543' 3,566' 87 3.970" 4 10,612' 3,569' 87 3.750" 5 10,615' 3,569' 87 4.825" 6 7 10,718' 3,573' 88 8 4.75" 9 4.75" 10 10,788' 3,575' 89 3.00" 3 4 Casing exit window 5 10,630'-1,646' MD 5-1/2" Eccentric Shoe 88 Inc OA Sand 6 7 Lateral L1 5-1/2" Slotted liner, date run 6/12/2019 8, 9 10 Resman Oil/Water Tracers (x5) HAL 5-1/2" Oil Swell Packers (x6) 5-1/2" Eccentric shoe 88 Inc 9-5/8" OA Sand Mainbore 5-1/2" Slotted liner, date run 7/18/2012 2 Baker MLXP Liner Hanger/Packer Seal Bore Receptacle Bottom of Seal Assembly Mainbore Baker SLZXP Liner Hanger/Packer RAM Hanger, 5.879" lateral L1 drift ID, 4.825" mainbore drift ID 4-1/2" x 9-5/8" RAM Seal Bore Diverter w/3.64" Seal Bore JEWELRY DETAIL 2 Motor Centralizer 7-5/8", bottom @ 10,331' L1 Baker SLXP Liner Hanger/Packer 4-1/2" Lateral Entry Module (LEM) w/3.64" Seal Bore Pump #2 - PMP 538PMSXD 75 FLEX80 Pump #1 - PMP538PMSXD 20 GINPSHH Gas Separator Intake Upper Tandem Seal Lower Tandem Seal Motor 562XP 400/2785/88 MGU Sensor Downhole Item 4-1/2" 'XN' Landing Nipple Discharge Head Zenith DGU Head 19,581' Tubing internally coated with TK-15X 12.6#, L-80, Hyd 563 Conductor 179#, X-65 Surface 68#, L-80, BTC Intermediate 40#, L-80, Hydril 563 Production (SP33-W03) 15.5#, L-80 (17# from 18,666') Production (SP33-W03L1) 15.5#, L-80, Hyd 521 TUBING DETAIL CASING DETAIL Type Wt/ Grade/ Conn Driven Mainbore 8-3/4" hole, slotted liner 19,544' Lateral L18-3/4" hole, slotted liner Cement Details Hole MD SP33-W03 Schematic Dual Lateral Producer with ESP Lift CEMENT 160' 13-3/8"16" hole, Stg 1: 496 bbls 10.7 ppg ASL Stg 2: 67 bbls 12.5 ppg DeepCrete, returns to surface 3,134' 9-5/8" 12-1/4" hole, 216 bbls 12.5 ppg DeepCrete 10,988' ESP power cable, 3/8" Chem Inj Line (x2) Flatpack w/2500# check valve on the motor centralizer 00070 degree inclination @ ~3,497' XN SP33-W3 Schematic 9-22-2025 new ESP Last edited by: DH 11/13/2025 Nikaitchuq Field Last Completed: 9/2/2025 PTD: 212-068 (Mainbore) / 219-053 (Lateral L1) API #: 50-629-23480-00-00 (Mainbore)/61-00 (Lateral L1) Casing 20 20" 5-1/2" 5-1/2" Size ID Top Btm 13-3/8" 20"N/A Surface 160 13-3/8" 12.415" Surface 3,118' 9-5/8"8.835 Surface 10,972' 5-1/2 4.950 10,788' 19,527' 5-12"4.950 10,615' 19,520' 4-1/2" 3.958" Surface TBD No Top MD TVD Inc ID 1 TBD TBD TBD 3.725" TBD TBD TBD 3.833" TBD TBD TBD NA TBD TBD TBD NA TBD TBD TBD NA TBD TBD TBD NA 1 TBD TBD TBD NA TBD TBD TBD NA TBD TBD TBD NA TBD TBD TBD NA TBD TBD TBD NA TBD TBD TBD NA 3 10,543' 3,566' 87 3.970" 4 10,612' 3,569' 87 3.750" 5 10,615' 3,569' 87 4.825" 6 7 10,718' 3,573' 88 8 4.75" 9 4.75" 10 10,788' 3,575' 89 3.00" 3 4 Casing exit window 5 10,630'-1,646' MD 5-1/2" Eccentric Shoe 88 Inc OA Sand 6 7 Lateral L1 5-1/2" Slotted liner, date run 6/12/2019 8, 9 10 Resman Oil/Water Tracers (x5) HAL 5-1/2" Oil Swell Packers (x6) 5-1/2" Eccentric shoe 88 Inc 9-5/8" OA Sand Mainbore 5-1/2" Slotted liner, date run 7/18/2012 2 Baker MLXP Liner Hanger/Packer Seal Bore Receptacle Bottom of Seal Assembly Mainbore Baker SLZXP Liner Hanger/Packer RAM Hanger, 5.879" lateral L1 drift ID, 4.825" mainbore drift ID 4-1/2" x 9-5/8" RAM Seal Bore Diverter w/3.64" Seal Bore JEWELRY DETAIL 2 Motor Centralizer 7-5/8", bottom @ 10,331' L1 Baker SLXP Liner Hanger/Packer 4-1/2" Lateral Entry Module (LEM) w/3.64" Seal Bore Pump #2 - PMP 538PMSXD 75 FLEX80 Pump #1 - PMP538PMSXD 20 GINPSHH Gas Separator Intake Upper Tandem Seal Lower Tandem Seal Motor 562XP 400/2785/88 MGU Sensor Downhole Item 4-1/2" 'XN' Landing Nipple Discharge Head Zenith DGU Head 19,581' Tubing internally coated with TK-15X 12.6#, L-80, Hyd 563 Conductor 179#, X-65 Surface 68#, L-80, BTC Intermediate 40#, L-80, Hydril 563 Production (SP33-W03) 15.5#, L-80 (17# from 18,666') Production (SP33-W03L1) 15.5#, L-80, Hyd 521 TUBING DETAIL CASING DETAIL Type Wt/ Grade/ Conn Driven Mainbore 8-3/4" hole, slotted liner 19,544' Lateral L18-3/4" hole, slotted liner Cement Details Hole MD SP33-W03 Proposed Schematic Dual Lateral Producer with ESP Lift CEMENT 160' 13-3/8"16" hole, Stg 1: 496 bbls 10.7 ppg ASL Stg 2: 67 bbls 12.5 ppg DeepCrete, returns to surface 3,134' 9-5/8" 12-1/4" hole, 216 bbls 12.5 ppg DeepCrete 10,988' ESP power cable, 3/8" Chem Inj Line (x2) Flatpack w/2500# check valve on the motor centralizer 00070 degree inclination @ ~3,497' XN SP33-W3 Proposed Schematic 11-13-2025 ESP Swap Last edited by: DH 11/13/2025 TEAM SNUBBINGINTERNATIONALSP-12BOP Stack Drawing54.13"33.8"33.8"24.0"13 5/8"00 PSI Annular5000 PSI Single Gae VBR:2 7/8" - 5 1/2"5000 PSI Single GaeBlinds5000 PSI Flow Cross5000 PSI Riser5013 5/8" 13 5/8" 13 5/8" 13 5/8" 1. 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 Other: ESP Swap 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): 19,544 NA Casing Collapse Conductor NA Surface 2,260psi Intermediate 3,090psi Slotted Liner NA 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: Contact Email: Contact Phone: 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 Keith Lopez 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 AOGCC USE ONLY Tubing Grade: Tubing MD (ft):Perforation Depth TVD (ft): STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0388574, ADL0391283 212-068 NIKAITCHUQ SP33-W03 3800 Centerpoint Dr, Suite 1400 Anchorage, AK 99503 50-629-23480-00-00 Hilcorp Alaska, LLC Length Size Proposed Pools: 3,572 19,527 3,571 1,083 SCHRADER BLUFF OIL SCHRADER BLUFF OIL 160' 160' 12.6# / L-80 TVD Burst 10,309' MD NA NA 10,938' 5,020psi 5,750psi 2,422' 3,589' 3,571' 3,118' 10,973' Slotted Liner 123' 20" 13-3/8" 9-5/8" 3,081' 5-1/2"8,739' Slotted Liner 907-777-8438 keith.lopez@hilcorp.com Operations Manager August 20, 2025 4-1/2" Perforation Depth MD (ft): NIKAITCHUQ SLXP Liner Hanger Packer, six oil swell packers, and NA 10,543' MD/3,566' TVD, see schematic for swell packers, and NA NA 19,527' Form 10-403 Revised 06/2023 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov By Grace Christianson at 8:17 am, Aug 12, 2025 Digitally signed by Sara Hannegan (2519) DN: cn=Sara Hannegan (2519) Date: 2025.08.11 14:54:49 - 08'00' Sara Hannegan (2519) 325-477 A.Dewhurst 12AUG25 DSR-8/14/25 10-404 * BOPE test to 2500 psi. 24 hour notice. MGR15AUG25*&: Jessie L. Chmielowski Digitally signed by Jessie L. Chmielowski Date: 2025.08.15 10:35:40 -08'00'08/15/25 RBDMS JSB 081825 Well: SP-33 PTD: 212-068 API: 50-629-23480-00-00 Well Name:SP-33 API Number:50-629-23480-00-00 Current Status:Producer Rig:Team Snubbing 101 Estimated Start Date:08/20/2025 Estimated Duration:9days Regulatory Contact:Darci Horner Permit to Drill Number:212-068 First Call Engineer:Keith Lopez (907) 777-8438 (O) (907) 903-5432 (M) Second Call Engineer:Sara Hannegan (907) 564-4624 (O) (907) 309-1196 (M) Current Bottom Hole Pressure: 1,400 psi @ 3,570’ TVD |7.5 PPGE Max Potential Surface Pressure: 1,083 psi Gas Column Gradient (0.1 psi/ft) Max Angle: 83° Sail Angle from 3,900’ MD to ESP setting depth of 10,300’ MD Brief Well Summary: SP33 was drilled and completed in July 2012 as a Schrader Bluff OA producer with an ESP completion. A second lateral was added in June 2019. The current ESP ran for 3 months before an apparent shaft part on August 11, 2025. Objectives: Pull ESP completion and run new ESP completion. Notes Regarding Wellbore Condition: x Casing test to 1,000 psi passed 5/19/2019. HWO Conditions x Traditional well control approach will be implemented. x KWF will be a barrier at all times during HWO operations. x No snubbing operations are planned during this work. x Team Snubbing’s BOP stack will be used for this operation (see attachment). Pre-Rig Procedure (Non Sundried Work) Operations: 1. Bleed off gas cap from IA before the rig move to the well HWO Procedure (Begin Sundried Work) 1. MIRU Team Snubbing Hydraulic Workover (HWO) Unit 101, ancillary equipment, and lines. 2. Displace corrosion inhibitor from capillary line prior to pulling ESP. 3. Kill well by bull heading the tubing string and the IA with injection water. a. Pump 130% tubing volume (203 bbls) of injection water inhibited with biocide. b. Pump 130% annulus volume (770 bbls) of injection water inhibited with biocide. c. Monitor OA annulus during kill. 4. Flow check for 30 min to ensure the well is killed. 5. Install BPV/TWC inside tubing hanger as per Vault. 6. Nipple up BOP. 7. Conduct BOP Test. a. Notify AOGCC 48 hours in advance for witness Well: SP-33 PTD: 212-068 API: 50-629-23480-00-00 b. Test to 250psi Low /2,500psi High / 2,500psi Annular c. BOPE will be used as needed to circulate the well. d. Submit to AOGCC completed 10-424 form within 5 days of BOPE test. 8. Pull BPV/TWC from the tubing hanger per Vault procedure. 9. Call out ESP Contractor to pull ESP and pull tubing hanger. 10. RU tubing handling equipment. 11. Pump approximately 10 bbl/hour (+ pipe displacement while pulling pipe) of injection water down the annulus throughout the operations to maintain well fill. 12. POOH with 4-1/2” ESP completion laying down tubing and ESP. Record number of clamps recovered. 13. RIH with ESP completion on 3-1/2” or 4-1/2” tubing to +/- 10,374’. a. Check electrical continuity every 1000’. b. Note PU and SO weights on tally. 14. Land tubing hanger. Use extra caution to not damage cable. 15. Lay down landing joint. 16. Set BPV/TWC, ND BOP. 17. NU tree and test, pull BPV/TWC. 18. RDMO TS HWO 101. Attachments: 1. Current Wellbore Schematic 2. Proposed Wellbore Schematic 3. Snubbing BOP diagram (TSI) 4. HWO Fluid Flow Diagrams (TSI) 5. Snubbing stack stabilization diagram (TSI) Nikaitchuq Field Last Completed: 4/16/2025 PTD: 212-068 (Mainbore) / 219-053 (Lateral L1) API #: 50-629-23480-00-00 (Mainbore)/61-00 (Lateral L1) Casing 20” 20" 5-1/2" 5-1/2" 13-3/8"Size ID Top Btm 20"N/A Surface 160’ 13-3/8"12.415" Surface 3,118' 9-5/8"8.835” Surface 10,972' 5-1/2”4.950” 10,788' 19,527' 5-12"4.950” 10,615' 19,520' 4-1/2"3.958" Surface 10,291' No Top MD TVD Inc ID OD 1 10,232' 3,539' 83 3.725" 6.072" 10,291' 3,546' 84 3.833" 5.130" 10,292' 3,546' 84 NA 5.130" 10,293' 3,546' 84 NA 4.000" 10,316' 3,548' 84 NA 5.380" 10,326' 3,549' 84 NA 5.380" 1 10,331'3,550' 84 NA 5.130" 10,332' 3,550' 84 NA 5.130" 10,339' 3,551' 84 NA 5.130" 10,346' 3,551' 84 NA 5.620" 10,371' 3,554' 85 NA 4.500" 10,374' 3,555' 85 NA 7.625" 3 10,543' 3,566' 87 3.970" 8.430" 4 10,612' 3,569' 87 3.750" 7.310" 5 10,615' 3,569' 87 4.825" 8.340" 6 7 10,718' 3,573' 88 8 4.75" 9 4.75" 10 10,788' 3,575' 89 3.00" 7.00" 3 4 Cement Details Hole MD SP33-W03 Schematic Dual Lateral Producer with ESP Lift CEMENT Type Wt/ Grade/ Conn Driven 160' 13-3/8"16" hole, Stg 1: 496 bbls 10.7 ppg ASL Stg 2: 67 bbls 12.5 ppg DeepCrete, returns to surface 3,134' 9-5/8" 12-1/4" hole, 216 bbls 12.5 ppg DeepCrete 10,988' Mainbore 8-3/4" hole, slotted liner 19,544' Lateral L18-3/4" hole, slotted liner 19,581' CASING DETAIL Tubing internally coated with TK-15X 12.6#, L-80, Hyd 563-CB Conductor 179#, X-65 Surface 68#, L-80, BTC Intermediate 40#, L-80, Hydril 563 Production (SP33-W03) 15.5#, L-80 (17# from 18,666') Production (SP33-W03L1) 15.5#, L-80, Hyd 521 TUBING DETAIL JEWELRY DETAIL Item 4-1/2" XN Landing Nipple, 3.813 XN profile 2 Discharge Head Zenith DGU Head Pump #2 - PMP 538PMSXD 82FLEX 27 HS 12CR Pump #1 - PMP538PMSXD 20 GINPSHH H6 FER 12CR Gas Separator Intake 2 Lower Tandem Seal Motor 562XP 400/2785/88/16R 12CR MGU Sensor Downhole Motor Centralizer, bottom @ 10,377' L1 Baker SLXP Liner Hanger/Packer 4-1/2" Lateral Entry Module (LEM) w/3.64" Seal Bore RAM Hanger, 5.879" lateral L1 drift ID, 4.825" mainbore drift ID 4-1/2" x 9-5/8" RAM Seal Bore Diverter w/3.64" Seal Bore Baker MLXP Liner Hanger/Packer Seal Bore Receptacle Bottom of Seal Assembly Mainbore Baker SLZXP Liner Hanger/Packer Upper Tandem Seal Casing exit window 5 ѷ10,630'-1,646' MD 5-1/2" Eccentric Shoe 88Ƶ Inc OA Sand 6 7 Lateral L1 5-1/2" Slotted liner, date run 6/12/2019 8 9 Resman Oil/Water Tracers (x5) 10 HAL 5-1/2" Oil Swell Packers (x6) 5-1/2" Eccentric shoe 88Ƶ Inc 9-5/8" OA Sand Mainbore 5-1/2" Slotted liner, date run 7/18/2012 ESP power cable, 3/8" Chem Inj Line (x2) Flatpack w/2500# check valve on the motor centralizer 00070 degree inclination @ ~3,497' XN SP33-W3 Schematic 5-19-2025 Last edited by: DH 8/11/2025 Nikaitchuq Field Last Completed: 4/16/2025 PTD: 212-068 (Mainbore) / 219-053 (Lateral L1) API #: 50-629-23480-00-00 (Mainbore)/61-00 (Lateral L1) Casing 20” 20" 5-1/2" 5-1/2" 13-3/8"Size ID Top Btm 20"N/A Surface 160’ 13-3/8"12.415" Surface 3,118' 9-5/8"8.835” Surface 10,972' 5-1/2”4.950” 10,788' 19,527' 5-12"4.950” 10,615' 19,520' 4-1/2"3.958" Surface 10,291' No Top MD TVD Inc ID OD 1* 10,232' 3,539' 83 3.725" 6.072" 10,291' 3,546' 84 3.833" 5.130" 10,292' 3,546' 84 NA 5.130" 10,293' 3,546' 84 NA 4.000" 10,316' 3,548' 84 NA 5.380" 10,326' 3,549' 84 NA 5.380" 1 10,331'3,550' 84 NA 5.130" 10,332' 3,550' 84 NA 5.130" 10,339' 3,551' 84 NA 5.130" 10,346' 3,551' 84 NA 5.620" 10,371' 3,554' 85 NA 4.500" 10,374' 3,555' 85 NA 7.625" 3 10,543' 3,566' 87 3.970" 8.430" 4 10,612' 3,569' 87 3.750" 7.310" 5 10,615' 3,569' 87 4.825" 8.340" 6 7 10,718' 3,573' 88 8 4.75" 9 4.75" 10 10,788' 3,575' 89 3.00" 7.00" * Depth Approximate 3 4 Cement Details Hole MD SP33-W03 Proposed Schematic Dual Lateral Producer with ESP Lift CEMENT Type Wt/ Grade/ Conn Driven 160' 13-3/8"16" hole, Stg 1: 496 bbls 10.7 ppg ASL Stg 2: 67 bbls 12.5 ppg DeepCrete, returns to surface 3,134' 9-5/8" 12-1/4" hole, 216 bbls 12.5 ppg DeepCrete 10,988' Mainbore 8-3/4" hole, slotted liner 19,544' Lateral L18-3/4" hole, slotted liner 19,581' CASING DETAIL Tubing internally coated with TK-15X 12.6#, L-80, Hyd 563-CB Conductor 179#, X-65 Surface 68#, L-80, BTC Intermediate 40#, L-80, Hydril 563 Production (SP33-W03) 15.5#, L-80 (17# from 18,666') Production (SP33-W03L1) 15.5#, L-80, Hyd 521 TUBING DETAIL JEWELRY DETAIL Item 4-1/2" XN Landing Nipple, 3.813 XN profile 2* Discharge Head Zenith DGU Head Pump #2 - PMP 538PMSXD 82FLEX 27 HS 12CR Pump #1 - PMP538PMSXD 20 GINPSHH H6 FER 12CR Gas Separator Intake 2 Lower Tandem Seal Motor 562XP 400/2785/88/16R 12CR MGU Sensor Downhole Motor Centralizer, bottom @ 10,377' L1 Baker SLXP Liner Hanger/Packer 4-1/2" Lateral Entry Module (LEM) w/3.64" Seal Bore RAM Hanger, 5.879" lateral L1 drift ID, 4.825" mainbore drift ID 4-1/2" x 9-5/8" RAM Seal Bore Diverter w/3.64" Seal Bore Baker MLXP Liner Hanger/Packer Seal Bore Receptacle Bottom of Seal Assembly Mainbore Baker SLZXP Liner Hanger/Packer Upper Tandem Seal Casing exit window 5 ѷ10,630'-1,646' MD 5-1/2" Eccentric Shoe 88Ƶ Inc OA Sand 6 7 Lateral L1 5-1/2" Slotted liner, date run 6/12/2019 8 9 Resman Oil/Water Tracers (x5) 10 HAL 5-1/2" Oil Swell Packers (x6) 5-1/2" Eccentric shoe 88Ƶ Inc 9-5/8" OA Sand Mainbore 5-1/2" Slotted liner, date run 7/18/2012 ESP power cable, 3/8" Chem Inj Line (x2) Flatpack w/2500# check valve on the motor centralizer 00070 degree inclination @ ~3,497' XN SP33-W3 Proposed Schematic 8-11-2025 new ESP Last edited by: DH 8/11/2025 (1(5*<6(59,&(6,&21EKd͗/E^d>>>dKDK>ϭϰϬϵϭϬd/KtE>h'^^D>z͘dzWYdzϰEKd͗h^KD'hzt/ZE,KZWK/Ed^ϯϴΖϬΗϯϴΖϬΗ'hz'hz'hz&'hz'hz'hz''hz,'hzEKd͗Z&ZdKKD^W^&KZ'/EWK>'hzt/ZZYh/ZDEd^EKd͗^hZdK:<ͲhWD^t/d,DK>ϭϮϳϱϮϮE,KZ͘dzWYdzϰy'hz>/E^W^yWd>KdE^/KE^KEW/t/EWZK&/>^Λϭϰϱ&dKs>EEϭ͕ϬϬϬ>&WZͲdE^/KE͘h^ϯͬϰ/tZ/W^ϲyϭϵt/ZZKWKZYh/s>Ed'hzt/ZWWZKy/Dd>E'd,^d/DdW<dE^/KEϰϬ&dϳ͕ϭϬϬ>&ϰϬ&dϳ͕ϯϬϬ>&ϰϬ&dϲ͕ϮϱϬ>&ϰϬ&dϲ͕ϭϬϬ>&Ϯϲ&dϭϬ͕ϮϬϬ>&&Ϯϲ&dϵ͕ϲϬϬ>&'Ϯϲ&dϵ͕ϱϬϬ>&,Ϯϲ&dϵ͕ϱϬϬ>&6'a216+25(B*8</,1(6ϭK&ϭZs͗%ZtE͗,<͗WWZKs͗d͗^,d^/͗WZK:d/KE͗ͲͲͲͲͲͲ&/>͗d/d>͗^,dd/d>͗^>^t't'η͗ϮϬϮϱͲϬϲͲϬϵd,/E&KZDd/KE/E>h/Ed,/^KhDEd/^WZKWZ/dZzE^,>>EKdZWZKh͕dZE^&ZZ͕KZ/^>K^dKKd,Z^͕&KZEzWhZWK^t,d^KsZ͕t/d,Khdd,tZ/ddEhd,KZ/d/KEK&/KEEZ'z^Zs/^͘Ϯϯϱϱϭ͘ϬϮϱ>td͗d^ͲϭϬϭͬϭϬϮDK<ͲhWϮϭϰϳϬ^,d͗ STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION BOPE Test Report for: Reviewed By: P.I. Suprv Comm ________NIKAITCHUQ SP33-W03 JBR 05/14/2025 MISC. INSPECTIONS: FLOOR SAFTY VALVES:CHOKE MANIFOLD:BOP STACK: ACCUMULATOR SYSTEM:MUD SYSTEM: P/F P/F P/FP/FP/F Visual Alarm QuantityQuantity Time/Pressure SizeQuantity Number of Failures:2 Tested with 2 7/8" and 5" Test Joints. LPR function and passed retest on 2 7/8" TJ and Annular Function and passed retest on 5" TJ. Precharge bottles = 1@950psi and 35@ 1000psi. Good Test Test Results TEST DATA Rig Rep:G. Neuharth / L. BillingOperator:Hilcorp Alaska, LLC Operator Rep:C. Gueco / C. Smith Rig Owner/Rig No.:Doyon 15 PTD#:2120680 DATE:4/7/2025 Type Operation:WRKOV Annular: 250/3500Type Test:INIT Valves: 250/3500 Rams: 250/3500 Test Pressures:Inspection No:bopBDB250408163128 Inspector Brian Bixby Inspector Insp Source Related Insp No: INSIDE REEL VALVES: Quantity P/F (Valid for Coil Rigs Only) Remarks: Test Time 5.5 MASP: 1083 Sundry No: 324-662 Control System Response Time (sec) Time P/F Housekeeping:P PTD On Location P Standing Order Posted P Well Sign P Hazard Sec.P Test Fluid W Misc NA Upper Kelly 1 P Lower Kelly 1 P Ball Type 1 P Inside BOP 1 P FSV Misc 0 NA 15 PNo. Valves 1 PManual Chokes 1 PHydraulic Chokes 0 NACH Misc Stripper 0 NA Annular Preventer 1 13 5/8"FP #1 Rams 1 2 7/8" x 5"P #2 Rams 1 Blind Shear P #3 Rams 1 2 7/8" x 5"FP #4 Rams 0 NA #5 Rams 0 NA #6 Rams 0 NA Choke Ln. Valves 1 3 1/8"P HCR Valves 2 3 1/8"P Kill Line Valves 2 3 1/8"P Check Valve 0 NA BOP Misc 0 NA System Pressure P3000 Pressure After Closure P2250 200 PSI Attained P12 Full Pressure Attained P35 Blind Switch Covers:PYES Bottle precharge P Nitgn Btls# &psi (avg)P10@4050 ACC Misc NA0 P PTrip Tank P PPit Level Indicators P PFlow Indicator P PMeth Gas Detector P PH2S Gas Detector 0 NAMS Misc Inside Reel Valves 0 NA Annular Preventer P9 #1 Rams P7 #2 Rams P7 #3 Rams P8 #4 Rams NA0 #5 Rams NA0 #6 Rams NA0 HCR Choke P2 HCR Kill P1 9 9 9 9999 9 9 9 9 9LPR function Annular Function FPAnnular Preventer FP#3 Rams 2 7/8" x 5" 2 1. 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 Other: ESP Swap 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): 19,544 NA Casing Collapse Conductor NA Surface 2,260psi Intermediate 3,090psi Slotted Liner NA 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: Contact Email: Contact Phone: 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 Keith Lopez 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 AOGCC USE ONLY Tubing Grade: Tubing MD (ft):Perforation Depth TVD (ft): STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0388574, ADL0391283 212-068 C.O. 639 NIKAITCHUQ SP33-W03 3800 Centerpoint Dr, Suite 1400 Anchorage, AK 99503 50-629-23480-00-00 Hilcorp Alaska, LLC Length Size Proposed Pools: 3,572 19,527 3,571 1,083 SCHRADER BLUFF OIL SCHRADER BLUFF OIL 160' 160' 12.6# / L-80 TVD Burst 10,309' MD NA NA 10,938' 5,020psi 5,750psi 2,422' 3,589' 3,571' 3,118' 10,973' Slotted Liner 123' 20" 13-3/8" 9-5/8" 3,081' 5-1/2"8,739' Slotted Liner 907-777-8438 keith.lopez@hilcorp.com Operations Manager December 15, 2024 4-1/2" Perforation Depth MD (ft): NIKAITCHUQ SLXP Liner Hanger Packer, six oil swell packers, and NA 10,543' MD/3,566' TVD, see schematic for swell packers, and NA NA 19,527' Form 10-403 Revised 06/2023 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov By Grace Christianson at 2:57 pm, Nov 21, 2024 Digitally signed by Sara Hannegan (2519) DN: cn=Sara Hannegan (2519) Date: 2024.11.21 14:31:55 - 09'00' Sara Hannegan (2519) 324-662 A.Dewhurst 25NOV24 10-404 DSR-11/21/24 X JJL 11/26/24 BOP Test to 3500 psi. VBR must be sized for both 2-7/8" and 4-1/2" pipe. *&: Jessie L. Chmielowski Digitally signed by Jessie L. Chmielowski Date: 2024.11.27 09:09:54 -09'00'11/27/24 RBDMS JSB 112924 Well: SP-33 PTD: 212-068 API: 50-629-23480-00-00 Well Name:SP-33 API Number:50-629-23480-00-00 Current Status:Producer Rig:Doyon 15 Estimated Start Date:12/15/2024 Estimated Duration:9 days Regulatory Contact:Darci Horner Permit to Drill Number:212-068 First Call Engineer:Keith Lopez (907) 777-8438 (O) (907) 903-5432 (M) Second Call Engineer:Sara Hannegan (907) 564-4624 (O) (907) 309-1196 (M) Current Bottom Hole Pressure: 1,400 psi @ 3,570’ TVD |7.5 PPGE Max Potential Surface Pressure: 1,083 psi Gas Column Gradient (0.1 psi/ft) Max Angle: 83° Sail Angle from 3,900’ MD to ESP setting depth of 10,300’ MD Brief Well Summary: SP33 was drilled and completed in July 2012 as a Schrader Bluff OA producer with an ESP completion. A second lateral was added in June 2019. The current ESP ran for 5.4 years before grounding out on 10/11/2024. Objectives: Pull ESP completion, run VAC tool to remove sand from ESP setting depth and 1,000’ into liner top, run new ESP completion. Notes Regarding Wellbore Condition: x Casing test to 1,000 psi passed 5/19/2019. Pre-Rig Procedure (Non Sundried Work) Operations: 1. Bleed off gas cap from IA before the rig move to the well Brief RWO Procedure (Begin Sundried Work) 1. MIRU Doyon 15 WO Rig, ancillary equipment, and lines. 2. Displace corrosion inhibitor from capillary line prior to pulling ESP. 3. Kill well by bullheading the tubing string and the IA. a. Pump 130% tubing volume (203 bbls) of injection water inhibited with biocide. b. Pump 130% annulus volume (575 bbls) of injection water inhibited with biocide. c. Monitor OA annulus during kill. 4. Flow check for 30 min to ensure the well is killed. 5. Install BPV inside tubing hanger as per Vault. 6. Nipple down X-mas tree. 7. Make up blanking plug on top of tubing hanger as per Vault procedure. 8. Nipple up BOP. 9. Run 4-1/2”, and 2-7/8” test joint and engage tubing hanger blanking plug. a. Perform full BOP pressure test to 250/3,500 psi (notify AOGCC 48 hours prior to BOP test). Submit to AOGCC completed 10-424 form within 5 days of BOPE test. 10. Pull 4-1/2” test joint with blanking plug. Well: SP-33 PTD: 212-068 API: 50-629-23480-00-00 11. Pull BPV from the tubing hanger per Vault procedure. 12. Call out Centrilift to pull ESP and pull tubing hanger. 13. RU tubing handling equipment. 14. Pump approximately 10 bbl/hour (+ pipe displacement while pulling pipe) of 8.6 ppg 3% KCl/NaCl brine down the annulus throughout the operations to maintain well fill. 15. POOH with 4-1/2” ESP completion standing back tubing and laying down ESP. Record number of clamps recovered. 16. PU and RIH with Cleanout/VACS assembly as outlined below: 17. RIH to 50’ above the top of liner and mark pipe. RIH to top of liner at 30 fpm (roughly 1 min per joint) using VACS tool. 18. POOH and lay down cleanout/VACS BHA a. Break down BHA capturing sand in containment. Report amount of sand captured in daily report. Inspect and empty washpipe and VACS tool. 19. PU and RIH with 5-1/2” liner cleanout assembly as outlined below: Well: SP-33 PTD: 212-068 API: 50-629-23480-00-00 20. RIH until BHA is approximately 30’ above liner top. Break circulation and record working parameters of VACS. 21. Slowly wash down into liner top and while maintaining operating parameters of the VACS. Wash down till snorkel pipe is 1,800’ into the liner. 22. POOH with VACS cleanout BHA laying down 2-7/8” snorkel pipe and 4-1/2” tubing. a. Break down BHA capturing sand in containment. Report amount of sand captured in daily report. Inspect and empty washpipe and VACS tool. 23. Call Operations Engineer after each cleanout run to discuss sand returns. 24. RIH with new 4-1/2” 12.25# L-80 TK-15XT and ESP completion to +/- 10,309 25. ’ with duel encapsulated capillary strings. a. Check electrical continuity every 1000’. b. Note PU and SO weights on tally. c. Install ESP clamps per Baker, and cross coupling clamps every other joint 26. Land tubing hanger. Use extra caution to not damage cable. 27. Lay down landing joint. 28. Set BPV. 29. ND BOPE and NU tree. 30. Test tubing hanger void to 500 psi low/5,000 psi high. Pull BPV. 31. RDMO Doyon 15. Attachments: 1. Current Wellbore Schematic 2. Proposed Wellbore Schematic 3. BOPE Schematic 4-½” 12.6 THW563 ppf Production TubingHAL 5-½” Oil SwellPackerSP33-W3Dual Lateral Producerwith ESP LiftNikaitchuq Field –Spy IslandAs Completed06/20/2019+/- 10,543' MD, 3,566'TVD – L1 - Baker SLXPLiner Hanger/Packer+/- 10,630'-10,646' MD,3,571'-3,572' TVDCasing Exit Window4-½” x-cplg cable clamps, for ESP Power Cable, (1) 3/8"Chem Inj Line with 2500 psi check valve at bottom10,242' MD, 3,540' TVD - Discharge Gauge Sub10,309' MD, 3,548' TVD, 83.7º Inc – Bottom of Motor Centralizer Centrilift, Conventional ESP, 68 stagesFlex80 SXD + 20 stage GINPSHH SXD, 513 GSB3 seals, 400 HP 562 MSP1 motorSurf. Casing13-3/8", 68 #3,118' MD,2,422' TVD58º Inc. Interm. Casing 9-5/8", 40#10,973' MD, 3,589' TVD 87º Inc.+/- 10,718' MD, 3,574' TVDBaker MLXP LinerHanger/PackerTD 8 3/4”19,544 MD,3,572' TVD 88º Inc.5-½” 15.5 ppf L80Slotted LinerSilver Bullet Ecc. Nose Guide Shoe 19,527' MD, 3,571' TVD, 88º Inc.Silver Bullet Ecc. NoseGuide Closed Shoe +/- 19,520' MD, 3,602'TVD, 90º Inc.TD 8 3/4”+/- 19,581' MD,3,604' TVD90º Inc.5-½” 15.5/17 ppfL80 Slotted LinerSealbore Receptacle4.75" ID+/- 10,615' MD RAM Hanger5.879" Lateral Drift ID4.825" Mainbore Drift ID4-½” x 9-5/8" RAMSeal Bore Diverterw/ 3.64" Seal BoreBottom of SealAssembly4 ½” Lateral EntryModule (LEM) w/ 3.64Seal Bore Resman Oil/WaterTracers10,788' MD, 3,579' TVD –Mainbore Baker SLXPLiner Hanger/PackerL80 Swivel joint 4" ½ 12.6ppfL1 Lateral sectionadded in 201910,630' to 19,581'MD 4-½” 12.6# THW563 Production TubingHAL 5-½” Oil SwellPackerSP33-W3Dual Lateral Producerwith ESP LiftNikaitchuq Field –Spy IslandProposed Nov2024+/- 10,543' MD, 3,566'TVD – L1 - Baker SLXPLiner Hanger/Packer+/- 10,630'-10,646' MD,3,571'-3,572' TVDCasing Exit Window4-½” x-cplg cable clamps, for ESP Power Cable, (2) 3/8"Chem Inj Line with 2500 psi check valve at bottom~10,242' MD, ~3,540' TVD - Discharge Gauge Sub~10,309' MD, ~,548' TVD, 83.7º Inc – Bottom of Motor Centralizer Centrilift,Surf. Casing13-3/8", 68 #3,118' MD,2,422' TVD58º Inc. Interm. Casing 9-5/8", 40#10,973' MD, 3,589' TVD 87º Inc.+/- 10,718' MD, 3,574' TVDBaker MLXP LinerHanger/PackerTD 8 3/4”19,544 MD,3,572' TVD 88º Inc.5-½” 15.5 ppf L80Slotted LinerSilver Bullet Ecc. Nose Guide Shoe 19,527' MD, 3,571' TVD, 88º Inc.Silver Bullet Ecc. NoseGuide Closed Shoe +/- 19,520' MD, 3,602'TVD, 90º Inc.TD 8 3/4”+/- 19,581' MD,3,604' TVD90º Inc.5-½” 15.5/17 ppfL80 Slotted LinerSealbore Receptacle4.75" ID+/- 10,615' MD RAM Hanger5.879" Lateral Drift ID4.825" Mainbore Drift ID4-½” x 9-5/8" RAMSeal Bore Diverterw/ 3.64" Seal BoreBottom of SealAssembly4 ½” Lateral EntryModule (LEM) w/ 3.64Seal Bore Resman Oil/WaterTracers10,788' MD, 3,579' TVD –Mainbore Baker SLXPLiner Hanger/PackerL1 Lateral sectionadded in 201910,630' to 19,581'MD WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. Atm.: Natural Resource Technician 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Cement Bond Log: SP33-W3 Run Date: 5/16/2019 21706un 30874 May 30, 2019 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of Fanny Sari, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 SP33-W3 Digital Data in LAS format, Digital Log Fileii`,Ep 1 CD Rom 50-629-23480-61-00 RE. 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General Information 2. Daily Summary 3. Morning Reports 4. Show Reports 5. Bit Record 6. Mud Record 7. Formation Tops 8. Survey Report 9. Days vs. Depth Digital Data to include: Final Logs Halliburton Log Viewer EMF Log Viewer End of Well Report in PDF format ADI Backup GENERAL WELL INFORMATION Company: Eni Petroleum Rig: Doyon 15 Well: SP33-W3 Field: Nikaitchuq Borough: North Slope Borough State: Alaska Country: United States API Number: 50-629-23480-00-00 Sperry Job Number: AK-AM-0009568240 Job Start Date: 13 Jun 2012 Spud Date: 17 Jun 2012 Total Depth: 19,544’ MD, 3,572’ TVD North Reference: True Declination: 20.468˚ Dip Angle: 81.083˚ Total Field Strength: 57645.744 nT Date Of Magnetic Data: 01 Jul 2012 Wellhead Coordinates N: North 70° 33’ 27.66770” Wellhead Coordinates W: West 149° 54’ 22.37774“ Drill Floor Elevation: 53.920’ Ground Elevation: 13.1’ Permanent Datum: Mean Sea Level SDL Engineers: Emil Opitz, Leigh Ann Rasher, Zachary Beekman Company Geologist: Andrew Buchanan Company Representatives: Jack Keener, Mike Ross SSDS Unit Number: 110 DAILY SUMMARY Begin SP33-W3 06/15/2012 Mudloggers rigged up equipment in the unit to get ready to spud. The rig crew began to load pipe shed with 5” drill pipe. Picked up 5” drill pipe, filled pits with spud mud and pick up tools. 06/16/2012 Continue to pick up 5” drill pipe. Wait for flow back operations on well SP16-FN3. Maintenance and service top drive. Pick up 5” drill pipe and strap 16” BHA in pipe shed. 06/17/2012 Fill conductor and check surface equipment. Make up BHA #1 per Schlumberger. Standby for flow back operations on SP16-FN3. Clean out conductor at 160’ MD. Back ream out of the hole to 43 MD’. Make up BHA #2. Rig up gyro wireline and drill from 219’ MD to 660’ MD. 06/18/2012 Continued to drill 16” surface hole from 660’ MD to 2963’ MD as of midnight. Max gas observed the past 24 hours was 391 units at a depth of 1917’ MD. The average background gas for the day was 97 units. 6/19/2012 Drilled ahead in 16” surface hole from 2963’ MD to 3134’ MD. TD was reached at 0300 hours. Max gas observed the past 24 hours was 86 units at a depth of 3009’ MD. The average background gas was 57 units. Circulate and reciprocate hole clean from 3134’ MD to 2912’ MD. Backreamed out of hole from 2912’ MD to 289’ MD per K&M as well conditions dictate. Lay down BHA #2. 6/20/2012 Lay down BHA #2. Rig up to run 13 3/8” casing in the 16” surface hole. Trouble shoot top drive. Run 13 3/8” casing down to 741’ MD. Work through tight spot at 741’ MD. Continued to run casing from 741’ MD to 3078’ MD and circulate. Make up landing joint & hanger assembly. Land casing shoe at 3118’ MD. Circulate bottoms up and condition mud. Lay down the Franks tools and rig up for cement head. 6/21/2012 Circulate and condition mud for cement job. Performed cement job and bump plug at 4410 strokes. Rig down cement equipment and drain cement from diverter and lines. Set lower riser and nipple up the BOP stack. Rig up to repair top drive. 6/22/2012 Repair top drive assembly and clean mud pits in preparation of LSND mud. Rig up and test choke assembly and choke manifold valves. Rig up BOP bell nipple and flow line. 6/23/2012 Continue to nipple up BOP riser and flow line. Test BOP and the rig down test equipment. Pick up and make up BHA #3 with 12.25” bit. Run in hole and perform shallow hole test at 292’ MD. Run in hole from 292’ MD to 2895’ MD and circulate bottoms up. Rig up and perform a casing test. Drill through cement to shoe at 3118’ MD and 20’ new hole to 3154’ MD. Prepare to displace mud. 6/24/2012 Displace mud to 9.25 ppg LSND. Perform a successful leak off test to 12.6 ppg EMW. Cut and slip drill line. Adjust brakes on the draw works. Drill ahead from 3154’ MD to 4336’ MD as of midnight. Max gas observed the past 24 hours is 108 units at 3351’ MD and the average background gas is 6 units. 6/25/2012 Drill ahead from 4336’ MD to 5162’ MD. Begin to back ream out of the hole due to low rate of penetration. Max gas observed the past 24 hours was 30 units at 4801’ MD. 6/26/2012 Continued to back ream out of the hole from 4944’ MD to 1072’ MD as per K&M. Circulate the hole clean at 1072’ MD and pull out of the hole. Lay down BHA #3 and pick up BHA #4. Run in the hole to 3074’ MD. 6/27/2012 Finished running in the hole with BHA #4. Drill ahead from 5162’ MD to 6900’ MD in the 12.25” intermediate section. Max gas observed the past 24 hours was 13 units at 6889’ MD. 6/28/2012 Continued to drill ahead in the 12.25” intermediate section from 6900’ MD to 7980’ MD. Max gas observed the past 24 hours was 27 units at 7796’ MD. 6/29/2012 Drill ahead from 7980’ MD to 8651’ MD in the 12.25” intermediate section. Begin to pull out of the hole due to Schlumberger Xceed tool failure. Max gas observed while drilling the past 24 hours was 196 units at 8552’ MD. Max trip gas observed was 24 units. 6/30/2012 Back ream out of the hole to 3070’ MD and circulate bottoms up. Continued to pull out of the hole and lay down BHA #4. Pick up BHA #5 and shallow test tools. Begin to run in the hole. 7/1/2012 Finished running in the hole and circulate and condition mud. Drill ahead in the 12.25” intermediate section from 8651’ MD to 9596’ MD. Max gas observed the past 24 hours was 231 units at 9520’ MD. Max trip gas observed was 59 units. 7/2/2012 Drill ahead from 9596’ MD to a TD of 10988’ MD. Begin to back ream out of the hole. Two max gas peaks observed were 3054 units at 10870’ MD and 3095 units at 10937’ MD. 7/3/2012 Continued to back ream out of the hole from 10988’ MD to 3000’ MD. Circulate the hole clean and pull out of the hole. The max trip gas observed the past 24 hours was 176 units. 7/4/2012 Finish pulling out of the hole and lay down BHA #5. Rig up casing tools and pick up shoe track and tested float. Begin to run in hole with 9 5/8” casing. 7/5/2012 Continue to run in hole with 9 5/8” casing. Land casing at 10,973’ MD. Lay down Tesco equipment and rig up cement head. Begin to cement 9 5/8” casing. 7/6/2012 Finish cementing 9 5/8” casing. Lay down cement head, install emergency slips, and pulled wear bushings. Install stack and test pack off, change rams, and test BOP’s. 7/7/2012 Pull out of hole with 5” drill pipe and install WEI subs. Pick up BHA #6 and begin to run in the hole with 4.5” drill pipe to 5,500’ MD. 7/8/2012 Continue to run in the hole with 5” drill pipe to 9647’ MD then reamed to 10,899’ MD. Perform casing test to 3,000 psi for 30 minutes. Displace mud and test WEI system. Drill 22’ of new hole to 11,010’ MD and prepare to perform FIT test. 7/9/2012 Perform FIT test to 13.0 ppg. Drill ahead through 8.75” hole from 11,010’ MD to 12,991’ MD. Max gas observed the past 24 hours was 887 units at 12,304’ MD. 7/10/2012 Continue to drill ahead in the 8.75” production section from 12,912” MD to 14,946’ MD. Max gas observed the past 24 hours was 1781 units at a depth of 13,272’ MD. 7/11/2012 Drill ahead in the 8.75” production section from 14,946’ MD to 16,632’ MD. Max gas observed the past 24 hours was 954 units at a depth of 15,944’ MD. 7/12/2012 Drill ahead in the 8.75” production section from 16,632’ MD to 18,076’ MD. Max gas observed the past 24 hours was 882 units at a depth of 17,382’ MD. 7/13/2012 Continue to drill ahead in the 8.75” hole from 18,076’MD to TD at 19,544’ MD. Max gas observed the past 24 hours was 932 units at a depth of 18,457’ MD. Monitor well, static, and circulate bottoms up and back ream out of the hole per K&M schedule at 530 gpm, 3780 psi, and 135 rpm from 19,544’ MD to 19,250’ MD, racking back one stand per bottoms up. 7/14/2012 Circulate bottoms up and back ream out of the hole per K&M schedule at 540 gpm, 3950 psi, and 135 rpm from 19,250’ MD to 16,732’ MD. Increase to full pump rate of 550 gpm. At 15,630’ MD an increase in torque was observed at 18-24k and pump psi to 3900. Run in hole to 15,962’ MD and re-establish full pump rate at 550 gpm, 3710 psi, and 130 rpm. 7/15/2012 Back ream out of the hole per K&M schedule from 15,673’ MD to last WEI sub on stand #146. Continue to back ream out of the hole to 11,232’ MD and circulate and condition per K&M to 11,139’ MD. Back ream out of hole to 10,765’ MD. Monitor well, static. Back ream out of hole to 8,807’MD, clear rig floor, and change to the 4.5” saver sub on the top drive. 7/16/2012 Change the 4.5” saver sub on the top drive and service the rig. Continue to back ream out of the hole from 8,807’ MD to 1,050’ MD per K&M schedule. Circulate and condition to 1,031’MD and observed shakers were clean. Monitor well, static. Pull out of the hole to 270’ MD and lay down the BHA. Clear the rig floor and rig down WEI sub equipment. 7/17/2012 Continued cleaning the rig floor and changed out the saver sub for the 5” drill pipe. Clean the drip pan and rig up the GBR liner equipment. Run 207 joints of the 5.5” slotted liner per detail. Make up the SLZXP packer and run in the hole with 5” drill pipe to 8,844’ MD. Break circulation at 2.5 bpm and 90 psi. Obtain parameters per K&M and run in the hole to 15,328’ MD. 7/18/2012 Continued running in the hole with the 5.5” slotted liner from 15,328’ MD to 19,527’ MD. No daily losses noted. Drop the ball per detail to set the packer and test. Displace to 9.0 lb/gal brine at 6bpm and 900 psi with 9,000 strokes until clean brine was observed. Cut and slip drill line and begin laying down 5” drill pipe and WEI subs from 10,715’MD to 5,133’ MD. Lay down WEI sub equipment and rack back 5” drill pipe to 4,218’ MD. 7/19/2012 Rack back 5” drill pipe from 4,218’ MD to 3,081” MD. Lay down 5” drill pipe and run in hole with 4.5” drill pipe and lay down. Rig up and test BOP’s per state regulations. 7/20/2012 Continue to test BOP’s. Pull the test plug and clean and clear rig floor to begin rig up of 4.5” tubing equipment. Run in the hole with 4.5” completion tubing per detail to 1,850’ MD. 7/21/2012 Continue running the 4.5” completion tubing per detail from 1,850’ MD to 7,257’ MD. Test ESP cable every 1,000’. Make up the tubing hanger. Splice ESP and injection tube. Clear the rig floor. Nipple down the BOPE stack. Rig up the Vetco tree. Rig up to freeze protect the well as of midnight. 7/22/2012 Mudloggers asked to rig down for rig move. Pumped 155 bbls of diesel at 1 bpm and 100 psi. After running slickline, replace shear valve. Prepare to move the rig to SI25-N2. . . Density (ppg) Viscosity out (sec/qt) Tools ECD (ppg) Avg Min Max SP Motor 1.83, ARC825, Telescope ml/30min RPM mg/l Depth Mud Type YP Cor Solids (lb/100ft 2) Condition Coal Gvl API FL Lst 1 Weight 160' Make 20" 16" Size 1 15-Jun-2012 1/1/1900 0:00 Time: Report #: Date: ENI Petroleum SP33-W3 Spy Island 24 hr Max North Slope Doyon 15 AK-AM-0009568240 Customer: Well: Avg (ppb Eq) cP PV MBT MWD Summary Depth 160' to 160' Sh Clyst Cly (current) Ss Cht Depth in / out Hughes MX-1 Mill Tooth 160' Lithology (%) Silt Siltst Total Charges: P/U BHA Rig Activity: Flow In (spm) $2,810.00 $8,510.00 Report For: Ross/Wimmer/Buchanan 160' 160' 0' Flow In (gpm) ROP (ft/hr) Bit Type TFA pH Hours Current Pump & Flow Data: Chlorides EVAMAR % Yesterday's Depth: Rig: Job No.: Current Depth: 24 Hour Progress: Daily Charges: 96% SPP (psi) Gallons/stroke @4.23 Max @ ft Area: Location: ROP Set At Size 178.9 X-65 Bit # Current in Footage WOB Mud Data Casing Summary Grade Tuff * 10000 units = 100% Gas In Air Trip 907-685-0772 Unit Phone: 24 hr Recap: Background 0 0 0 00 0 Maximum 0 Depth Units* 0 0 0 Rig Up equipment. Load pipeshed with 5" DP. P/U 5" DP. Fill pits with spud mud. P/U tools. md. Minimum Average Chromatograph (ppm) 00 0 0 00 C-4i 0 Logging Engineers: Emil Opitz / Matt Smith (max) (current) Report By: Matt Smith C-3 0 C-4n Gas Summary C-2 Connection (max) C-5n C-5i C-1 000 . . Density (ppg) Viscosity out (sec/qt) Tuff Mud Data Casing Summary Grade ROP Set At Size 178.9 X-65 Bit # Current in Footage WOB Area: Location: Max @ ft @4.23 Rig: Job No.: Current Depth: 24 Hour Progress: Daily Charges: 96% SPP (psi) Gallons/stroke % Chlorides EVAMAR ROP (ft/hr) Bit Type TFA pH Flow In (gpm) Hours $11,320.00 Report For: Ross/Wimmer/Buchanan 160' 160' 0' Current Pump & Flow Data: Yesterday's Depth: Silt Siltst Total Charges: Strap BHA Rig Activity: Flow In (spm) $2,810.00 Cht Depth in / out Hughes MX-1 Mill Tooth 160' Lithology (%) Ss Sh Clyst Cly (ppb Eq) cP PV MBT MWD Summary Depth 160' to 160' ENI Petroleum SP33-W3 Spy Island 24 hr Max North Slope Doyon 15 AK-AM-0009568240 Customer: Well: Avg 2 16-Jun-2012 24:00 Time: Report #: Date: Size Make 20" 16" (current) Weight 160' Lst 1 YP Cor Solids (lb/100ft 2) Condition Depth Mud Type ml/30min RPM mg/l Coal Gvl API FL Tools ECD (ppg) Avg Min Max SP Motor 1.83, ARC825, Telescope * 10000 units = 100% Gas In Air Connection (max) C-5n C-5i C-1 000 Gas Summary C-2 Matt Smith C-3 0 Logging Engineers: Emil Opitz / Matt Smith (max) (current) Report By: 0 0 Chromatograph (ppm) 00 0 0 Minimum C-4i topdrive. Pick up 5" DP. Strap 16" BHA in pipe shed at time of report. Continue to pick up 5" DP. Wait for flow back operations to complete on well SP16-FN3. Maintenance and service md. Average 0 0 0 C-4n 0 0 Depth Units* 0 0000 0 Maximum 907-685-0772 Unit Phone: 24 hr Recap: Background Trip . . Density (ppg) Viscosity out (sec/qt) Tools ECD (ppg) Avg Min Max SP Motor 1.83, ARC825, Telescope ml/30min RPM mg/l Coal Gvl API FL 5.4 Gel Mud Depth Mud Type 87 Cor Solids (lb/100ft 2) 2,400 9.60 Condition 565' YP 1 9.00 Weight 160' Make 20" 16" (current) 9.00 17.5 31 29 Size 3 17-Jun-2012 24:00 Time: Report #: Date: ENI Petroleum SP33-W3 Spy Island 24 hr Max North Slope Doyon 15 AK-AM-0009568240 Customer: Well: Avg PV MBT MWD Summary Depth 160' to 660' Sh Clyst Cly Ss Cht Depth in / out Hughes MX-1 Mill Tooth 160' Lithology (%) Total Charges: 4.0 Drilling 16" Hole Rig Activity: Flow In (spm) 991.1 $2,810.00 (ppb Eq) cP $14,130.00 Report For: Ross/Wimmer/Buchanan 123.2 160' 660' 500' Current Pump & Flow Data: 404' Yesterday's Depth: Flow In (gpm) Hours ROP (ft/hr) Bit Type TFA pH Chlorides EVAMAR % Rig: Job No.: Current Depth: 24 Hour Progress: Daily Charges: 96% 603 143 SPP (psi) Gallons/stroke 793 @4.23 285.3 Max @ ft Area: Location: ROP Set At Size 178.9 X-65 Bit # Current in Footage WOB Mud Data Casing Summary Grade Tuff Silt Siltst Lst * 10000 units = 100% Gas In Air Trip 907-685-0772 Unit Phone: N/A 24 hr Recap: 3Background Maximum 0 0 000 0 0 Depth Units* 05 0 0 C-4n out conductor @ 160'MD. Drill to 291'MD. BROOH to 43'. M/U BHA #2, R/U gyro wireline. Drill from 291'MD to 660'MD. Fill Conductor and check surface equipment. M/U BHA #1 per SLB. Standby for flowback operations on SP16-FN3. Clean 2 md. Average 0Minimum C-4i 652' 160' Chromatograph (ppm) 00 0 0 28 0 168 Logging Engineers: Emil Opitz / Matt Smith (max) (current) Report By: Matt Smith C-3 0 Gas Summary C-2 Connection (max) N/A C-5n C-5i C-1 000 . . Density (ppg) Viscosity out (sec/qt) 10.30 Tools ECD (ppg) Avg Min Max SP Motor 1.83, ARC825, Telescope 10.30 ml/30min RPM mg/l 10.30 Coal Gvl API FL 4.7 Gel Mud Depth Mud Type 101 Cor Solids (lb/100ft 2) 1,900 9.10 Condition Chlorides 2710' YP 1 9.00 Weight 160' Make 20" 16" (current) 21.0 37 31 Size 4 18-Jun-2012 24:00 Time: Report #: Date: ENI Petroleum SP33-W3 Spy Island 24 hr Max North Slope Doyon 15 AK-AM-0009568240 Customer: Well: Avg PV MBT MWD Summary Depth 660' to 2963' Sh Clyst Cly Ss Cht Depth in / out Hughes MX-1 Mill Tooth 160' Lithology (%) Total Charges: 6.5 Drilling 16" Hole Rig Activity: Flow In (spm) 1123.0 $2,810.00 (ppb Eq) cP $16,940.00 Report For: Ross/Wimmer/Buchanan 164.0 660' 2963' 2303' Current Pump & Flow Data: 665' Yesterday's Depth: Flow In (gpm) Hours ROP (ft/hr) Bit Type TFA pH EVAMAR % Rig: Job No.: Current Depth: 24 Hour Progress: Daily Charges: 96% 635 148 SPP (psi) Gallons/stroke 1209 @4.23 102.7 Max @ ft Area: Location: ROP Set At Size 178.9 X-65 Bit # Current in Footage WOB Mud Data Casing Summary Grade Tuff Silt Siltst Lst * 10000 units = 100% Gas In Air Trip 907-685-0772 Unit Phone: N/A 24 hr Recap: 97 Background Maximum 0 0 000 0 0 Depth Units* 2391 0 0 C-4n MD. Drill 16" surface hole from 660' MD to 2963' MD. Max gas observed the past 24 hours was 391 units at a depth of 1917' 93 md. Average 0Minimum C-4i 1917' 670' Chromatograph (ppm) 00 0 0 10281 3 50035 Logging Engineers: Emil Opitz / Leigh Ann Rasher (max) (current) Report By: Leigh Ann Rasher C-3 0 Gas Summary C-2 Connection (max) N/A C-5n C-5i C-1 0092 . . Density (ppg) Viscosity out (sec/qt) Tuff Silt Siltst Lst Mud Data Casing Summary Grade ROP Set At Size 178.9 X-65 Bit # Current in Footage WOB Area: Location: Max @ ft @4.23 Rig: Job No.: Current Depth: 24 Hour Progress: Daily Charges: 96% SPP (psi) Gallons/stroke % EVAMAR ROP (ft/hr) Bit Type TFA pH Flow In (gpm) Hours $19,750.00 Report For: Keener/Wimmer/Buchanan 108.9 2963' 3134' 171' Current Pump & Flow Data: 3052' Yesterday's Depth: Total Charges: 6.5 L/D BHA Rig Activity: Flow In (spm) 874.1 $2,810.00 (ppb Eq) cP Cht Depth in / out Hughes MX-1 Mill Tooth 160' Lithology (%) Ss Sh Clyst Cly PV MBT MWD Summary Depth 2963' to 3134' ENI Petroleum SP33-W3 Spy Island 24 hr Max North Slope Doyon 15 AK-AM-0009568240 Customer: Well: Avg 5 19-Jun-2012 24:00 Time: Report #: Date: 19.0 26 22 Size 20" 16" (current) Weight 160' Make 3134' YP 1 9.50 Cor Solids (lb/100ft 2) 1,400 9.80 Condition Chlorides Gel Mud Depth Mud Type 65 ml/30min RPM mg/l Coal Gvl API FL 4.8 Tools ECD (ppg) Avg Min Max SP Motor 1.83, ARC825, Telescope * 10000 units = 100% Gas In Air Connection (max) N/A C-5n C-5i C-1 005292 Gas Summary C-2 Leigh Ann Rasher C-3 0 Logging Engineers: Emil Opitz / Leigh Ann Rasher (max) (current) Report By: 6908 43 10212 Chromatograph (ppm) 00 0 0 Minimum C-4i 3009' 3079' MD. Circ & recip hole clean. BROOH per K&M as well conditions dictate. L/D BHA #2. Drill 16" surface hole from 2963' MD to 3134' MD. Max gas observed the past 24 hours was 86 units at a depth of 3009' 57 md. Average 0 0 0 C-4n 86 0 0 Depth Units* 0 0000 0 Maximum 907-685-0772 Unit Phone: 64 24 hr Recap: N/A Background Trip . . Density (ppg) Viscosity out (sec/qt) Tools ECD (ppg) Avg Min Max SP Motor 1.83, ARC825, Telescope ml/30min RPM mg/l Coal Gvl API FL Gel Mud Depth Mud Type 73 1-1-WT-A-E-I-BU-TD Cor Solids (lb/100ft 2) 9.00 Condition 40.0 Chlorides 3134' YP 2 9.50 Weight 291' 3134' 2843' Make 20" 16" (current) 17.20 23 1.117 28 Size 6 20-Jun-2012 24:00 Time: Report #: Date: ENI Petroleum SP33-W3 Spy Island 24 hr Max North Slope Doyon 15 AK-AM-0009568240 Customer: Well: Avg PV MBT MWD Summary Depth 3134' to 3134' Sh Clyst Cly Ss Cht Depth in / out Hughes MX-1 Mill Tooth 160' Lithology (%) Total Charges: R/U Cement Rig Activity: Flow In (spm) $2,810.00 (ppb Eq) cP $22,560.00 Report For: Keener/Wimmer/Buchanan 3134' 3134' 0' Current Pump & Flow Data: Yesterday's Depth: Flow In (gpm) Hours ROP (ft/hr) Bit Type TFA pH EVAMAR % Rig: Job No.: Current Depth: 24 Hour Progress: Daily Charges: 96% SPP (psi) Gallons/stroke @4.23 Max @ ft 30.0 Area: Location: ROP Set At Size 178.9 X-65 Bit # Current in Footage WOB Mud Data Casing Summary Grade Tuff Silt Siltst Lst * 10000 units = 100% Gas In Air Trip 907-685-0772 Unit Phone: 42 24 hr Recap: N/A Background Maximum 0 0 000 0 0 Depth Units* 0 0 0 C-4n to 1900' MD and circ. M/U landing joint & hanger assembly. Land casing at 3078' MD. Circ B/U & condition mud. R/U cement head. L/D BHA #2. R/U 13-3/8" casing. Trouble shoot top drive. Run 13 3/8" casing. Work through tight spot at 741' MD. RIH md. Average 0Minimum C-4i Chromatograph (ppm) 00 0 0 0 0 Logging Engineers: Emil Opitz / Leigh Ann Rasher (max) (current) Report By: Leigh Ann Rasher C-3 0 Gas Summary C-2 Connection (max) N/A C-5n C-5i C-1 000 . . Density (ppg) Viscosity out (sec/qt) Tuff Silt Siltst Lst Mud Data Casing Summary Grade ROP Set At Size 178.9 X-65 Bit # Current in Footage WOB Area: Location: Max @ ft 30.0 @4.23 Rig: Job No.: Current Depth: 24 Hour Progress: Daily Charges: 96% SPP (psi) Gallons/stroke % EVAMAR ROP (ft/hr) Bit Type TFA pH Flow In (gpm) Hours $25,370.00 Report For: Keener/Wimmer/Buchanan 3134' 3134' 0' Current Pump & Flow Data: Yesterday's Depth: Total Charges: Work on top drive Rig Activity: Flow In (spm) $2,810.00 (ppb Eq) cP Cht Depth in / out Hughes MX-1 Mill Tooth 160' Lithology (%) Ss Sh Clyst Cly PV MBT MWD Summary Depth 3134' to 3134' ENI Petroleum SP33-W3 Spy Island 24 hr Max North Slope Doyon 15 AK-AM-0009568240 Customer: Well: Avg 7 21-Jun-2012 24:00 Time: Report #: Date: 17.20 14 1.117 22 Size 20" 16" (current) Weight 291' 3134' 2843' Make 3134' YP 2 9.50 1-1-WT-A-E-I-BU-TD Cor Solids (lb/100ft 2) 8.30 Condition 40.0 Chlorides Gel Mud Depth Mud Type 54 ml/30min RPM mg/l Coal Gvl API FL Tools ECD (ppg) Avg Min Max SP Motor 1.83, ARC825, Telescope * 10000 units = 100% Gas In Air Connection (max) N/A C-5n C-5i C-1 000 Gas Summary C-2 Leigh Ann Rasher C-3 0 Logging Engineers: Emil Opitz / Leigh Ann Rasher (max) (current) Report By: 0 0 Chromatograph (ppm) 00 0 0 Minimum C-4i 10 bbl H2O. Chase with 442 bbls 9.5 lb/gal spud mud. Bump plug @ 4410 stks. R/D cement job. L/D tools & equipment. R/U to Circ & condition mud for cement job. Pump 100 bbls 10.1 lb/gal MudPush, 496 bbl lead cement, 67 bbl tail cement & md. Average 0 0 0 C-4n repair top drive. R/U BOP stack. 0 0 Depth Units* 0 0000 0 Maximum 907-685-0772 Unit Phone: N/A 24 hr Recap: N/A Background Trip . . Density (ppg) Viscosity out (sec/qt) Tuff Silt Siltst Lst Mud Data Casing Summary Grade L-80 ROP Set At Size 178.9 X-65 Bit # Current in Footage WOB Area: Location: Max @ ft 30.0 @4.23 Rig: Job No.: Current Depth: 24 Hour Progress: Daily Charges: 96% SPP (psi) Gallons/stroke % BTC EVAMAR ROP (ft/hr) Bit Type TFA pH Flow In (gpm) Hours $28,480.00 Report For: Keener/Wimmer/Buchanan 3134' 3134' 0' Current Pump & Flow Data: Yesterday's Depth: Total Charges: Nipple up BOP's Rig Activity: Flow In (spm) $3,110.00 (ppb Eq) cP Cht Depth in / out Hughes MX-1 Mill Tooth 160' 3118' Lithology (%) Ss Sh Clyst Cly PV MBT MWD Summary Depth 3134' to 3134' ENI Petroleum SP33-W3 Spy Island 24 hr Max North Slope Doyon 15 AK-AM-0009568240 Customer: Well: Avg 8 22-Jun-2012 24:00 Time: Report #: Date: 17.20 13 1.117 22 Size 20" 13 3/8" 16" (current) 68.0 Weight 291' 3134' 2843' Make 3134' YP 2 9.50 1-1-WT-A-E-I-BU-TD Cor Solids (lb/100ft 2) 8.30 Condition 40.0 Chlorides Gel Mud Depth Mud Type 52 ml/30min RPM mg/l Coal Gvl API FL Tools ECD (ppg) Avg Min Max SP Motor 1.83, ARC825, Telescope * 10000 units = 100% Gas In Air Connection (max) N/A C-5n C-5i C-1 000 Gas Summary C-2 Leigh Ann Rasher C-3 0 Logging Engineers: Emil Opitz / Leigh Ann Rasher (max) (current) Report By: 0 0 Chromatograph (ppm) 00 0 0 Minimum C-4i Repair top drive assembly. R/U BOP stack. Test choke assembly. Nipple up BOP riser and flow line. md. Average 0 0 0 C-4n 0 0 Depth Units* 0 0000 0 Maximum 907-685-0772 Unit Phone: N/A 24 hr Recap: N/A Background Trip . . Density (ppg) Viscosity out (sec/qt) Tools ECD (ppg) Avg Min Max Xceed 900, ARC825, Telescope ml/30min RPM mg/l Coal Gvl API FL LSND Depth Mud Type 43 1-1-WT-A-E-I-BU-TD Cor Solids (lb/100ft 2) 10.10 Condition 40.0 Chlorides 12.25 1.167 3134' YP 2 3 Smith MDSi716 PDC 9.30 Weight 291' 3134' 2843' Make 20" 13 3/8" 16" (current) 68.0 17.20 11 1.117 22 Size 9 23-Jun-2012 24:00 Time: Report #: Date: ENI Petroleum SP33-W3 Spy Island 24 hr Max North Slope Doyon 15 AK-AM-0009568240 Customer: Well: Avg PV MBT MWD Summary Depth 3134' to 3154' Sh Clyst Cly Ss Cht Depth in / out Hughes MX-1 Mill Tooth 160' 3118' Lithology (%) Total Charges: Prep to displace Rig Activity: Flow In (spm) 202.5 $3,410.00 (ppb Eq) cP $32,890.00 Report For: Keener/Wimmer/Buchanan 21.2 3134' 3154' 20' Current Pump & Flow Data: 3147' Yesterday's Depth: Flow In (gpm) Hours ROP (ft/hr) Bit Type TFA pH EVAMAR % BTC Rig: Job No.: Current Depth: 24 Hour Progress: Daily Charges: 96% SPP (psi) Gallons/stroke @4.23 Max @ ft 30.0 Area: Location: ROP Set At Size 178.9 X-65 Bit # Current in Footage WOB Mud Data Casing Summary Grade L-80 Tuff Silt Siltst Lst * 10000 units = 100% Gas In Air Trip 907-685-0772 Unit Phone: 3 24 hr Recap: N/A Background Maximum 0 0 000 0 0 Depth Units* 0 hole to 3154" MD. Prepare to displace mud. 0 0 C-4n 2895' MD. R/U and perform casing test. Wash & ream to FC @ 3026' MD. Drill through cement to shoe @ 3117" MD and 20 " new Nipple up BOP riser & flow line. Test BOP. R/D test equip. P/U BHA #3 & M/U 12.25" bit. Shallow hole test tools. RIH to md. Average 0Minimum C-4i Chromatograph (ppm) 00 0 0 0 0 Logging Engineers: Emil Opitz / Leigh Ann Rasher (max) (current) Report By: Leigh Ann Rasher C-3 0 Gas Summary C-2 Connection (max) N/A C-5n C-5i C-1 000 . . Density (ppg) Viscosity out (sec/qt) Tuff Silt Siltst Lst Mud Data Casing Summary Grade L-80 ROP Set At Size 178.9 X-65 Bit # Current in Footage WOB Area: Location: Max @ ft 30.0 1295 @4.23 52.6 Rig: Job No.: Current Depth: 24 Hour Progress: Daily Charges: 96% 802 97 SPP (psi) Gallons/stroke % BTC EVAMAR ROP (ft/hr) Bit Type TFA pH Flow In (gpm) Hours $36,300.00 Report For: Keener/Wimmer/Buchanan 108.5 3154' 4336' 1182' Current Pump & Flow Data: 3290' Yesterday's Depth: Total Charges: 4.5 Drill 12.25" Hole Rig Activity: Flow In (spm) 663.2 $3,410.00 (ppb Eq) cP Cht Depth in / out Hughes MX-1 Mill Tooth 160' 3118' Lithology (%) Ss 60 40 Sh Clyst Cly PV MBT MWD Summary Depth 3154' to 4336' ENI Petroleum SP33-W3 Spy Island 24 hr Max North Slope Doyon 15 AK-AM-0009568240 Customer: Well: Avg 10 24-Jun-2012 24:00 Time: Report #: Date: 17.20 5.5 27 1.117 11 Size 20" 13 3/8" 16" (current) 68.0 Weight 291' 3134' 2843' 3134' Make 12.25" 1.167 4193' YP 2 3 Smith MDSi716 PDC 9.20 1-1-WT-A-E-I-BU-TD Cor Solids (lb/100ft 2) 700 10.30 Condition 40.0 Chlorides LSND Depth Mud Type 55 ml/30min RPM mg/l 9.44 Coal Gvl API FL 5.6 9.94 Tools ECD (ppg) Avg Min Max Xceed 900, ARC825, Telescope 9.67 * 10000 units = 100% Gas In Air Connection (max) N/A C-5n C-5i C-1 0027 Gas Summary C-2 Leigh Ann Rasher C-3 0 Logging Engineers: Emil Opitz / Leigh Ann Rasher (max) (current) Report By: 2768 3 12201 Chromatograph (ppm) 00 0 0 Minimum C-4i 3351' 4245' 3154" MD to 4336" MD. Clays/sand blind off screens; shaker runoff. Max gas observed past 24 hrs is 108 units. Displace mud to 9.25 lb/gal. FIT/LOT to 12.6 lb/gal EMW. Cut & slip drill line. Adjust brakes on drawworks. Drill from 28 md. Average 0 0 0 C-4n 108 0 0 Depth Units* 0 0000 0 Maximum 907-685-0772 Unit Phone: N/A 24 hr Recap: 6Background Trip . . Density (ppg) Viscosity out (sec/qt) Tuff Silt Siltst Lst Mud Data Casing Summary Grade L-80 ROP Set At Size 178.9 X-65 Bit # Current in Footage WOB Area: Location: Max @ ft 30.0 1752 @4.23 Rig: Job No.: Current Depth: 24 Hour Progress: Daily Charges: 96% 909 213 SPP (psi) Gallons/stroke % BTC EVAMAR ROP (ft/hr) Bit Type TFA pH Flow In (gpm) Hours $39,710.00 Report For: Keener/Wimmer/Buchanan 59.7 4336' 5162' 826' Current Pump & Flow Data: 5118' Yesterday's Depth: Total Charges: 4.5 BROOH Rig Activity: Flow In (spm) 982.3 $3,410.00 (ppb Eq) cP Cht Depth in / out Hughes MX-1 Mill Tooth 160' 3118' Lithology (%) Ss 80 20 Sh Clyst Cly PV MBT MWD Summary Depth 4336' to 5162' ENI Petroleum SP33-W3 Spy Island 24 hr Max North Slope Doyon 15 AK-AM-0009568240 Customer: Well: Avg 11 25-Jun-2012 24:00 Time: Report #: Date: 17.20 12.0 33 1.117 15 Size 20" 13 3/8" 16" (current) 68.0 Weight 291' 3134' 2843' 3134' Make 12.25" 1.167 5161' YP 2 3 Smith MDSi716 PDC 9.20 1-1-WT-A-E-I-BU-TD Cor Solids (lb/100ft 2) 950 9.60 Condition 40.0 Chlorides LSND Depth Mud Type 58 ml/30min RPM mg/l 9.41 Coal Gvl API FL 4.5 10.05 Tools ECD (ppg) Avg Min Max Xceed 900, ARC825, Telescope 9.76 * 10000 units = 100% Gas In Air Connection (max) N/A C-5n C-5i C-1 00342 Gas Summary C-2 Leigh Ann Rasher C-3 0 Logging Engineers: Emil Opitz / Leigh Ann Rasher (max) (current) Report By: 1011 3 3352 Chromatograph (ppm) 00 0 0 Minimum C-4i 4801' 4635' Drill ahead from 4336' MD to 5162' MD. BROOH due to low ROP. Max gas of 30 units observed at 4801' MD. 14 md. Average 0 0 0 C-4n 30 Note: Mag and non-mag metal shavings found in samples. 0 0 Depth Units* 0 0010 0 Maximum 907-685-0772 Unit Phone: 10 24 hr Recap: 3Background Trip . . Density (ppg) Viscosity out (sec/qt) 5162' 2028' 15 150 4-6-BT-S-X-2-RO-ROP 3 Smith MDSi716 PDC 12.25" 1.167 26.50 3134' Tools ECD (ppg) Avg Min Max Xceed 900, ARC825, Telescope 825 ml/30min RPM mg/l Coal Gvl API FL 4.6 LSND Depth Mud Type 58 1-1-WT-A-E-I-BU-TD Cor Solids (lb/100ft 2) 900 9.80 Condition 40.0 Chlorides 12.25" 1.116 5161' YP 2 4 Smith GF15B Insert 9.20 Weight 291' 3134' 2843' 5162' Make 20" 13 3/8" 16" (current) 68.0 17.20 14.0 28 1.117 15 Size 12 26-Jun-2012 24:00 Time: Report #: Date: ENI Petroleum SP33-W3 Spy Island 24 hr Max North Slope Doyon 15 AK-AM-0009568240 Customer: Well: Avg PV MBT MWD Summary Depth 5162' to 5162' Sh Clyst Cly Ss Cht Depth in / out Hughes MX-1 Mill Tooth 160' 3118' Lithology (%) Total Charges: 4.8 RIH BHA#4 Rig Activity: Flow In (spm) $4,410.00 (ppb Eq) cP $44,120.00 Report For: Keener/Wimmer/Buchanan 5162' 5162' 0' Current Pump & Flow Data: Yesterday's Depth: Flow In (gpm) Hours ROP (ft/hr) Bit Type TFA pH EVAMAR % BTC Rig: Job No.: Current Depth: 24 Hour Progress: Daily Charges: 96% SPP (psi) Gallons/stroke @4.23 Max @ ft 30.0 Area: Location: ROP Set At Size 178.9 X-65 Bit # Current in Footage WOB Mud Data Casing Summary Grade L-80 Tuff Silt Siltst Lst *10000 units = 100% Gas In Air Trip 907-685-0772 Unit Phone: 5 24 hr Recap: N/A Background Maximum 0 0 000 0 0 Depth Units* 0 0 0 C-4n 3074' MD. BROOH from 4944' MD to 1072' MD per K&M. Circ hole clean at 1072' MD. POOH. L/D BHA #3. P/U BHA #4. RIH to md. Average 0Minimum C-4i Chromatograph (ppm) 00 0 0 0 0 Logging Engineers: Emil Opitz / Leigh Ann Rasher (max) (current) Report By: Leigh Ann Rasher C-3 0 Gas Summary C-2 Connection (max) N/A C-5n C-5i C-1 000 . . Density (ppg) Viscosity out (sec/qt) 2028' 15 150 4-6-BT-S-X-2-RO-ROP 3 Smith MDSi716 PDC 12.25" 1.167 26.50 10.23 ml/30min RPM 5162' ECD (ppg) Avg Min Max Xceed 900, ARC825, Telescope 825 9.94 mg/l 9.58 Coal Gvl API FL 4.4 1-1-WT-A-E-I-BU-TD Cor Solids Chlorides LSND Depth Mud Type 57 1,100 9.50 Condition 40.0 12.25" 1.116 6717' YP 2 4 Smith GF15B Insert 9.30 (lb/100ft 2) Weight 291' 3134' 2843' 5162' Make 3134' 20" 13 3/8" 16" (current) 68.0 17.20 16.0 34 1.117 15 Size 13 27-Jun-2012 24:00 Time: Report #: Date: ENI Petroleum SP33-W3 Spy Island 24 hr Max North Slope Doyon 15 AK-AM-0009568240 Customer: Well: Avg PV MBT MWD Summary Depth 5162' to 6900' Tools 10 Sh Clyst Cly Ss 90 Cht Depth in / out Hughes MX-1 Mill Tooth 160' 3118' Lithology (%) Total Charges: 5.2 Drill 12.25" hole Rig Activity: Flow In (spm) 875.6 $4,410.00 (ppb Eq) cP $48,530.00 Report For: Keener/Smith/Buchanan 80.6 5162' 6900' 1738' Current Pump & Flow Data: 5282' Yesterday's Depth: Flow In (gpm) Hours ROP (ft/hr) Bit Type TFA pH EVAMAR % BTC Rig: Job No.: Current Depth: 24 Hour Progress: Daily Charges: 96% 948 224 SPP (psi) Gallons/stroke 2061 @4.23 875.6 Max @ ft 30.0 Area: Location: ROP Set At Size 178.9 X-65 Bit # Current in Footage WOB Mud Data Casing Summary Grade L-80 Tuff Silt Siltst Lst *10000 units = 100% Gas In Air 13 Trip 907-685-0772 Unit Phone: N/A 24 hr Recap: 4Background Maximum 0 0 000 Depth Units* 0 Gas Summary C-2 0 0 C-4n 0 past 24 hours was 13 units at 6889' MD. Finished RIH with BHA #4. Drill ahead from 5162' MD to 6900' MD in 12.25" intermediate hole. Max gas observed the 6 md. Average 0Minimum C-4i 6880' 5699' Chromatograph (ppm) 00 0 0 249 3 1027 Logging Engineers: Kori Jo Anderson / Leigh Ann Rasher (max) (current) Report By: Leigh Ann Rasher C-3 0 Connection (max) N/A C-5n C-5i C-1 0076 0 . . Density (ppg) Viscosity out (sec/qt) Lst Mud Data Casing Summary Grade L-80 ROP Set At Size 178.9 X-65 Bit # Current in Footage WOB Area: Location: Max @ ft 30.0 @4.23 3.0 Tuff Rig: Job No.: Current Depth: 24 Hour Progress: Daily Charges: 96% 893 211 SPP (psi) Gallons/stroke % BTC Silt Siltst ROP (ft/hr) Bit Type TFA pH Flow In (gpm) Hours EVAMAR 1958 $51,940.00 Report For: Keener/Smith/Buchanan 63.4 6900' 7980' 1080' Current Pump & Flow Data: 7866' Yesterday's Depth: Total Charges: 5.6 Drill 12.25" hole Rig Activity: Flow In (spm) 749.0 $3,410.00 (ppb Eq) cP Depth in / out Hughes MX-1 Mill Tooth 160' 3118' Lithology (%) Ss 100 Cht Sh Clyst Cly PV MBT MWD Summary Depth 6900' to 7980' Tools ENI Petroleum SP33-W3 Spy Island 24 hr Max North Slope Doyon 15 AK-AM-0009568240 Customer: Well: Avg 14 28-Jun-2012 24:00 Time: Report #: Date: 17.20 15.5 29 1.117 16 Size 20" 13 3/8" 16" (current) 68.0 Weight 291' 3134' 2843' 5162' Make 3134' 12.25" 1.116 7900' YP 2 4 Smith GF15B Insert 9.30 (lb/100ft 2) 1,500 9.70 Condition 40.0 LSND Depth Mud Type 59 mg/l 9.89 Coal Gvl API FL 4.6 1-1-WT-A-E-I-BU-TD Cor Solids Chlorides ECD (ppg) Avg Min Max Xceed 900, ARC825, Telescope 825 10.06 10.27 ml/30min RPM 5162' 2028' 15 150 4-6-BT-S-X-2-RO-ROP 3 Smith MDSi716 PDC 12.25" 1.167 26.50 *10000 units = 100% Gas In Air (max) N/A C-5n C-5i C-1 0049 0 Connection Leigh Ann Rasher C-3 0 Logging Engineers: Kori Jo Anderson / Leigh Ann Rasher (max) (current) Report By: 783 3 2842 Chromatograph (ppm) 00 0 0 Minimum C-4i 7796' 7425' at 7796' MD. Drill ahead from 6900' MD to 7980' MD in 12.25" intermediate hole. Max gas observed the past 24 hours was 27 units 12 md. Average 0 0 C-4n 0 Gas Summary C-2 0 0 Depth Units* 0000 0 Maximum 907-685-0772 Unit Phone: N/A 24 hr Recap: 3Background Note: Mag & non mag metal shaving found in samples from 7850' MD & 7900' MD. 27 Trip . . Density (ppg) Viscosity out (sec/qt) 15 150 4-6-BT-S-X-2-RO-ROP 3 Smith MDSi716 PDC 12.25" 1.167 26.50 10.33 ml/30min RPM 5162' ECD (ppg) Avg Min Max Xceed 900, ARC825, Telescope 825 9.98 mg/l 9.77 Coal Gvl API FL 4.5 1-1-WT-A-E-I-BU-TD Cor Solids Chlorides LSND Depth Mud Type 59 1,500 9.60 Condition 40.0 12.25" 1.116 8651' YP 2 4 Smith GF15B Insert 9.30 (lb/100ft 2) 291' 3134' 2843' 5162' Make 3134' 2028' 13 3/8" 16" (current) 68.0 Weight 17.20 16.0 28 1.117 17 Size 15 29-Jun-2012 24:00 Time: Report #: Date: ENI Petroleum SP33-W3 Spy Island 24 hr Max North Slope Doyon 15 AK-AM-0009568240 Customer: Well: Avg PV MBT MWD Summary Depth 7980' to 8651' Tools Sh Clyst Cly 40 60 Cht Depth in / out Hughes MX-1 Mill Tooth 160' 3118' Lithology (%) Ss 20" Total Charges: 5.2 BROOH Rig Activity: Flow In (spm) 984.2 $3,410.00 (ppb Eq) cP $55,350.00 Report For: Keener/Smith/Buchanan 53.5 7980' 8651' 671' Current Pump & Flow Data: 8572' Yesterday's Depth: Flow In (gpm) Hours EVAMAR 1994 ROP (ft/hr) Bit Type TFA pH Silt Siltst % BTC Rig: Job No.: Current Depth: 24 Hour Progress: Daily Charges: 96% 901 213 SPP (psi) Gallons/stroke @4.23 Tuff Max @ ft 30.0 Area: Location: ROP Set At Size 178.9 X-65 Bit # Current in Footage WOB Mud Data Casing Summary Grade L-80 Lst *10000 units = 100% Gas In Air 168 Trip 907-685-0772 Unit Phone: 24 24 hr Recap: N/A Background Maximum 0 0 000 Depth Units* Gas Summary C-2 C-4n 0 0 observed the past 24 hours was 168 units at 8552' MD. Drill ahead from 7980' MD to 8651' MD in 12.25" intermediate hole. POOH due to SLB Xceed tool failure. Max gas 23 md. Average 0Minimum C-4i 8552' 8008' Chromatograph (ppm) 00 0 0 1862 5 20516 Logging Engineers: Kori Jo Anderson / Leigh Ann Rasher (max) (current) Report By: Leigh Ann Rasher C-3 0 Connection 0 0 (max) N/A C-5n C-5i C-1 00100 0 . . Density (ppg) Viscosity out (sec/qt) 5 Hycalog M4685CP Mill Tooth 12.25" 1.116 8651' Lst Mud Data Casing Summary Grade L-80 ROP Set At Size 178.9 X-65 Bit # Current in Footage WOB Area: Location: Max @ ft 30.0 @4.23 Tuff Rig: Job No.: Current Depth: 24 Hour Progress: Daily Charges: 96% SPP (psi) Gallons/stroke % BTC Silt Siltst ROP (ft/hr) Bit Type TFA pH Flow In (gpm) Hours EVAMAR $58,760.00 Report For: Keener/Smith/Buchanan 8651' 8651' 0' Current Pump & Flow Data: Yesterday's Depth: Total Charges: 5.8 RIH Rig Activity: Flow In (spm) $3,410.00 (ppb Eq) cP Depth in / out Hughes MX-1 Mill Tooth 2-2-WT-A-E-1-BT-DTF 160' 3118' Lithology (%) Ss 20" Cht Sh Clyst Cly PV MBT MWD Summary Depth 8651' to 8651' Tools ENI Petroleum SP33-W3 Spy Island 24 hr Max North Slope Doyon 15 AK-AM-0009568240 Customer: Well: Avg 16 30-Jun-2012 24:00 Time: Report #: Date: 49.60 3490' 17.20 17.5 31 1.117 18 Size 25 13 3/8" 16" (current) 68.0 Weight 291' 3134' 2843' 5162' 8651' Make 3134' 2028' 12.25" 1.116 8651' YP 2 4 Smith GF15B Insert 9.30 (lb/100ft 2) 1,500 9.50 Condition 40.0 LSND Depth Mud Type 60 mg/l Coal Gvl API FL 4.6 1-1-WT-A-E-I-BU-TD Cor Solids Chlorides 100 ECD (ppg) Avg Min Max Xceed 900, ARC825, Telescope 825 ml/30min RPM 5162' 15 150 4-6-BT-S-X-2-RO-ROP 3 Smith MDSi716 PDC 12.25" 1.167 26.50 *10000 units = 100% Gas In Air (max) N/A C-5n C-5i C-1 000 0 Connection 0 0 Leigh Ann Rasher C-3 0 Logging Engineers: Kori Jo Anderson / Leigh Ann Rasher (max) (current) Report By: 0 0 Chromatograph (ppm) 00 0 0 Minimum C-4i BROOH to 3070'MD and circ B/U. Cont to POOH. L/D BHA #4. P/U BHA #5. Shallow tested tools. RIH. md. Average 0 C-4n 0 0 Gas Summary C-2 Depth Units* 0000 0 (current) Maximum 907-685-0772 Unit Phone: 23 24 hr Recap: N/A Background Trip . . Density (ppg) Viscosity out (sec/qt) 150 4-6-BT-S-X-2-RO-ROP 3 Smith MDSi716 PDC 12.25" 1.167 26.50 10.41 ml/30min RPM 5162' ECD (ppg) Avg Min Max Xceed 900, ARC825, Telescope 825 10.10 mg/l 9.80 Coal Gvl API FL 4.8 1-1-WT-A-E-I-BU-TD Cor Solids Chlorides 100 LSND Depth Mud Type 57 1,400 9.60 Condition 40.0 12.25" 1.116 9270' YP 2 4 Smith GF15B Insert 9.40 (lb/100ft 2) 291' 3134' 2843' 5162' 8651' Make 3134' 2028' 15 16" (current) 68.0 Weight 49.60 3490' 17.20 17.5 28 1.117 15 Size 25 17 1-Jul-2012 24:00 Time: Report #: Date: ENI Petroleum SP33-W3 Spy Island 24 hr Max North Slope Doyon 15 AK-AM-0009568240 Customer: Well: Avg PV MBT MWD Summary Depth 8651' to 9596' Tools 30 Sh Clyst Cly 20" 70 Cht 13 3/8" cP Depth in / out Hughes MX-1 Mill Tooth 2-2-WT-A-E-1-BT-DTF 160' 3118' Lithology (%) Ss Yesterday's Depth: Total Charges: 5.8 Drill 12.25" Int Rig Activity: Flow In (spm) 777.8 $3,410.00 (ppb Eq) 2538 $62,170.00 Report For: Keener/Smith/Buchanan 77.3 8651' 9596' 945' Current Pump & Flow Data: 8789' Flow In (gpm) Hours EVAMAR ROP (ft/hr) Bit Type TFA pH BTC 96% 901 213 SPP (psi) Gallons/stroke % 122.0 Tuff Rig: Job No.: Current Depth: 24 Hour Progress: Daily Charges: @4.23 Silt Siltst Max @ ft 30.0 Area: Location: WOB L-80 ROP Set At Size 178.9 X-65 Bit # Current in Footage Mud Data Casing Summary Grade Lst 8651' 5 Hycalog M4685CP Mill Tooth 12.25" 1.116 *10000 units = 100% Gas In Air 231 Trip 907-685-0772 Unit Phone: 59 24 hr Recap: 113 Background (current) Maximum 3 0 0117 30 Depth Units* 70 Gas Summary C-2 74 md. Average 0 C-4n 301 observed the past 24 hours is 231 units at 9520' MD. Finish RIH. Circ and condition mud. Drill ahead in 12.25" intermediate section from 8651' MD to 9596' MD. Max gas 43 C-4i 9520' 8778' 26 Minimum Chromatograph (ppm) 13 75 3450 2 27247 Logging Engineers: Kori Jo Anderson / Leigh Ann Rasher (max) (current) Report By: 42 Leigh Ann Rasher C-3 0 0 Connection 0 (max) N/A C-5n C-5i C-1 0032 . . Density (ppg) Viscosity out (sec/qt) 5 Hycalog M4685CP Mill Tooth 12.25" 1.116 8651' Lst Mud Data Casing Summary Grade L-80 ROP Set At Size 178.9 X-65 Bit # Current in Footage WOB Area: Location: Max @ ft 30.0 @4.23 Silt Siltst Tuff Rig: Job No.: Current Depth: 24 Hour Progress: Daily Charges: 96% 856 202 SPP (psi) Gallons/stroke % BTC ROP (ft/hr) Bit Type TFA pH Flow In (gpm) Hours EVAMAR 2413 $65,580.00 Report For: Keener/Smith/Buchanan 59.5 9596' 10988' 1392' Current Pump & Flow Data: 9896' Yesterday's Depth: Total Charges: 7.0 BROOH Rig Activity: Flow In (spm) 622.6 $3,410.00 (ppb Eq) cP Depth in / out Hughes MX-1 Mill Tooth 2-2-WT-A-E-1-BT-DTF 160' 3118' Lithology (%) Ss 20" 80 Cht 13 3/8" 20 Sh Clyst Cly PV MBT MWD Summary Depth 9596' to 10988' Tools ENI Petroleum SP33-W3 Spy Island 24 hr Max North Slope Doyon 15 AK-AM-0009568240 Customer: Well: Avg 18 2-Jul-2012 24:00 Time: Report #: Date: 49.60 3490' 17.20 18.0 28 1.117 17 Size 25 16" (current) 68.0 Weight 291' 3134' 2843' 5162' 8651' Make 3134' 2028' 15 12.25" 1.116 10988' YP 2 4 Smith GF15B Insert 9.50 (lb/100ft 2) 1,500 9.50 Condition 40.0 LSND Depth Mud Type 56 mg/l 10.16 Coal Gvl API FL 4.2 1-1-WT-A-E-I-BU-TD Cor Solids Chlorides 100 ECD (ppg) Avg Min Max Xceed 900, ARC825, Telescope 825 10.47 10.77 ml/30min RPM 5162' 150 4-6-BT-S-X-2-RO-ROP 3 Smith MDSi716 PDC 12.25" 1.167 26.50 *10000 units = 100% Gas In Air (max) N/A C-5n C-5i C-1 0038 0 Connection 0 2271 Leigh Ann Rasher C-3 1363 Logging Engineers: Kori Jo Anderson / Leigh Ann Rasher (max) (current) Report By: 12581 5 222116 Chromatograph (ppm) 162 159 3059 3941 Minimum C-4i 10937' 10419' 3095 units @ 10937' MD. Drill from 9696' MD to TD of 10988' MD. BROOH. Two max gas peaks observed were 3054 units @ 10870' MD and 324 md. Average 0 C-4n 4726 5479 Gas Summary C-2 Depth Units* 80 20 51 148 233 229 0 (current) Maximum 907-685-0772 Unit Phone: 141 24 hr Recap: N/A Background 3095 Trip . . Density (ppg) Viscosity out (sec/qt) 150 4-6-BT-S-X-2-RO-ROP 3 Smith MDSi716 PDC 12.25" 1.167 26.50 ml/30min RPM 5162' ECD (ppg) Avg Min Max Xceed 900, ARC825, Telescope 825 mg/l Coal Gvl API FL 4.2 1-1-WT-A-E-I-BU-TD Cor Solids Chlorides 100 LSND Depth Mud Type 52 1,400 9.60 Condition 40.0 12.25" 1.116 10988' YP 2 4 Smith GF15B Insert 9.50 (lb/100ft 2) 291' 3134' 2843' 5162' 8651' Make 3134' 2028' 15 16" (current) 68.0 Weight 49.60 3490' 17.20 18.0 26 1.117 15 Size 25 19 3-Jul-2012 24:00 Time: Report #: Date: ENI Petroleum SP33-W3 Spy Island 24 hr Max North Slope Doyon 15 AK-AM-0009568240 Customer: Well: Avg PV MBT MWD Summary Depth 10988' to 10988' Tools Sh Clyst Cly 20" Cht 13 3/8" cP Depth in / out Hughes MX-1 Mill Tooth 2-2-WT-A-E-1-BT-DTF 160' 3118' Lithology (%) Ss Yesterday's Depth: Total Charges: 7.4 BROOH Rig Activity: Flow In (spm) $3,410.00 (ppb Eq) 1425 $68,990.00 Report For: Keener/Smith/Buchanan 10988' 10988' 0' Current Pump & Flow Data: Flow In (gpm) Hours EVAMAR ROP (ft/hr) Bit Type TFA pH BTC 96% 901 213 SPP (psi) Gallons/stroke % Tuff Rig: Job No.: Current Depth: 24 Hour Progress: Daily Charges: @4.23 Silt Siltst Max @ ft 30.0 Area: Location: WOB L-80 ROP Set At Size 178.9 X-65 Bit # Current in Footage Mud Data Casing Summary Grade Lst 8651' 5 Hycalog M4685CP Mill Tooth 12.25" 1.116 *10000 units = 100% Gas In Air Trip 907-685-0772 Unit Phone: 176 24 hr Recap: N/A Background (current) Maximum 0 0 000 Depth Units* Gas Summary C-2 0 md. Average 0 C-4n 0 Continued to BROOH from 10988' MD to 3000' MD. Circ hole clean and POOH. C-4i 0 Minimum Chromatograph (ppm) 00 0 0 0 Logging Engineers: Kori Jo Anderson / Leigh Ann Rasher (max) (current) Report By: 0 Leigh Ann Rasher C-3 0 0 Connection 0 (max) N/A C-5n C-5i C-1 000 . . Density (ppg) Viscosity out (sec/qt) 10988' 2337' 25 120 2-1-WT-A-E-I-NO-TD 5 Hycalog M4685CP Mill Tooth 12.25" 1.116 24.10 8651' Lst Mud Data Casing Summary Grade L-80 ROP Set At Size 178.9 X-65 Bit # Current in Footage WOB Area: Location: Max @ ft 30.0 @4.23 Silt Siltst Tuff Rig: Job No.: Current Depth: 24 Hour Progress: Daily Charges: 96% SPP (psi) Gallons/stroke % BTC ROP (ft/hr) Bit Type TFA pH Flow In (gpm) Hours EVAMAR $72,400.00 Report For: Ross/Smith/Buchanan9.4 10988' 10988' 0' Current Pump & Flow Data: Yesterday's Depth: Total Charges: 6.0 Run 9.625" Casing Rig Activity: Flow In (spm) $3,410.00 (ppb Eq) cP Depth in / out Hughes MX-1 Mill Tooth 2-2-WT-A-E-1-BT-DTF 160' 3118' Lithology (%) Ss 20" Cht 13 3/8" Sh Clyst Cly PV MBT MWD Summary Depth 10988' to 10988' Tools ENI Petroleum SP33-W3 Spy Island 24 hr Max North Slope Doyon 15 AK-AM-0009568240 Customer: Well: Avg 20 4-Jul-2012 24:00 Time: Report #: Date: 49.60 3490' 17.20 17.5 23 1.117 13 Size 25 16" (current) 68.0 Weight 291' 3134' 2843' 5162' 8651' Make 3134' 2028' 15 12.25" 1.116 10988' YP 2 4 Smith GF15B Insert 9.40 (lb/100ft 2) 1,300 9.20 Condition 40.0 LSND Depth Mud Type 51 mg/l Coal Gvl API FL 5.4 1-1-WT-A-E-I-BU-TD Cor Solids Chlorides 100 ECD (ppg) Avg Min Max Xceed 900, ARC825, Telescope 825 ml/30min RPM 5162' 150 4-6-BT-S-X-2-RO-ROP 3 Smith MDSi716 PDC 12.25" 1.167 26.50 *10000 units = 100% Gas In Air (max) N/A C-5n C-5i C-1 000 0 Connection 0 0 Leigh Ann Rasher C-3 0 Logging Engineers: Kori Jo Anderson / Leigh Ann Rasher (max) (current) Report By: 0 0 Chromatograph (ppm) 00 0 0 Minimum C-4i Finish POOH. L/D BHA #5. R/U casing tools and P/U shoe track and tested float. RIH with 9.625" casing. md. Average 0 C-4n 0 0 Gas Summary C-2 Depth Units* 0000 0 (current) Maximum 907-685-0772 Unit Phone: N/A 24 hr Recap: N/A Background Trip . . Density (ppg) Viscosity out (sec/qt) 10988' 2337' 25 120 2-1-WT-A-E-I-NO-TD 5 Hycalog M4685CP Mill Tooth 12.25" 1.116 24.10 8651' Lst Mud Data Casing Summary Grade L-80 ROP Set At Size 178.9 X-65 Bit # Current in Footage WOB Area: Location: Max @ ft 30.0 @4.23 Silt Siltst Tuff Rig: Job No.: Current Depth: 24 Hour Progress: Daily Charges: 96% SPP (psi) Gallons/stroke % BTC L80 ROP (ft/hr) Bit Type TFA pH Flow In (gpm) Hours EVAMAR $75,810.00 Report For: Ross/Smith/Buchanan 10988' 10988' 0' Current Pump & Flow Data: Yesterday's Depth: Total Charges: 6.0 Cement 9 5/8" casing Rig Activity: Flow In (spm) $3,410.00 (ppb Eq) cP Depth in / out Hughes MX-1 Mill Tooth 2-2-WT-A-E-1-BT-DTF 160' 3118' Lithology (%) 9 5/8" Ss 20" 10973' Cht 13 3/8" Sh Clyst Cly PV MBT MWD Summary Depth 10988' to 10988' Tools ENI Petroleum SP33-W3 Spy Island 24 hr Max North Slope Doyon 15 AK-AM-0009568240 Customer: Well: Avg 21 5-Jul-2012 24:00 Time: Report #: Date: 49.60 3490' 17.20 15.0 16 1.117 11 Size 25 16" (current) 68.0 Weight 40.0 Hydro 563 291' 3134' 2843' 5162' 8651' Make 3134' 2028' 15 12.25" 1.116 10988' YP 2 4 Smith GF15B Insert 9.40 (lb/100ft 2) 1,300 9.00 Condition 40.0 LSND Depth Mud Type 45 mg/l Coal Gvl API FL 5.8 1-1-WT-A-E-I-BU-TD Cor Solids Chlorides 100 ECD (ppg) Avg Min Max Xceed 900, ARC825, Telescope 825 ml/30min RPM 5162' 150 4-6-BT-S-X-2-RO-ROP 3 Smith MDSi716 PDC 12.25" 1.167 26.50 *10000 units = 100% Gas In Air (max) N/A C-5n C-5i C-1 000 0 Connection 0 0 Leigh Ann Rasher C-3 0 Logging Engineers: Kori Jo Anderson / Leigh Ann Rasher (max) (current) Report By: 0 0 Chromatograph (ppm) 00 0 0 Minimum C-4i at 10973' MD. Cont to RIH with 9 5/8" casing. Land casing @ 10973' MD. L/D Tesco eqipment and R/U cmt head. Cmt 9 5/8" casing md. Average 0 C-4n 0 0 Gas Summary C-2 Depth Units* 0000 0 (current) Maximum 907-685-0772 Unit Phone: N/A 24 hr Recap: N/A Background Trip . . Density (ppg) Viscosity out (sec/qt) 10988' 2337' 25 120 2-1-WT-A-E-I-NO-TD 5 Hycalog M4685CP Mill Tooth 12.25" 1.116 24.10 8651' Lst Mud Data Casing Summary Grade L-80 ROP Set At Size 178.9 X-65 Bit # Current in Footage WOB Area: Location: Max @ ft 30.0 @4.23 Silt Siltst Tuff Rig: Job No.: Current Depth: 24 Hour Progress: Daily Charges: 96% SPP (psi) Gallons/stroke % BTC HYDRIL ROP (ft/hr) Bit Type TFA pH Flow In (gpm) Hours EVAMAR $79,520.00 Report For: Ross/Smith/Buchanan 10988' 10988' 0' Current Pump & Flow Data: Yesterday's Depth: Total Charges: 6.0 Testing BOP's Rig Activity: Flow In (spm) $3,710.00 (ppb Eq) cP Depth in / out Hughes MX-1 Mill Tooth 2-2-WT-A-E-1-BT-DTF 160' 3118' Lithology (%) 9 5/8" Ss 20" 10973' Cht 13 3/8" Sh Clyst Cly PV MBT MWD Summary Depth 10988' to 10988' Tools ENI Petroleum SP33-W3 Spy Island 24 hr Max North Slope Doyon 15 AK-AM-0009568240 Customer: Well: Avg 22 6-Jul-2012 24:00 Time: Report #: Date: 49.60 3490' 17.20 15.0 15 1.117 12 Size 25 16" (current) 68.0 Weight 40.0 L-80 291' 3134' 2843' 5162' 8651' Make 3134' 2028' 15 12.25" 1.116 10988' YP 2 4 Smith GF15B Insert 9.40 (lb/100ft 2) 1,300 9.00 Condition 40.0 LSND Depth Mud Type 46 mg/l Coal Gvl API FL 5.8 1-1-WT-A-E-I-BU-TD Cor Solids Chlorides 100 ECD (ppg) Avg Min Max ml/30min RPM 5162' 150 4-6-BT-S-X-2-RO-ROP 3 Smith MDSi716 PDC 12.25" 1.167 26.50 *10000 units = 100% Gas In Air (max) N/A C-5n C-5i C-1 000 0 Connection 0 0 Leigh Ann Rasher C-3 0 Logging Engineers: Kori Jo Anderson / Leigh Ann Rasher (max) (current) Report By: 0 0 Chromatograph (ppm) 00 0 0 Minimum C-4i off, change rams, test BOP's. Finish cmt 9 5/8" casing. L/D cmt head, install emergency slips, pulled wear bushings. Install stack and tested pack md. Average 0 C-4n 0 0 Gas Summary C-2 Depth Units* 0000 0 (current) Maximum 907-685-0772 Unit Phone: N/A 24 hr Recap: N/A Background Trip . . Density (ppg) Viscosity out (sec/qt) ECD (ppg) Tools Xceed, PeriScope, TeleScope, AdnVision API FL Depth 10988'to 10988' Avg Min Max 10973' FazePro Depth Mud Type YP Cor Solids (lb/100ft 2) 3.64 2.80 Mud (lb/bbl) ml/30min 6 Cht Silt Siltst HYDRIL Ss NA Lst EVAMAR Make 9.45 65/35 12 10988' WOB 23 7-Jul-2012 24:00:00 Time: Report #: Date: AK-AM-0009568240 Customer: Well: Avg 0.902 16 46 8 3/4" PV Oil / Water Footage ENI Petroleum SP33-W3 Spy Island 24 hr Max North Slope Lithology (%) (current) Sh Clyst 68.0 Weight Size Hycalog SKH616M-EID PDC 160' 3118' 10973' Tuff Gvl Coal $3,410.00 8.8 Alkal Lime $82,930.00 Report For: Ratio cP Ross/Smith/Buchanan Flow In (gpm) Total Charges: 10988' 10988' 0' Current Depth: 24 Hour Progress: RIH Rig Activity: Doyon 15 Daily Charges: Current Pump & Flow Data: Max @ ft Current 4.23 Flow In (spm) MWD Summary Bit Type TFA Cly RPM Hours Depth in / out % Casing Summary Condition in Mud Data @ Yesterday's Depth: 0.0 Rig: Job No.: ROP (ft/hr) Area: Location: 96% SPP (psi) Gallons/stroke ROP Set At Size 178.9 X-65 Bit # L-80 Grade L-80 40.0 20" 13 3/8" 9 5/8" BTC * 10000 units = 100% Gas In Air N/A Connection (max) Chromatograph (ppm) N/A 24 hr Recap: N/A Background Trip 0 0 0 0 0 0 C-4i C-4n C-5n 00 0 0 Gas Summary md. Finish POOH with 5" DP and installing WEI subs. P/U BHA #6 and RIH w/ 4.5" DP to 5,500' MD. Units* 0 0 00Minimum Average 00 0 Depth C-2 C-3 0 C-1 0Maximum 0 907-685-0772 Unit Phone: 0 Leigh Ann Rasher Report By: Logging Engineers: Leigh Ann Rasher / Kori Jo Anderson (max) (current) C-5i . . Density (ppg) Viscosity out (sec/qt) 20" 13 3/8" 9 5/8" BTC L-80 Grade L-80 40.0 ROP Set At Size 178.9 X-65 Bit # Area: Location: 96% 486 115 SPP (psi) Gallons/stroke 2471 @ Yesterday's Depth: 0.0 Rig: Job No.: ROP (ft/hr) Condition in Mud Data Depth in / out % Casing Summary RPM Hours Bit Type TFA Cly Current Pump & Flow Data: Max @ ft Current 4.23 Flow In (spm) MWD Summary Total Charges: 10988' 11010' 22' Current Depth: 24 Hour Progress: Circ to perform LOT Rig Activity: Doyon 15 Daily Charges: $3,410.00 13.0 Alkal Lime $86,340.00 Report For: Ratio cP Ross/Smith/Buchanan Flow In (gpm) Tuff Gvl Coal 68.0 Weight Size Hycalog SKH616M-EID PDC 160' 3118' 10973' Lithology (%) (current) Sh Clyst Footage ENI Petroleum SP33-W3 Spy Island 24 hr Max North Slope Customer: Well: Avg 0.902 15 47 8 3/4" PV Oil / Water 10988' WOB 24 8-Jul-2012 24:00:00 Time: Report #: Date: AK-AM-0009568240 64/36 13 Ss NA Lst EVAMAR Make 9.45 6 Cht Silt Siltst HYDRIL YP Cor Solids (lb/100ft 2) 3.90 3.00 Mud (lb/bbl) ml/30min 10973' FazePro Depth Mud Type Depth 11010'to 10988' Avg Min Max ECD (ppg) Tools Xceed, PeriScope, TeleScope, AdnVision API FL * 10000 units = 100% Gas In Air Logging Engineers: Leigh Ann Rasher / Kori Jo Anderson (max) (current) C-5i 907-685-0772 Unit Phone: 0 Leigh Ann Rasher Report By: C-1 0Maximum 0 0 Depth C-2 C-3 0Minimum Average 000 0 00 Units* test WEI system. Drilled 22' of new hole to 11010' MD. RIH with 5" DP to 9647' MD then reamed to 10899' MD. Perform casing test to 3000 psi for 30 min. Displace mud and md. 0 0 Gas Summary C-5n 00 C-4i C-4n 0 0 0 0 0 0 Trip 192 24 hr Recap: N/A Background N/A Connection (max) Chromatograph (ppm) . . Density (ppg) Viscosity out (sec/qt) ECD (ppg) Tools Xceed, PeriScope, TeleScope, AdnVision API FL Depth 12991'to 11010' 11.28 10.55 11.02 Avg Min Max 12560' FazePro Depth Mud Type YP Cor Solids (lb/100ft 2) 3.38 2.60 Mud (lb/bbl) ml/30min 6 Cht Silt Siltst 100 HYDRIL Ss NA Lst EVAMAR Make 9.40 66/34 16 10988' WOB 25 9-Jul-2012 24:00:00 Time: Report #: Date: AK-AM-0009568240 Customer: Well: Avg 0.902 14 47 8 3/4" PV Oil / Water Footage ENI Petroleum SP33-W3 Spy Island 24 hr Max North Slope 649.8 Lithology (%) (current) Sh Clyst 68.0 Weight Size Hycalog SKH616M-EID PDC 160' 3118' 10973' Tuff Gvl Coal $3,410.00 10.0 Alkal Lime $89,750.00 Report For: Ratio cP Ross/Smith/Buchanan Flow In (gpm) Total Charges: 11010' 12991' 1981' Current Depth: 24 Hour Progress: Drilling ahead Rig Activity: Doyon 15 Daily Charges: Current Pump & Flow Data: Max @ ft Current 11366'157.3 4.23 Flow In (spm) MWD Summary Bit Type TFA Cly RPM Hours Depth in / out % Casing Summary Condition in Mud Data @ Yesterday's Depth: 304.5 Rig: Job No.: ROP (ft/hr) Area: Location: 96% 550 130 SPP (psi) Gallons/stroke 3171 ROP Set At Size 178.9 X-65 Bit # L-80 Grade L-80 40.0 20" 13 3/8" 9 5/8" BTC * 10000 units = 100% Gas In Air N/A Connection (max) Chromatograph (ppm) N/A 24 hr Recap: 150 Background Trip 753 366 306 111 2 197 C-4i C-4n C-5n 00 96499 1025 Gas Summary md. at 12304' MD. Lithology consist of 100% sandstone. Perform FIT test to 13.0 ppg. Drill ahead in 8.75" hole from 11010" MD to 12991' MD. Max gas observed was 887 units 328 Units* 11 12304'887 11012' 166 339 24Minimum Average 64 31088 0 Depth C-2 C-3 197 C-1 172 Maximum 374 907-685-0772 Unit Phone: 94 Leigh Ann Rasher Report By: Logging Engineers: Leigh Ann Rasher / Kori Jo Anderson (max) (current) C-5i . . Density (ppg) Viscosity out (sec/qt) 20" 13 3/8" 9 5/8" BTC L-80 Grade L-80 40.0 ROP Set At Size 178.9 X-65 Bit # Area: Location: 96% 533 126 SPP (psi) Gallons/stroke 3279 @ Yesterday's Depth: 181.6 Rig: Job No.: ROP (ft/hr) Condition in Mud Data Depth in / out % Casing Summary RPM Hours Bit Type TFA Cly Current Pump & Flow Data: Max @ ft Current 13848'98.7 4.23 Flow In (spm) MWD Summary Total Charges: 12912' 14946' 2034' Current Depth: 24 Hour Progress: Drilling ahead Rig Activity: Doyon 15 Daily Charges: $5,410.00 10.5 Alkal Lime $91,750.00 Report For: Ratio cP Ross/Wimmer/Buchanan Flow In (gpm) Tuff Gvl Coal 68.0 Weight Size Hycalog SKH616M-EID PDC 160' 3118' 10973' Lithology (%) (current) Sh Clyst Footage ENI Petroleum SP33-W3 Spy Island 24 hr Max North Slope 517.6 Customer: Well: Avg 0.902 13 44 8 3/4" 3958' PV Oil / Water 10988' WOB 26 10-Jul-2012 24:00:00 Time: Report #: Date: AK-AM-0009568240 66/34 14 Ss Lst EVAMAR Make 9.40 6 Cht Silt Siltst 100 HYDRIL YP Cor Solids (lb/100ft 2) 2.86 2.20 Mud (lb/bbl) ml/30min 14707' FazePro Depth Mud Type Depth 14946'to 12912' 11.41 Avg Min Max ECD (ppg) Tools Xceed, PeriScope, TeleScope, AdnVision API FL * 10000 units = 100% Gas In Air Logging Engineers: Zach Beekman / Leigh Ann Rasher (max) (current) C-5i 907-685-0772 Unit Phone: 128 Zach Beekman Report By: C-1 223 Maximum 375 45 Depth C-2 C-3 1456 Minimum Average 76 35935 159 327 67 70 14070' 1781 Units* 55 13272' last 24 hours was 1781 units at a depth of 13272' MD. Continue drilling ahead with the 8.75" hole from 12912' MD to 14946' MD as of midnight. Max gas observed during the 385 md. 188099 802 Gas Summary C-5n 52 84 C-4i C-4n 335 264 126 92 191 534 Trip 24 hr Recap: 42 Background Connection (max) Chromatograph (ppm) . . Density (ppg) Viscosity out (sec/qt) ECD (ppg) Tools Xceed, PeriScope, TeleScope, AdnVision API FL Depth 16632'to 14946' 11.53 Avg Min Max 16511' FazePro Depth Mud Type YP Cor Solids (lb/100ft 2) 2.34 1.80 Mud (lb/bbl) ml/30min 6 10 Cht Silt Siltst 90 HYDRIL Ss Lst EVAMAR Make 9.40 66/34 13 10988' WOB 27 11-Jul-2012 24:00:00 Time: Report #: Date: AK-AM-0009568240 Customer: Well: Avg 0.902 15 45 8 3/4" 5644' PV Oil / Water Footage ENI Petroleum SP33-W3 Spy Island 24 hr Max North Slope 635.8 Lithology (%) (current) Sh Clyst 68.0 Weight Size Hycalog SKH616M-EID PDC 160' 3118' 10973' Tuff Gvl Coal $3,410.00 11.0 Alkal Lime $94,160.00 Report For: Ratio cP Ross/Wimmer/Buchanan Flow In (gpm) Total Charges: 14946' 16632' 1686' Current Depth: 24 Hour Progress: Drilling ahead Rig Activity: Doyon 15 Daily Charges: Current Pump & Flow Data: Max @ ft Current 15284'74.1 4.23 Flow In (spm) MWD Summary Bit Type TFA Cly RPM Hours Depth in / out % Casing Summary Condition in Mud Data @ Yesterday's Depth: 151.3 Rig: Job No.: ROP (ft/hr) Area: Location: 96% 539 127 SPP (psi) Gallons/stroke 3613 ROP Set At Size 178.9 X-65 Bit # L-80 Grade L-80 40.0 20" 13 3/8" 9 5/8" BTC * 10000 units = 100% Gas In Air Connection (max) Chromatograph (ppm) 24 hr Recap: 38 Background Trip 865 323 283 115 50 184 C-4i C-4n C-5n 32 44 99358 1135 Gas Summary md. last 24 hours was 954 units at a depth of 15944' MD. Continue to drill ahead with the 8.75" hole from 14946' MD to 16632' MD as of midnight. Max gas observed during the 349 Units* 54 15944'954 16579' 150 388 33 37 Minimum Average 71 24847 23 Depth C-2 C-3 1314 C-1 221 Maximum 437 907-685-0772 Unit Phone: 128 Zach Beekman Report By: Logging Engineers: Zach Beekman / Leigh Ann Rasher (max) (current) C-5i . . Density (ppg) Viscosity out (sec/qt) 20" 13 3/8" 9 5/8" BTC L-80 Grade L-80 40.0 ROP Set At Size 178.9 X-65 Bit # Area: Location: 96% 533 126 SPP (psi) Gallons/stroke 3636 @ Yesterday's Depth: 0.0 Rig: Job No.: ROP (ft/hr) Condition in Mud Data Depth in / out % Casing Summary RPM Hours Bit Type TFA Cly Current Pump & Flow Data: Max @ ft Current 17437'65.0 4.23 Flow In (spm) MWD Summary Total Charges: 16632' 18076' 1444' Current Depth: 24 Hour Progress: Drilling ahead Rig Activity: Doyon 15 Daily Charges: $3,410.00 10.9 Alkal Lime $97,570.00 Report For: Ratio cP Ross/Wimmer/Buchanan Flow In (gpm) Tuff Gvl Coal 68.0 Weight Size Hycalog SKH616M-EID PDC 160' 3118' 10973' Lithology (%) (current) Sh Clyst Footage ENI Petroleum SP33-W3 Spy Island 24 hr Max North Slope 435.0 Customer: Well: Avg 0.902 14 45 8 3/4" 7088' PV Oil / Water 10988' WOB 28 12-Jul-2012 24:00:00 Time: Report #: Date: AK-AM-0009568240 67/33 13 Ss Lst EVAMAR Make 9.40 6 Cht Silt Siltst 100 HYDRIL YP Cor Solids (lb/100ft 2) 3.77 2.90 Mud (lb/bbl) ml/30min 17912' FazePro Depth Mud Type Depth 18076'to 16632' 11.60 Avg Min Max ECD (ppg) Tools Xceed, PeriScope, TeleScope, AdnVision API FL * 10000 units = 100% Gas In Air Logging Engineers: Zach Beekman / Leigh Ann Rasher (max) (current) C-5i 907-685-0772 Unit Phone: 133 Zach Beekman Report By: C-1 228 Maximum 461 29 Depth C-2 C-3 2426 Minimum Average 62 24919 140 404 30 37 16741' 862 Units* 59 17382' last 24 hours was 862 units at a depth of 17382' MD. Continue drilling ahead with the 8.75" hole from 16632' MD to 18076' MD as of midnight. Max gas observed during the 340 md. 89467 1113 Gas Summary C-5n 30 40 C-4i C-4n 323 282 100 44 171 897 Trip 24 hr Recap: 61 Background Connection (max) Chromatograph (ppm) . . Density (ppg) Viscosity out (sec/qt) ECD (ppg) Tools Xceed, PeriScope, TeleScope, AdnVision API FL Depth 19544'to 18076' 11.96 Avg Min Max 19544' FazePro Depth Mud Type YP Cor Solids (lb/100ft 2) 2.80 2.15 Mud (lb/bbl) ml/30min 6 Cht Silt Siltst 100 HYDRIL Ss Lst EVAMAR Make 9.40 67/33 14 10988' 19544' WOB 29 13-Jul-2012 24:00:00 Time: Report #: Date: AK-AM-0009568240 Customer: Well: Avg 0.902 14 45 8 3/4" 8556' PV Oil / Water Footage ENI Petroleum SP33-W3 Spy Island 24 hr Max North Slope 496.5 Lithology (%) (current) Sh Clyst 68.0 Weight Size Hycalog SKH616M-EID PDC 160' 3118' 10973' Tuff Gvl Coal $3,410.00 11.7 Alkal Lime $100,980.00 Report For: Ratio cP Ross/Wimmer/Buchanan Flow In (gpm) Total Charges: 18076' 19544' 1468' Current Depth: 24 Hour Progress: BROOH Rig Activity: Doyon 15 Daily Charges: Current Pump & Flow Data: Max @ ft Current 18814'56.6 4.23 Flow In (spm) MWD Summary Bit Type TFA Cly RPM Hours Depth in / out % Casing Summary Condition in Mud Data @ Yesterday's Depth: 0.0 Rig: Job No.: ROP (ft/hr) Area: Location: 96% 536 127 SPP (psi) Gallons/stroke 3852 ROP Set At Size 178.9 X-65 Bit # L-80 Grade L-80 40.0 20" 13 3/8" 9 5/8" BTC * 10000 units = 100% Gas In Air Connection (max) Chromatograph (ppm) 24 hr Recap: 46 Background Trip 848 337 294 104 64 181 C-4i C-4n C-5n 36 51 96397 1131 Gas Summary md. K&M schedule at 530 gpm, 3780 psi, and 135 rpm from 19544' MD to 19250' MD racking back one stand per bottoms up as of midnight. 24 hours was 932 units at a depth of 18457' MD. Monitor well. Static. Circulate a bottoms up and back ream out of the hole per Continue drilling ahead with the 8.75" hole from 18076' MD to TD at 19544' MD. Max gas observed during the last 322 Units* 62 18457'932 19186' 148 365 43 60 Minimum Average 64 25908 45 Depth C-2 C-3 2382 C-1 196 Maximum 410 907-685-0772 Unit Phone: 113 Zach Beekman Report By: Logging Engineers: Zach Beekman / Leigh Ann Rasher (max) (current) C-5i . . Density (ppg) Viscosity out (sec/qt) 20" 13 3/8" 9 5/8" BTC L-80 Grade L-80 40.0 ROP Set At Size 178.9 X-65 Bit # Area: Location: 96% 550 130 SPP (psi) Gallons/stroke 3439 @ Yesterday's Depth: Rig: Job No.: ROP (ft/hr) Condition in Mud Data Depth in / out % Casing Summary RPM Hours Bit Type TFA Cly Current Pump & Flow Data: Max @ ft Current 4.23 Flow In (spm) MWD Summary Total Charges: 19544' 19544' 0' Current Depth: 24 Hour Progress: BROOH Rig Activity: Doyon 15 Daily Charges: $3,410.00 11.9 Alkal Lime $104,390.00 Report For: Ratio cP Ross/Wimmer/Buchanan Flow In (gpm) Tuff Gvl Coal 68.0 Weight Size Hycalog SKH616M-EID PDC 160' 3118' 10973' Lithology (%) (current) Sh Clyst Footage ENI Petroleum SP33-W3 Spy Island 24 hr Max North Slope Customer: Well: Avg 0.902 14 46 8 3/4" 8556' PV Oil / Water 10988' 19544' WOB 30 14-Jul-2012 24:00:00 Time: Report #: Date: AK-AM-0009568240 67/33 15 Ss Lst EVAMAR Make 9.40 6 Cht Silt Siltst HYDRIL YP Cor Solids (lb/100ft 2) 3.25 2.50 Mud (lb/bbl) ml/30min 19544' FazePro Depth Mud Type Depth 19544'to 19544' Avg Min Max ECD (ppg) Tools API FL * 10000 units = 100% Gas In Air Logging Engineers: Zach Beekman / Leigh Ann Rasher (max) (current) C-5i 907-685-0772 Unit Phone: 0 Zach Beekman Report By: C-1 0Maximum 0 0 Depth C-2 C-3 0Minimum Average 000 0 00 Units* 19250' MD to 16732' MD. Increase to full pump rate of 550 gpm. At 15630' MD, observed increase in torque, 18-24k and pump Circulate bottoms up and back ream out of the hole per K&M schedule at 540 gpm, 3950 psi, and 135 rpm from md. psi to 3900. Run in hole to 15962' MD. Re-establish full pump rate 550 gpm, 3710 psi, and 130 rpm as of midnight. 0 0 Gas Summary C-5n 00 C-4i C-4n 0 0 0 0 0 0 Trip 24 hr Recap: 22 Background Connection (max) Chromatograph (ppm) . . Density (ppg) Viscosity out (sec/qt) ECD (ppg) Tools API FL Depth 19544'to 19544' Avg Min Max 19544' FazePro Depth Mud Type YP Cor Solids (lb/100ft 2) 3.19 2.45 Mud (lb/bbl) ml/30min 6 Cht Silt Siltst HYDRIL Ss Lst EVAMAR Make 9.40 67/33 14 10988' 19544' WOB 31 15-Jul-2012 24:00:00 Time: Report #: Date: AK-AM-0009568240 Customer: Well: Avg 0.902 14 46 8 3/4" 8556' PV Oil / Water Footage ENI Petroleum SP33-W3 Spy Island 24 hr Max North Slope Lithology (%) (current) Sh Clyst 68.0 Weight Size Hycalog SKH616M-EID PDC 160' 3118' 10973' Tuff Gvl Coal $2,810.00 11.2 Alkal Lime $107,200.00 Report For: Ratio cP Ross/Wimmer/Buchanan Flow In (gpm) Total Charges: 19544' 19544' 0' Current Depth: 24 Hour Progress: C/O Saver Sub Rig Activity: Doyon 15 Daily Charges: Current Pump & Flow Data: Max @ ft Current 4.23 Flow In (spm) MWD Summary Bit Type TFA Cly RPM Hours Depth in / out % Casing Summary Condition in Mud Data @ Yesterday's Depth: Rig: Job No.: ROP (ft/hr) Area: Location: 96% 533 126 SPP (psi) Gallons/stroke 2556 ROP Set At Size 178.9 X-65 Bit # L-80 Grade L-80 40.0 20" 13 3/8" 9 5/8" BTC * 10000 units = 100% Gas In Air Connection (max) Chromatograph (ppm) 24 hr Recap: 13 Background Trip 0 0 0 0 0 0 C-4i C-4n C-5n 00 0 0 Gas Summary md. Monitor well. Static. Back ream out of the hole to 8807' MD. Clear rig floor and change to the 4.5" saver sub on the top drive as of midnight. back reaming out of the hole to 11232' MD. Circulate and condition per K&M to 11139' MD. Back ream out of the hole to 10765' MD. Continue back reaming out of the hole per K&M schedule from 15673' MD to last WEI sub on stand #146. Continue Units* 0 0 00Minimum Average 00 0 Depth C-2 C-3 0 C-1 0Maximum 0 907-685-0772 Unit Phone: 0 Zach Beekman Report By: Logging Engineers: Zach Beekman / Leigh Ann Rasher (max) (current) C-5i . . Density (ppg) Viscosity out (sec/qt) 20" 13 3/8" 9 5/8" BTC L-80 Grade L-80 40.0 ROP Set At Size 178.9 X-65 Bit # Area: Location: 96% SPP (psi) Gallons/stroke @ Yesterday's Depth: Rig: Job No.: ROP (ft/hr) Condition in Mud Data Depth in / out % Casing Summary RPM Hours Bit Type TFA Cly Current Pump & Flow Data: Max @ ft Current 4.23 Flow In (spm) MWD Summary Total Charges: 19544' 19544' 0' Current Depth: 24 Hour Progress: Clean Rig Floor Rig Activity: Doyon 15 Daily Charges: $2,810.00 11.2 Alkal Lime $110,010.00 Report For: Ratio cP Ross/Wimmer/Buchanan Flow In (gpm) Tuff Gvl Coal 68.0 Weight Size Hycalog SKH616M-EID PDC 160' 3118' 10973' Lithology (%) (current) Sh Clyst Footage ENI Petroleum SP33-W3 Spy Island 24 hr Max North Slope Customer: Well: Avg 0.902 14 46 8 3/4" 8556' PV Oil / Water 10988' 19544' WOB 32 16-Jul-2012 24:00:00 Time: Report #: Date: AK-AM-0009568240 67/33 14 Ss Lst EVAMAR Make 9.40 6 Cht Silt Siltst HYDRIL YP Cor Solids (lb/100ft 2) 2.86 2.20 Mud (lb/bbl) ml/30min 19544' FazePro Depth Mud Type Depth 19544'to 19544' Avg Min Max ECD (ppg) Tools API FL * 10000 units = 100% Gas In Air Logging Engineers: Zach Beekman / Leigh Ann Rasher (max) (current) C-5i 907-685-0772 Unit Phone: 0 Zach Beekman Report By: C-1 0Maximum 0 0 Depth C-2 C-3 0Minimum Average 000 0 00 Units* to 1050' MD per K&M schedule. Circulate and condition per K&M to 1031' MD and observed the shakers were clean. Monitor well. Change to the 4.5" saver sub on the top drive and service the rig. Continue back reaming out of the ole from 8807' MD md. Static. Pull out of the hole to 270' MD and lay down the BHA. Clear the rig floor. Rig down the WEI sub equipment and clean the rig floor as of midnight. 0 0 Gas Summary C-5n 00 C-4i C-4n 0 0 0 0 0 0 Trip 24 hr Recap: Background Connection (max) Chromatograph (ppm) . . Density (ppg) Viscosity out (sec/qt) ECD (ppg) Tools API FL 8.0 Depth 19544'to 19544' Avg Min Max 19544' FazePro Depth Mud Type YP 1-2-BT-A-X-I-CT-TD Cor Solids (lb/100ft 2) 3.12 2.40 Mud (lb/bbl) ml/30min 6 Cht Silt Siltst HYDRIL Ss Lst EVAMAR Make 9.40 140.0 66.30 67/33 12 10988' 19544' WOB 33 17-Jul-2012 24:00:00 Time: Report #: Date: AK-AM-0009568240 Customer: Well: Avg 0.902 14 58 8 3/4" 8556' PV Oil / Water Footage ENI Petroleum SP33-W3 Spy Island 24 hr Max North Slope Lithology (%) (current) Sh Clyst 68.0 Weight Size Hycalog SKH616M-EID PDC 160' 3118' 10973' Tuff Gvl Coal $2,810.00 11.7 Alkal Lime $112,820.00 Report For: Ratio cP Keener/Wimmer/Buchanan Flow In (gpm) Total Charges: 19544' 19544' 0' Current Depth: 24 Hour Progress: RIH w/ 5.5" slotted liner Rig Activity: Doyon 15 Daily Charges: Current Pump & Flow Data: Max @ ft Current 4.23 Flow In (spm) MWD Summary Bit Type TFA Cly RPM Hours Depth in / out % Casing Summary Condition in Mud Data @ Yesterday's Depth: Rig: Job No.: ROP (ft/hr) Area: Location: 96% SPP (psi) Gallons/stroke ROP Set At Size 178.9 X-65 Bit # L-80 Grade L-80 40.0 20" 13 3/8" 9 5/8" BTC * 10000 units = 100% Gas In Air Connection (max) Chromatograph (ppm) 24 hr Recap: Background Trip 0 0 0 0 0 0 C-4i C-4n C-5n 00 0 0 Gas Summary md. 8844' MD. Break circulation at 2.5 bpm and 90 psi. Obtain parameters per K&M. Run in hole to 15,328' MD as of midnight. liner equipment. Run the 5.5" slotted liner per detail. 207 joints run. Make up the SLZXP packer. Run in hole with 5" drill pipe to Continued cleaning the rig floor. Change out the saver sub for 5" drill pipe. Clean the drip pan and rig up the GBR Units* 0 0 00Minimum Average 00 0 Depth C-2 C-3 0 C-1 0Maximum 0 907-685-0772 Unit Phone: 0 Zach Beekman Report By: Logging Engineers: Zach Beekman / Leigh Ann Rasher (max) (current) C-5i . . Density (ppg) Viscosity out (sec/qt) ml/30min RPM ECD (ppg) Avg Min Max mg/l Coal Gvl API FL Cor Solids Chlorides KCl/NaCl Brine Depth Mud Type 28 69,000 Condition 19544' YP 9.00 (lb/100ft 2) L-80 Make (current) 68.0 Weight 40.0 Size 34 18-Jul-2012 24:00 Time: Report #: Date: ENI Petroleum SP33-W3 Spy Island 24 hr Max North Slope Doyon 15 AK-AM-0009568240 Customer: Well: Avg PV MBT MWD Summary Depth 19544' to 19544' Tools Sh Clyst Cly 20" 10973' Cht 13 3/8" cP Depth in / out 160' 3118' Lithology (%) 9 5/8" Ss Yesterday's Depth: Total Charges: POOH w/ 5" DP Rig Activity: Flow In (spm) $2,810.00 (ppb Eq) $115,630.00 Report For: Keener/Wimmer/Buchanan 19544' 19544' 0' Current Pump & Flow Data: Flow In (gpm) Hours EVAMAR ROP (ft/hr) Bit Type TFA pH BTC HYDRIL 96% SPP (psi) Gallons/stroke % Tuff Rig: Job No.: Current Depth: 24 Hour Progress: Daily Charges: @4.23 Silt Siltst Max @ ft Area: Location: WOB L-80 ROP Set At Size 178.9 X-65 Bit # Current in Footage Mud Data Casing Summary Grade Lst *10000 units = 100% Gas In Air 5133' MD. Lay down WEI sub equipment. Rack back 5" drill pipe to 4218' MD as of midnight. No daily Brine losses noted. pumped until clean Brine was observed. Cut and slip drill line. Begin laying down 5" drill pipe and WEI subs from 10715' MD to Trip 907-685-0772 Unit Phone: N/A 24 hr Recap: N/A Background Maximum 0 0 000 Depth Units* Gas Summary C-2 0 md. Average 0 C-4n 0 per detail to set the packer. Test, OK. Unsting. TOL: 10,5788'. Displace to 9.0 lb/gal Brine at 6 bpm and 900 psi. 9000 strokes Continue running in hole with the 5.5" slotted liner from 15328' MD to 19527' MD. No daily losses noted. Drop the ball C-4i 0 Minimum Chromatograph (ppm) 00 0 0 0 Logging Engineers: Zach Beekman / Leigh Ann Rasher (max) (current) Report By: 0 Zach Beekman C-3 0 0 Connection 0 (max) N/A C-5n C-5i C-1 000 . . Density (ppg) Viscosity out (sec/qt) Lst Mud Data Casing Summary Grade L-80 ROP Set At Size 178.9 X-65 Bit # Current in Footage Area: Location: Max @ ft @4.23 Silt Siltst Tuff Rig: Job No.: Current Depth: 24 Hour Progress: Daily Charges: 96% SPP (psi) Gallons/stroke % BTC HYDRIL ROP (ft/hr) Bit Type TFA pH Flow In (gpm) Hours EVAMAR $118,440.00 Report For: Keener/Wimmer/Buchanan 19544' 19544' 0' Current Pump & Flow Data: Yesterday's Depth: Total Charges: Test BOPE's Rig Activity: Flow In (spm) $2,810.00 (ppb Eq) cP Depth in / out 160' 3118' Lithology (%) 9 5/8" Ss WOB 20" 10973' Cht 13 3/8" Sh Clyst Cly PV MBT MWD Summary Depth 19544' to 19544' Tools ENI Petroleum SP33-W3 Spy Island 24 hr Max North Slope Doyon 15 AK-AM-0009568240 Customer: Well: Avg 35 19-Jul-2012 24:00 Time: Report #: Date: Size (current) 68.0 Weight 40.0 YP 9.00 (lb/100ft 2) L-80 Make Condition 19544'KCl/NaCl Brine Depth Mud Type 28 mg/l Coal Gvl API FL Cor Solids Chlorides 69,000 ECD (ppg) Avg Min Max ml/30min RPM *10000 units = 100% Gas In Air N/A C-5n C-5i C-1 000 0 Connection 0 0 Zach Beekman C-3 0 Logging Engineers: Zach Beekman / Leigh Ann Rasher (max) (current) Report By: (max) 0 0 Chromatograph (ppm) 00 0 0 Minimum C-4i Rig up and test BOPE's per state regulations as of midnight. Rack back 5" drill pipe from 4218' MD to 3081' MD. Lay down 5" drill pipe. Run in hole with 4.5" drill pipe and lay down. md. Average 0 C-4n 0 0 Gas Summary C-2 Depth Units* 0000 0 Maximum 907-685-0772 Unit Phone: N/A 24 hr Recap: N/A Background Trip . . Density (ppg) Viscosity out (sec/qt) ml/30min RPM ECD (ppg) Avg Min Max mg/l Coal Gvl API FL Cor Solids Chlorides 69,000 KCl/NaCl Brine Depth Mud Type 28 Condition 19544' YP 9.00 (lb/100ft 2) L-80 Make (current) 68.0 40.0 Size 36 20-Jul-2012 24:00 Time: Report #: Date: ENI Petroleum SP33-W3 Spy Island 24 hr Max North Slope Doyon 15 AK-AM-0009568240 Customer: Well: Avg PV MBT MWD Summary Depth 19544' to 19544' Tools Sh Clyst Cly WOB 20" 10973' Cht 13 3/8" Weight 160' 3118' Lithology (%) 9 5/8" Ss Total Charges: RIH w/ 4.5" tubing Rig Activity: Flow In (spm) $2,810.00 (ppb Eq) cP $121,250.00 Report For: Keener/Wimmer/Buchanan 19544' 19544' 0' Current Pump & Flow Data: Yesterday's Depth: Flow In (gpm) Hours EVAMAR Depth in / out ROP (ft/hr) Bit Type TFA pH BTC HYDRIL 96% SPP (psi) Gallons/stroke % Tuff Rig: Job No.: Current Depth: 24 Hour Progress: Daily Charges: @4.23 Silt Siltst Max @ ft Area: Location: ROP Set At Size 178.9 X-65 Bit # Current in Footage Mud Data Casing Summary Grade L-80 Lst *10000 units = 100% Gas In Air Trip 907-685-0772 Unit Phone: N/A 24 hr Recap: N/A Background Maximum 0 0 000 Depth Units* Gas Summary C-2 md. Average 0 C-4n 0 4.5" completion tubing per detail to 1850' MD as of midnight. Continue to test BOPE's. Pull the test plug. Clean and clear the rig floor. Rig up 4.5" tubing equipment. Run in hole with 0 Minimum C-4i Chromatograph (ppm) 00 0 0 0 Logging Engineers: Zach Beekman / Leigh Ann Rasher (max) (current) Report By: (max) Zach Beekman C-3 0 Connection 0 0 N/A C-5n C-5i C-1 000 0 0 . . Density (ppg)Viscosity out (sec/qt) *10000 units = 100% Gas In Air 0 0 Connection 0 0 N/A C-5n Zach Beekman Mud Data C-3 Casing Summary 0 L-80 ROP Set AtSize 178.9 X-65 Bit # Current in Logging Engineers:Zach Beekman / Leigh Ann Rasher (max)(current) Report By: Grade (max) Area: Location: 0 0 Max @ ft Chromatograph (ppm) 0 Footage 0 0 Minimum Silt Siltst C-4i Lst C-5iC-1 0 @4.23 Tuff HYDRIL C-4n 000 Daily Charges: 96% SPP (psi) Gallons/stroke BOEJOKFDUJPOUVCF$MFBSSJHGMPPS/JQQMFEPXO#01&TUBDL3JHVQ7FUDPUSFF3JHVQUPGSFF[FQSPUFDUUIFXFMMBTPGNJEOJHIU.VEMPHHJOHTIBDL Continue running 4.5" competion tubing from 1850' MD to 7257' MD. Test ESP cable every 1000'. Make up tubing hanger. Splice ESP % md. Average 0 BTC 0 ROP (ft/hr) Bit Type TFA pH Yesterday's Depth: Flow In (gpm) Hours Gas Summary C-2 EVAMAR cP $125,060.00 Report For:Keener/Wimmer/Buchanan Weight PVMBT 19544' 19544' 0' Current Pump & Flow Data: Rig: Job No.: Current Depth: 24 Hour Progress: Total Charges: R/U Freeze ProtectRig Activity: Flow In (spm) $3,810.00 (ppb Eq) 160' 3118' Lithology (%) 9 5/8" Ss 20" DepthUnits* 10973' Cht 13 3/8" ShClystCly MWD Summary Depth 19544' to 19544' Tools ENI Petroleum SP33-W3 Spy Island 24 hr Max North Slope Doyon 15 AK-AM-0009568240 Customer: Well: Avg 37 21-Jul-2012 24:00Time: Report #: Date: Size WOB Depth in / out 0000 0 (current) Maximum 68.0 40.0 YP 9.00 (lb/100ft2) L-80 Make Condition 19544' 907-685-0772Unit Phone: KCl/NaCl Brine Depth Mud Type N/A 24 hr Recap: N/ABackground 28 mg/l Coal Gvl API FL Cor SolidsChlorides 69,000 ECD (ppg)Avg Min Max rigged down as of midnight per toolpusher request. Trip ml/30min RPM Well Name: Depth (MD) to ft Location: (TVD) to ft Operator:Show Report No. Show Report Report Prepared By: Formation: Report Delivered To: Date Drilled: SP33-W3 3587 1 3508 Andrew Buchanan 9988 10936 Spy Island ENI Petroleum Leigh Ann Rasher 2-Jul-12 OA Sand Top Dt h ft C1 C1 C1 C1 Hydrocarbon Ratios Producible gas within zones 2 through 4 based upon gas and chromatograph data collected. 1500Md C h l i d ( / L )5319998 Interpretation: GU i t 1 Depth ft C1 C1 C1 C1 Flowline Background Show C2 C3 C4 C5 ppm ppm ppm Hydrocarbon Ratios C1 -=C1/C2 = C2 -=C1/C3 = C3 -=C1/C4 = C4 -=C1/C5 = C5 -= 1500Mud Chlorides (mg/L) = 47 464 73 403 893 88 6012 56252 62 805 511 645 108572 531 447 44 50240 125 88 9998 Gas Units 1000 NPH Production Analysis x Gas Oil Water Non-Producible Hydrocarbons Depth ft Flowline Background Show ppm ppm ppm Hydrocarbon Ratios C1 -=C1/C2 = C2 -=C1/C3 = 1500 29 33 Mud Chlorides (mg/L) = 204 10152 9358 113 88 6012 Gas Units 3346 116 2 10 100 Gas C3 -=C1/C4 = C4 -=C1/C5 = C5 -= Production Analysis x Gas Oil Water Non-Producible Hydrocarbons Depth ft C1 C1 C1 C1 Flowline Background Show C2 C3 C4 C5 ppm ppm ppm Mud Chlorides (mg/L) =1500 101 120 20 3054 28 67 47 44 193 73 145 10871 167 Gas Units Hydrocarbon Ratios3 1 Oil NPH pp pp pp Hydrocarbon Ratios C1 -=C1/C2 = C2 -=C1/C3 = C3 =C1/C4 = C4 -=C1/C5 = C5 -= Production Analysis x Gas Oil Water Non-Producible Hydrocarbons 4026 214263 404639 69 5473 3106 217962 3699 85 107 72 55142 2964 47 3919 4570 4 5388 100 1000 NPH Depth ft Flowline Background Show ppm ppm ppm Hydrocarbon Ratios C1 -=C1/C2 = C2 -=C1/C3 = C3 -=C1/C4 = C4 -=C1/C5 = Mud Chlorides (mg/L) =1500 3699 3941 107 3834 5479 222116 3059 142 4726 69 10936 2917 57 47 85 5394 40 75 218417 3095 4657 Gas Units 4 10 NPH Oil Gas C5 -= Production Analysis x Gas Oil Water Non-Producible Hydrocarbons 3941 107 3834 1 NPH Well Name: Depth (MD) to ft Location: (TVD) to ft Operator:Show Report No. Show Report Report Prepared By: Formation: Report Delivered To: Date Drilled: SP33-W3 3603 2 3594 Andrew Buchanan 11513 12131 Spy Island ENI Petroleum Leigh Ann Rasher 9-Jul-12 OA Sands Dt h ft C1 C1 C1 C1 Hydrocarbon Ratios No producible oil within these zones based upon gas and chromatograph data collected. 89000Md C h l i d ( / L )76911513 Interpretation: GU i t 1 Depth ft C1 C1 C1 C1 Flowline Background Show C2 C3 C4 C5 ppm ppm ppm Hydrocarbon Ratios C1 -=C1/C2 = C2 -=C1/C3 = C3 -=C1/C4 = C4 -=C1/C5 = C5 -= 89000Mud Chlorides (mg/L) = 80 180 164 619 961 61 1028 83711 92 900 260 691 459527 769 722 103 82683 134 157 11513 Gas Units 1000 NPH Production Analysis Gas Oil Water x Non-Producible Hydrocarbons Depth ft Flowline Background Show ppm ppm ppm Hydrocarbon Ratios C1 -=C1/C2 = C2 -=C1/C3 = 89000 96 139 Mud Chlorides (mg/L) = 1025 11580 96499 878 57 3636 Gas Units 92863 968 2 10 100 Gas C3 -=C1/C4 = C4 -=C1/C5 = C5 -= Production Analysis Gas Oil Water x Non-Producible Hydrocarbons Depth ft C1 C1 C1 C1 Flowline Background Show C2 C3 C4 C5 ppm ppm ppm Mud Chlorides (mg/L) =86000 667 195 298 778 476 374 76 86 339 144 753 12066 312 Gas Units Hydrocarbon Ratios3 1 Oil NPH pp pp pp Hydrocarbon Ratios C1 -=C1/C2 = C2 -=C1/C3 = C3 =C1/C4 = C4 -=C1/C5 = C5 -= Production Analysis Gas Oil Water x Non-Producible Hydrocarbons 394 66824 112886 109 698 343 74881 8057 103 82 323 214136 207 86 312 777 4 595 100 1000 NPH Depth ft Flowline Background Show ppm ppm ppm Hydrocarbon Ratios C1 -=C1/C2 = C2 -=C1/C3 = C3 -=C1/C4 = C4 -=C1/C5 = Mud Chlorides (mg/L) =86000 6163 421 160 261 775 92747 376 298 1021 163 12131 78 332 101 205 570 152 1110 86584 868 858 Gas Units 4 10 NPH Oil Gas C5 -= Production Analysis Gas Oil Water x Non-Producible Hydrocarbons 421 160 261 1 NPH Well Name: Depth (MD) to ft Location: (TVD) to ft Operator:Show Report No. Show Report Report Prepared By: Formation: Report Delivered To: Date Drilled: SP33-W3 3571 3 3573 Andrew Buchanan 13089 13839 Spy Island ENI Petroleum Leigh Ann Rasher 10-Jul-12 OA Sands Dt h ft C1 C1 C1 C1 Hydrocarbon Ratios No producible oil within these zones based upon gas and chromatograph data collected. 86000Md C h l i d ( / L )141213089 Interpretation: GU i t 1 Depth ft C1 C1 C1 C1 Flowline Background Show C2 C3 C4 C5 ppm ppm ppm Hydrocarbon Ratios C1 -=C1/C2 = C2 -=C1/C3 = C3 -=C1/C4 = C4 -=C1/C5 = C5 -= 86000Mud Chlorides (mg/L) = 167 155 218 372 732 89 5146 151951 228 643 322 636 947418 1412 475 103 146805 395 351 13089 Gas Units 1000 NPH Production Analysis Gas Oil Water x Non-Producible Hydrocarbons Depth ft Flowline Background Show ppm ppm ppm Hydrocarbon Ratios C1 -=C1/C2 = C2 -=C1/C3 = 85000 254 420 Mud Chlorides (mg/L) = 802 13271 188099 1781 97 9056 Gas Units 179043 705 2 10 100 Gas C3 -=C1/C4 = C4 -=C1/C5 = C5 -= Production Analysis Gas Oil Water x Non-Producible Hydrocarbons Depth ft C1 C1 C1 C1 Flowline Background Show C2 C3 C4 C5 ppm ppm ppm Mud Chlorides (mg/L) =85000 426 103 204 975 1738 375 171 108 327 224 534 13736 878 Gas Units Hydrocarbon Ratios3 1 Oil NPH pp pp pp Hydrocarbon Ratios C1 -=C1/C2 = C2 -=C1/C3 = C3 =C1/C4 = C4 -=C1/C5 = C5 -= Production Analysis Gas Oil Water x Non-Producible Hydrocarbons 405 90645 187911 131 614 357 104249 13604 128 193 872 428253 104 116 212 780 4 486 100 1000 NPH Depth ft Flowline Background Show ppm ppm ppm Hydrocarbon Ratios C1 -=C1/C2 = C2 -=C1/C3 = C3 -=C1/C4 = C4 -=C1/C5 = Mud Chlorides (mg/L) =85000 13604 385 193 192 598 92578 339 253 860 131 13839 86 411 108 128 470 168 918 78974 973 729 Gas Units 4 10 NPH Oil Gas C5 -= Production Analysis Gas Oil Water x Non-Producible Hydrocarbons 385 193 192 1 NPH Well Name: Depth (MD) to ft Location: (TVD) to ft Operator:Show Report No. Show Report Report Prepared By: Formation: Report Delivered To: Date Drilled: SP33-W3 3562 4 3570 Andrew Buchanan 15463 16026 Spy Island ENI Petroleum Leigh Ann Rasher 11-Jul-12 OA Sands Dt h ft C1 C1 C1 C1 Hydrocarbon Ratios No producible oil within these zones based upon gas and chromatograph data collected. 75500Md C h l i d ( / L )73715463 Interpretation: GU i t 1 Depth ft C1 C1 C1 C1 Flowline Background Show C2 C3 C4 C5 ppm ppm ppm Hydrocarbon Ratios C1 -=C1/C2 = C2 -=C1/C3 = C3 -=C1/C4 = C4 -=C1/C5 = C5 -= 75500Mud Chlorides (mg/L) = 141 199 178 629 921 59 2834 78121 87 862 340 744 378566 737 719 90 75287 120 133 15463 Gas Units 1000 NPH Production Analysis Gas Oil Water x Non-Producible Hydrocarbons Depth ft Flowline Background Show ppm ppm ppm Hydrocarbon Ratios C1 -=C1/C2 = C2 -=C1/C3 = 75500 85 114 Mud Chlorides (mg/L) = 736 15556 60811 575 27 762 Gas Units 60049 709 2 10 100 Gas C3 -=C1/C4 = C4 -=C1/C5 = C5 -= Production Analysis Gas Oil Water x Non-Producible Hydrocarbons Depth ft C1 C1 C1 C1 Flowline Background Show C2 C3 C4 C5 ppm ppm ppm Mud Chlorides (mg/L) =78000 528 156 222 954 385 336 114 56 286 130 584 15944 270 Gas Units Hydrocarbon Ratios3 1 Oil NPH pp pp pp Hydrocarbon Ratios C1 -=C1/C2 = C2 -=C1/C3 = C3 =C1/C4 = C4 -=C1/C5 = C5 -= Production Analysis Gas Oil Water x Non-Producible Hydrocarbons 437 97398 1211135 45 865 388 99358 1960 60 94 350 284110 278 89 343 1090 4 805 100 1000 NPH Depth ft Flowline Background Show ppm ppm ppm Hydrocarbon Ratios C1 -=C1/C2 = C2 -=C1/C3 = C3 -=C1/C4 = C4 -=C1/C5 = Mud Chlorides (mg/L) =78000 1960 400 94 306 777 85839 350 110 1009 45 16026 240 274 87 60 717 117 349 83879 818 964 Gas Units 4 10 NPH Oil Gas C5 -= Production Analysis Gas Oil Water x Non-Producible Hydrocarbons 400 94 306 1 NPH Well Name: Depth (MD) to ft Location: (TVD) to ft Operator:Show Report No. Show Report Report Prepared By: Formation: Report Delivered To: Date Drilled: SP33-W3 3561 5 3540 Andrew Buchanan 16867 17381 Spy Island ENI Petroleum Leigh Ann Rasher 12-Jul-12 OA Sands Dt h ft C1 C1 C1 C1 Hydrocarbon Ratios No producible oil within these zones based upon gas and chromatograph data collected. 70000Md C h l i d ( / L )45016867 Interpretation: GU i t 1 Depth ft C1 C1 C1 C1 Flowline Background Show C2 C3 C4 C5 ppm ppm ppm Hydrocarbon Ratios C1 -=C1/C2 = C2 -=C1/C3 = C3 -=C1/C4 = C4 -=C1/C5 = C5 -= 70000Mud Chlorides (mg/L) = 67 143 65 428 575 17 788 46587 82 558 210 455 320390 450 457 29 45799 107 117 16867 Gas Units 1000 NPH Production Analysis Gas Oil Water x Non-Producible Hydrocarbons Depth ft Flowline Background Show ppm ppm ppm Hydrocarbon Ratios C1 -=C1/C2 = C2 -=C1/C3 = 70000 85 112 Mud Chlorides (mg/L) = 614 16990 51044 488 26 1116 Gas Units 49928 588 2 10 100 Gas C3 -=C1/C4 = C4 -=C1/C5 = C5 -= Production Analysis Gas Oil Water x Non-Producible Hydrocarbons Depth ft C1 C1 C1 C1 Flowline Background Show C2 C3 C4 C5 ppm ppm ppm Mud Chlorides (mg/L) =71000 446 144 185 788 347 261 76 40 222 78 486 17284 270 Gas Units Hydrocarbon Ratios3 1 Oil NPH pp pp pp Hydrocarbon Ratios C1 -=C1/C2 = C2 -=C1/C3 = C3 =C1/C4 = C4 -=C1/C5 = C5 -= Production Analysis Gas Oil Water x Non-Producible Hydrocarbons 405 80465 1081003 36 801 356 81607 1142 54 71 304 24191 265 83 334 967 4 747 100 1000 NPH Depth ft Flowline Background Show ppm ppm ppm Hydrocarbon Ratios C1 -=C1/C2 = C2 -=C1/C3 = C3 -=C1/C4 = C4 -=C1/C5 = Mud Chlorides (mg/L) =71000 1225 461 92 369 897 89467 404 118 1113 42 17381 286 239 82 67 830 106 309 88242 862 1071 Gas Units 4 10 NPH Oil Gas C5 -= Production Analysis Gas Oil Water x Non-Producible Hydrocarbons 461 92 369 1 NPH Well Name: Depth (MD) to ft Location: (TVD) to ft Operator:Show Report No. Show Report Report Prepared By: Formation: Report Delivered To: Date Drilled: SP33-W3 3560 6 3567 Andrew Buchanan 18457 18910 Spy Island ENI Petroleum Leigh Ann Rasher 13-Jul-12 OA Sands Dt h ft C1 C1 C1 C1 Hydrocarbon Ratios No producible oil within these zones based upon gas and chromatograph data collected. 75500Md C h l i d ( / L )93218457 Interpretation: GU i t 1 Depth ft C1 C1 C1 C1 Flowline Background Show C2 C3 C4 C5 ppm ppm ppm Hydrocarbon Ratios C1 -=C1/C2 = C2 -=C1/C3 = C3 -=C1/C4 = C4 -=C1/C5 = C5 -= 75500Mud Chlorides (mg/L) = 89 220 110 790 1131 40 2045 96397 86 1091 309 775 429665 932 848 58 94352 119 142 18457 Gas Units 1000 NPH Production Analysis Gas Oil Water x Non-Producible Hydrocarbons Depth ft Flowline Background Show ppm ppm ppm Hydrocarbon Ratios C1 -=C1/C2 = C2 -=C1/C3 = 75500 90 126 Mud Chlorides (mg/L) = 1013 18527 90720 881 20 1098 Gas Units 89622 993 2 10 100 Gas C3 -=C1/C4 = C4 -=C1/C5 = C5 -= Production Analysis Gas Oil Water x Non-Producible Hydrocarbons Depth ft C1 C1 C1 C1 Flowline Background Show C2 C3 C4 C5 ppm ppm ppm Mud Chlorides (mg/L) =75000 712 239 294 781 375 365 71 38 320 81 750 18836 305 Gas Units Hydrocarbon Ratios3 1 Oil NPH pp pp pp Hydrocarbon Ratios C1 -=C1/C2 = C2 -=C1/C3 = C3 =C1/C4 = C4 -=C1/C5 = C5 -= Production Analysis Gas Oil Water x Non-Producible Hydrocarbons 403 76550 122964 102 764 347 80305 3755 136 134 551 285208 139 89 269 862 4 628 100 1000 NPH Depth ft Flowline Background Show ppm ppm ppm Hydrocarbon Ratios C1 -=C1/C2 = C2 -=C1/C3 = C3 -=C1/C4 = C4 -=C1/C5 = Mud Chlorides (mg/L) =75000 6128 378 133 245 709 70685 324 206 886 105 18910 118 263 83 134 575 112 547 64557 705 781 Gas Units 4 10 NPH Oil Gas C5 -= Production Analysis Gas Oil Water x Non-Producible Hydrocarbons 378 133 245 1 NPH WE L L N A M E : SP 3 3 - W 3 LO C A T I O N : Spy Island OP E R A T O R : EN I P e t r o l e u m AREA:North Slope MU D C O : MI S w a c o ST A T E : Alaska RI G : Do y o n 1 5 SPUD:17-Jun-12 SP E R R Y J O B : AK - A M - 0 0 0 9 5 6 8 2 4 0 TD:13-Jul-12 BI T RE C O R D MW D BH A # SD L RU N # Bi t # B i t T y p e B i t Si z e De p t h In ( f t ) De p t h Ou t ( f t ) Fo o t a g e B i t Ho u r s TF A A V G RO P WO B (m a x ) RP M (m a x ) SP P (m a x ) FL O W G P M (m a x ) Bi t G r a d e R e m a r k s 2 1 0 0 1 R R H u g h e s M X - 1 M il l T o o t h 1 6 " 16 0 3 1 3 4 2 9 7 4 1 7 . 2 0 1 . 1 1 7 1 6 4 . 9 30 40 1 5 0 0 6 5 0 1 - 1 - W T - A - E - I - B U - T D S u r f a c e T D 3 2 0 0 2 S m i t h M D S i 7 1 6 1 2 . 2 5 " 3 1 3 4 5 1 6 2 2 0 2 8 2 6 . 5 0 1 . 1 6 7 7 6 . 4 15 15 0 1 4 5 0 8 0 0 4- 6 - B T - S - X - 2 - R O - R O P Beginnings of ringing out on shoulder 4 3 0 0 3 S m i t h G F 1 5 B I n s e r t 1 2 . 2 5 " 5 1 6 2 8 6 5 1 3 4 9 0 4 9 . 6 0 1 . 1 1 6 7 0 . 4 25 10 0 2 0 0 0 9 0 0 2- 2 - W T - A - E - 1 - B T - D T F Downhole tool failure 5 4 0 0 4 H y c a l o g M 4 6 8 5 C P M il l T o o t h 1 2 . 2 5 " 86 5 1 1 0 9 8 8 2 3 3 7 2 4 . 1 0 1 . 1 1 6 9 7 . 0 25 12 0 2 7 5 0 9 0 0 2- 1 - W T - A - E - I - N O - T D Intermediate TD 6 5 0 0 5 H y c a l o g S K H 6 1 6 M - E I D P D C 8 . 7 5 " 1 0 9 8 8 1 9 5 4 4 8 5 5 6 6 6 . 3 0 0 . 9 0 2 12 9 . 1 8 1 4 0 3 8 0 0 5 5 0 1 - 2 - B T - A - X - I - C T - T D P r o d u c t i o n T D WE L L N A M E : L O C A T I O N : OP E R A T O R : A R E A : MU D C O : S T A T E : RI G : S P U D : SP E R R Y J O B : T D : Mu d R e c o r d W a t e r B a s e d M u d R e c o r d 16 0 ' t o 3 1 3 4 ' 31 3 4 ' t o 1 0 9 8 8 ' Da t e D e p t h W t V i s P V Y P G e l s F i l t R6 0 0 / R 3 0 0 / R 2 0 0 / R 1 0 0 / R6 / R 3 Ca k e S o l i d s Oi l / W a t e r Sd P m p H M B T P f / M f C h l o r H a r d R e m a r k s ft - M D p p g s e c l b / 1 0 0 l b / 1 0 0 f t 2 m / 3 0 m R h e o m e t e r 3 2 n d s % v o l % v o l m g / l C a + + 16 - J u n 1 6 0 8 . 7 0 1 2 0 3 9 4 4 1 4 / 2 2 / 2 8 6 . 0 1 2 2 / 8 3 / 6 5 / 4 5 / 1 7 / 1 3 1 / - 3 . 0 1/ 9 6 0 . 0 0 0 . 2 5 9 . 3 1 8 . 0 . 1 3 / . 3 0 6 0 0 4 0 S t r a p B H A i n s h e d 17 - J u n 6 6 0 9 . 0 0 8 7 2 9 3 1 1 7 / 3 4 / 4 8 5 . 4 8 9 / 6 0 / 4 9 / 3 6 / 1 7 / 1 5 2 / - 4 . 0 1 / 9 5 0 . 0 0 0 . 1 5 9 . 6 1 7 . 5 . 0 9 / . 4 0 2 4 0 0 1 2 0 D r ill 16" Surface 18 - J u n 2 7 1 0 9 . 5 0 1 0 1 3 1 3 7 1 8 / 4 7 / 6 2 4 . 7 9 9 / 6 8 / 5 5 / 4 0 / 1 8 / 1 6 2 / - 6 . 5 . 7 5 / 9 2 . 7 5 0 . 7 5 0 . 0 5 9 . 1 2 1 . 0 . 0 3 / . 3 5 1 9 0 0 8 0 D r ill 16" Surface 19 - J u n 3 1 3 4 9 . 5 0 6 5 2 2 2 6 1 7 / 5 2 / 6 4 4 . 8 7 0 / 4 8 / 3 9 / 2 9 / 1 6 / 1 4 2 / - 6 . 5 . 5 / 9 3 0 . 5 0 0 . 1 6 9 . 8 1 9 . 0 . 0 8 / . 4 0 1 4 0 0 6 0 L / D B H A 20 - J u n 3 1 3 4 9 . 5 0 7 3 2 8 2 3 9 / 2 5 / 3 7 - 7 9 / 5 1 / 4 0 / 2 8 / 1 0 / 8 - - - - - 9 . 0 - - - - R / U C m t H e a d 21 - J u n 3 1 3 4 9 . 5 0 5 4 2 2 1 4 6 / 8 / 1 1 - 5 8 / 3 6 / 2 6 / 1 9 / 6 / 5 - - - - - 8 . 3 - - - - W o r k o n t o p d r i v e 22 - J u n 3 1 3 4 9 . 5 0 5 2 2 2 1 3 6 / 8 / 1 2 - 5 7 / 3 5 / 2 6 / 1 8 / 6 / 5 - - - - - 8 . 3 - - - - N i p p l e u p B O P ' s 23 - J u n 3 1 3 4 9 . 3 0 4 3 2 2 1 1 6 / 8 / 1 4 - 5 5 / 3 3 / 2 5 / 1 7 / 6 / 5 - - - - - 1 0 . 1 - - - - P r e p t o d i s p l a c e 24 - J u n 4 1 9 3 1 0 . 3 0 5 5 1 1 2 7 1 1 / 1 7 / 1 9 5 . 6 4 9 / 3 8 / 3 2 / 2 5 / 1 2 / 1 0 1 / - 4 . 5 1 . 5 / 9 4 0 . 1 0 0 . 2 5 1 0 . 3 5 . 5 . 1 5 / . 9 0 7 0 0 4 0 D r ill 12.25" Int 25 - J u n 5 1 6 1 9 . 2 0 5 8 1 5 3 3 1 4 / 2 6 / 3 2 4 . 5 6 3 / 4 8 / 4 2 / 3 3 / 1 5 / 1 3 1 / - 4 . 5 2. 2 5 / 9 3 . 2 5 0. 1 5 0 . 1 5 9 . 6 1 2 . 0 . 1 1 / . 8 5 9 5 0 6 0 B R O O H 26 - J u n 5 1 6 1 9 . 2 0 5 8 1 5 2 8 1 3 / 2 4 / 3 0 4 . 6 5 8 / 4 3 / 3 7 / 2 8 / 1 3 / 1 1 1 / - 4 . 8 2 / 9 3 . 2 0 . 1 5 0 . 1 8 9 . 8 1 4 . 0 . 1 5 / . 9 0 9 0 0 6 0 R I H B H A # 4 27 - J u n 6 7 1 7 9 . 3 0 5 7 1 5 3 4 1 5 / 2 6 / 3 5 4 . 4 6 4 / 4 9 / 4 2 / 3 2 / 1 4 / 1 2 2/ - 5 . 2 2 / 9 3 1 . 0 0 0 . 2 0 9 . 5 1 6 . 0 . 1 0 / 1 . 0 0 1 1 0 0 6 0 D r ill 12.25" Int 28 - J u n 7 9 0 0 9 . 3 0 5 9 1 6 2 9 1 5 / 3 0 / 4 4 4 . 6 6 1 / 4 5 / 3 8 / 2 9 / 1 4 / 1 2 1 / - 5 . 6 2 / 9 3 0 . 1 0 0 . 2 0 9 . 7 1 5 . 5 . 1 4 / . 8 0 1 5 0 0 6 0 D r ill 12.25" Int 29 - J u n 8 6 5 1 9 . 3 0 5 9 1 7 2 8 1 4 / 2 6 / 3 4 4 . 5 6 2 / 4 5 / 4 0 / 3 0 / 1 4 / 1 2 1 / - 5 . 2 3 / 9 2 0 . 1 0 0 . 2 5 9 . 6 1 6 . 0 . 1 8 / . 8 0 1 5 0 0 6 0 B R O O H 30 - J u n 8 6 5 1 9 . 3 0 6 0 1 8 3 1 1 5 / 3 1 / 4 4 4 . 6 6 7 / 4 9 / 4 2 / 3 1 / 1 4 / 1 2 1 / - 5 . 8 3 / 9 2 0 . 1 0 0 . 1 5 9 . 5 1 7 . 5 . 0 8 / . 7 0 1 5 0 0 6 0 R I H B H A # 5 1- J u l 9 2 7 0 9 . 6 0 5 7 1 5 2 8 1 4 / 2 9 / 3 9 4 . 8 5 8 / 4 3 / 3 7 / 2 8 / 1 4 / 1 1 1 / - 5 . 8 2 / 9 2 0 . 1 0 0 . 2 0 9 . 6 1 7 . 5 . 1 0 / . 7 0 1 4 0 0 6 0 D r ill 12.25" Int 2- J u l 1 0 9 8 8 9 . 5 0 5 6 1 7 2 8 1 4 / 2 8 / 4 7 4 . 2 6 2 / 4 5 / 3 8 / 2 9 / 1 3 / 1 1 2 / - 7 . 0 3 / 9 1 0 . 1 0 0 . 1 5 9 . 5 1 8 . 0 . 1 0 / . 9 0 1 5 0 0 6 0 B R O O H 3- J u l 1 0 9 8 8 9 . 5 0 5 2 1 5 2 6 1 2 / 2 6 / 4 3 4 . 2 5 6 / 4 1 / 3 3 / 2 5 / 1 3 / 1 1 1 / - 7 . 4 2 / 9 1 0 . 1 0 0 . 2 0 9 . 6 1 8 . 0 . 1 5 / . 7 0 1 4 0 0 6 0 B R O O H 4- J u l 1 0 9 8 8 9 . 4 0 5 1 1 3 2 3 1 1 / 1 9 / 2 5 5 . 4 4 9 / 3 6 / 2 9 / 2 3 / 1 1 / 9 1 / - 6 . 0 2 / 9 2 0. 1 0 0 . 0 9 9 . 2 1 7 . 5 . 0 6 / 1 . 1 0 1 3 0 0 6 0 R I H w / 9 5 / 8 " c a s i n g 5- J u l 1 0 9 8 8 9 . 4 0 4 5 1 1 1 6 8 / 1 1 / 1 4 5 . 8 3 8 / 2 7 / 2 4 / 1 8 / 8 / 6 1 / - 6 . 0 2 / 9 2 - 0 . 0 7 9 . 0 1 5 . 0 . 0 4 / 1 . 0 0 1 3 0 0 6 0 C m t 9 5 / 8 " c a s i n g 6- J u l 1 0 9 8 8 9 . 4 0 4 6 1 2 1 5 9 / 1 2 / 1 8 5 . 8 3 9 / 2 7 / 2 5 / 1 8 / 9 / 7 1 / - 6 . 0 2 / 9 2 - 0 . 0 7 9 . 0 1 5 . 0 . 0 4 / 1 . 0 0 1 3 0 0 6 0 T e s t B O P ' s Oi l B a s e d M u d R e c o r d 10 9 8 8 ' t o 1 9 5 4 4 ' Da t e D e p t h W t V i s P V Y P G e l s F i l t R6 0 0 / R 3 0 0 / R 2 0 0 / R 1 0 0 / R6 / R 3 Ca k e Co r r . So l i d s Oi l / W a t e r Oi l P m L i m e S a l t C l - Em u l St a b i l i t y S d R e m a r k s ft - M D p p g s e c l b / 1 0 0 l b / 1 0 0 f t 2 m / 3 0 m R h e o m e t e r 3 2 n d s % v o l % v o l l b / b b l % W t m g / L m g / l % v o l 7- J u l 1 0 9 7 3 9 . 4 5 4 6 1 6 1 2 6 / 7 / 7 5 . 7 4 4 / 2 8 / 2 3 / 1 7 / 7 / 6 - / 2 8 . 8 6 5 / 3 5 5 6 2 . 8 0 3 . 6 4 3 3 . 1 0 9 8 0 0 0 4 7 2 - R I H 8- J u l 1 0 9 7 3 9 . 4 5 4 7 1 5 1 3 6 / 7 / 7 5 . 0 4 3 / 2 8 / 2 4 / 1 7 / 7 / 6 - / 2 1 3 . 0 6 4 / 3 6 5 6 3 . 0 0 3 . 9 0 3 3 . 1 0 9 8 0 0 0 4 7 5 - C i r c t o p e r f o r m L O T 9- J u l 1 2 5 6 0 9 . 4 0 4 7 1 4 1 6 7 / 7 / 8 4 . 7 4 4 / 3 0 / 2 3 / 1 7 / 7 / 6 - / 2 9 . 9 6 6 6 / 3 4 5 7 2 . 6 0 3 . 3 8 3 0 . 8 6 8 5 0 0 0 8 5 0 - D r ill 8.75" Prod 10 - J u l 1 4 7 0 7 9 . 4 0 4 4 1 3 1 4 6 / 7 / 7 4 . 8 4 0 / 2 7 / 2 1 / 1 5 / 7 / 6 - / 2 1 0 . 5 6 6 / 3 4 5 7 2 . 2 0 2 . 8 6 2 8 . 8 0 7 6 0 0 0 7 2 0 - D r ill 8.75" Prod 11 - J u l 1 6 5 1 1 9 . 4 0 4 5 1 5 1 3 6 / 7 / 7 4 . 4 4 3 / 2 8 / 2 2 / 1 6 / 6 / 6 - / 2 1 1 . 0 6 6 / 3 4 5 7 1 . 8 0 2 . 3 4 2 7 . 6 3 7 1 0 0 0 7 9 5 0 . 1 5 D r ill 8.75" Prod 12 - J u l 1 7 9 1 2 9 . 4 0 4 5 1 4 1 3 6 / 7 / 7 4 . 6 4 1 / 2 7 / 2 1 / 1 5 / 6 / 6 - / 2 1 0 . 9 6 7 / 3 3 5 8 2 . 9 0 3 . 7 7 2 9 . 5 4 7 5 0 0 0 8 8 2 0 . 1 5 D r ill 8.75" Prod 13 - J u l 1 9 5 4 4 9 . 4 0 4 5 1 4 1 4 6 / 6 / 7 4 . 7 4 2 / 2 8 / 2 2 / 1 5 / 6 / 6 - / 2 1 1 . 7 6 7 / 3 3 5 8 2 . 1 5 2 . 8 0 2 8 . 1 2 7 0 0 0 0 8 3 0 0 . 1 5 B R O O H 14 - J u l 1 9 5 4 4 9 . 4 0 4 6 1 4 1 5 6 / 7 / 7 4 . 8 4 3 / 2 9 / 2 3 / 1 6 / 6 / 6 - / 2 1 1 . 9 6 7 / 3 3 5 8 2 . 5 0 3 . 2 5 3 0 . 3 8 7 7 5 0 0 7 7 5 0 . 1 0 B R O O H 15 - J u l 1 9 5 4 4 9 . 4 0 4 6 1 4 1 4 6 / 6 / 7 4 . 7 4 2 / 2 8 / 2 2 / 1 6 / 6 / 6 - / 2 1 1 . 2 6 7 / 3 3 5 8 2 . 4 5 3 . 1 9 3 1 . 5 8 8 2 0 0 0 9 1 0 0 . 1 0 C / O S a v e r S u b 16 - J u l 1 9 5 4 4 9 . 4 0 4 6 1 4 1 4 6 / 6 / 7 - 4 2 / 2 8 / 2 2 / 1 7 / 6 / 6 - / - 1 1 . 2 6 7 / 3 3 5 8 2 . 2 0 2 . 8 6 3 1 . 0 5 8 0 0 0 0 8 9 0 - C l e a n R i g F l o o r 17 - J u l 1 9 5 4 4 9 . 4 0 5 8 1 4 1 2 5 / 6 / 6 - 4 0 / 2 6 / 2 0 / 1 5 / 6 / 5 - / - 1 1 . 7 6 7 / 3 3 5 8 2 . 4 0 3 . 1 2 3 1 . 5 8 8 2 0 0 0 3 5 0 - R I H 5 . 5 " L i n e r 18 - J u l 1 9 5 4 4 9 . 0 0 2 8 - - - - - - - - - - - - 6 9 0 0 0 - - D i s p l a c e t o B r i n e 19 - J u l 1 9 5 4 4 9 . 0 0 2 8 - - - - - - - - - - - - 6 9 0 0 0 - - L a y D o w n 5 " D r ill Pipe 20 - J u l 1 9 5 4 4 9 . 0 0 2 8 - - - - - - - - - - - - 6 9 0 0 0 - - T e s t B O P ' s 21 - J u l 1 9 5 4 4 9 . 0 0 2 8 - - - - - - - - - - - - 6 9 0 0 0 - - R I H w / C o m p l e t i o n T u b i n g SP 3 3 - W 3 EN I P e t r o l e u m MI S w a c o Do y o n 1 5 9 5 / 8 " I n t e r m e d i a t e @ 1 0 , 9 7 3 ' M D Su r f a c e S e c t i o n Fa z e P r o MI S p u d M u d LS N D AK - A M - 0 0 0 9 5 6 8 2 4 0 13 3 / 8 " S u r f a c e @ 3 , 1 1 8 ' M D Ca s i n g R e c o r d Pr o d u c t i o n S e c t i o n In t e r m e d i a t e S e c t i o n Sp y I s l a n d No r t h S l o p e Al a s k a 17 - J u n - 1 2 13 - J u l - 1 2 20 " C o n d u c t o r @ 1 6 0 ' M D Marker MD INC AZ TVD TVDSS 16" Surface Borehole 20" Conductor Shoe 160.0 0.9 167.8 160.0 -106.1 SV-4 772.0 16.3 178.5 765.2 -711.3 SV-3 1,172.0 36.4 175.5 1,115.1 -1,061.2 SV-2 1,500.0 42.7 173.5 1,370.8 -1,316.9 Permafrost Base 2,020.0 43.3 173.4 1,755.5 -1,701.6 SV-1 2,273.0 51.4 172.4 1,921.0 -1,867.1 Ugnu Top (UG4)2,786.0 54.0 206.8 2,235.1 -2,181.2 13 3/8" Casing Shoe 3,118.0 58.1 222.9 2,421.8 -2,367.9 TD 16" Borehole 3,134.0 58.2 223.5 2,430.3 -2,376.4 12 1/4" Intermediate Borehole UG-2 Coal Bed Marker 4,085.0 83.8 240.2 2,709.7 -2,655.8 Int Fault 1 6,685.0 82.1 240.0 3,049.7 -2,995.8 Int Fault 2 7,129.0 82.0 237.0 3,110.9 -3,057.0 Lower Ugnu 7,774.0 82.6 240.1 3,199.7 -3,145.8 Int Fault 3 7,952.0 80.8 243.4 3,225.0 -3,171.1 Schrader Bluff 8,890.0 81.3 267.6 3,367.5 -3,313.6 N Sequence Top 9,270.0 82.9 277.3 3,416.5 -3,362.6 N Sand Bottom 9,683.0 82.2 290.6 3,468.5 -3,414.6 N Sequence Base 10,188.0 83.3 307.0 3,534.5 -3,480.6 OA Sand Top 10,833.0 86.8 310.0 3,582.2 -3,528.3 OA-sbl2 10,988.0 87.3 309.1 3,590.1 -3,536.2 9 5/8" Intermediate Casing 10,973.0 87.3 309.3 3,589.2 -3,535.3 TD 12 1/4" Borehole 10,988.0 87.3 309.1 3,589.9 -3,536.0 8 3/4" Lateral Borehole OA-sbl3 11,126.0 87.6 308.5 3,595.4 -3,541.5 OA-sbl3 12,496.0 92.9 311.6 3,591.9 -3,538.0 OA-sbl2 12,742.0 92.3 311.6 3,581.0 -3,527.1 OA-sbl2 13,890.0 87.8 307.1 3,572.8 -3,518.9 OA-sbl3 14,004.0 87.6 308.2 3,577.6 -3,523.7 Fault A 15,337.0 91.2 308.9 3,574.5 -3,520.6 OA Sand Top 15,563.0 92.2 309.1 3,564.8 -3,510.9 OA Sand Top 15,720.0 88.4 309.0 3,563.9 -3,510.0 Fault B 15,800.0 88.9 309.3 3,565.8 -3,511.9 Fault C 16,444.0 93.8 311.7 3,549.0 -3,495.1 OA Sand Top 16,545.0 93.6 311.4 3,542.5 -3,488.6 OA Sand Top 16,803.0 86.3 311.2 3,543.7 -3,489.8 Fault D 16,910.0 87.3 312.1 3,549.7 -3,495.8 OA-sbl3 18,214.0 90.9 313.6 3,570.6 -3,516.7 Fault E 18,289.0 91.0 311.4 3,569.4 -3,515.5 OA-sbl3 18,659.0 91.5 311.6 3,563.2 -3,509.3 OA-sbl2 18,758.0 90.0 310.1 3,562.0 -3,508.1 OA Sand Top 19,015.0 89.9 310.5 3,562.0 -3,508.1 OA Sand Top 19,281.0 87.7 311.3 3,566.5 -3,512.6 OA-sbl2 19,328.0 88.5 312.1 3,567.9 -3,514.0 OA-sbl3 19,368.0 89.0 312.7 3,569.1 -3,515.2 TD 8 3/4" Borehole 19,544.0 88.4 314.0 3,571.7 -3,517.8 SP33-W3 Interpolated Tops 0 1000 2000 3000 4000 5000 6000 7000 8000 9000 10000 11000 12000 13000 14000 15000 16000 17000 18000 19000 20000 0 4 8 12 16 20 24 28 32 36 40 Me a s u r e d D e p t h Rig Days Prognosed Actual SP33-W3 Days vs. Depth 19 Jun 2012 Reached surface TD at 0300 hrs 3134' MD / 2431' TVD 5 Jul 2012 Run & Land 9 5/8" casing to 10973' MD 9 Jul 2012 RIH, FIT 13.0 ppg EMW, Drill ahead 20 Jun 2012 Run & Land 13 3/8" casing to 3078' MD 23 Jun 2012 RIH, LOT 12.6 ppg EMW, Drill ahead 15 Jun 2012 SDL rig up unit and gas equipment 17 Jun 2012 Pre Spud meeting and spud the well 29 Jun 2012 POOH at8651' MD due to Xceed tool failure 25 Jun 2012 POOH at 5168' MD for bit trip due to low ROP 2 Jul 2012 Reached intermediate TD at 2045 hrs 10988' MD / 3590' TVD 13 Jul 2012 Reached production TD at 1800 hrs 19544' MD/ 3577' TVD Surface Data Logging After Action Review Employee Name: Leigh Ann Rasher Date: 20-Jul-2012 Well: SP33-W3 Hole Section: Production What went as, or better than, planned: All of our equipment functioned properly and there were no issues with INSITE. Difficulties experienced: Early during the well there were communication problems with GCI. The GCI employee came into the unit but did not set up the internet and local area network connections correctly. This caused the fourth computer to have issues WITS data to Petrolink and kicked it off the local area network. Also, the internet and phone were down for a few nights so unable to update daily reports with Petrolink. During the intermediate section, the rig lost power creating a small data gap on the log. Also, we are still experiencing moisture throughout the poly flow lines. Recommendations: In future wells, ensure that the local area connection and internet on the computers are hooked up correctly so there won't be any interuptions with data being sent through WITS. During the next rig move, the vortex cooler is to be installed to help reduce the amount of moisture in the poly flow lines. Innovations and/or cost savings: None for this section.