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211-127
1 Gluyas, Gavin R (OGC) From:Rixse, Melvin G (OGC) Sent:Thursday, January 16, 2025 3:34 PM To:Keith Lopez Cc:Sara Hannegan; Lau, Jack J (OGC) Subject:20250116 1530 APPROVAL PTD 211-127 Nikaitchuq SP23-N03 sundry 324-696 question Attachments:NIK SP23 10-403 Dec 2024 Approval.pdf Keith, Hilcorp is approved to PU and run 5” work string on Rig Up #2 on sundry 324-696. VBR BOPE test will be required to test on 2-7/8” and 5” test joints. Mel Rixse Senior Petroleum Engineer (PE) Alaska Oil and Gas Conservation Commission 907-793-1231 OƯice 907-297-8474 Cell CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Mel Rixse at (907-793-1231 ) or (Melvin.Rixse@alaska.gov). cc. Jack Lau, Sara Hannegan From: Keith Lopez <Keith.Lopez@hilcorp.com> Sent: Thursday, January 16, 2025 1:47 PM To: Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov> Cc: Sara Hannegan <shannegan@hilcorp.com>; Keith Lopez <Keith.Lopez@hilcorp.com> Subject: RE: [EXTERNAL] PTD 211-127 Nikaitchuq SP23-N03 sundry 324-696 question Mr. Rixse Hilcorp has decided to use a 5” work string (instead of 2-7/8”) for fishing and cementing operations on SP23. On the second RWO operation, we will test the BOP with our 2-7/8” x 5” VBR’s on both a 2-7/8” test joint and 5” test joint. Please let me know if the AOGCC needs any additional information. Thank you. Keith Lopez Operations Engineer – Western North Slope CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. 2 Office: 907-777-8438 Cell: 907-903-5432 keith.lopez@hilcorp.com From: Keith Lopez <keith.lopez@hilcorp.com> Sent: Thursday, December 26, 2024 2:51 PM To: Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov> Cc: Sara Hannegan <shannegan@hilcorp.com>; Keith Lopez <Keith.Lopez@hilcorp.com> Subject: RE: [EXTERNAL] PTD 211-127 Nikaitchuq SP23-N03 sundry 324-696 question Mr. Rixse, What is the Vault procedure? The procedure refers to using the recommended procedure of our wellhead contractor (Vault) for setting and retrieving the BPV and blanking plug. What is the expected cement volume for the IC patch squeeze? We have not landed on an expected volume of cement yet. This may depend on the caliper information and whether we plan to perf and squeeze the patch or if it has to be milled and retrieved. Once the production formation is isolated, injectivity tests may be conducted to inform the design volume. What will be the work string in step #33. Throughout this program we plan to use the 2-7/8” 6.5# Hyd563 production tubing as the work string. Will the VBRs only be closing on 2-7/8” pipe bodies? Yes, the 2-7/8” work string. What are the size ranges for the VBRs? We will be using a set of 2-7/8” x 5” VBR’s. Please let me know if you need additional information. Thank you. Keith Lopez Operations Engineer – Western North Slope Office: 907-777-8438 Cell: 907-903-5432 keith.lopez@hilcorp.com From: Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov> Sent: Monday, December 23, 2024 3:36 PM To: Keith Lopez <keith.lopez@hilcorp.com> Subject: [EXTERNAL] PTD 211-127 Nikaitchuq SP23-N03 sundry 324-696 question Keith, What is the Vault procedure? What is the expected cement volume for the IC patch squeeze? CAUTION: External sender. DO NOT open links or attachments from UNKNOWN senders. 3 What will be the work string in step #33. Will the VBRs only be closing on 2-7/8” pipe bodies? What are the size ranges for the VBRs? Mel Rixse Senior Petroleum Engineer (PE) Alaska Oil and Gas Conservation Commission 907-793-1231 OƯice 907-297-8474 Cell CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Mel Rixse at (907-793-1231 ) or (Melvin.Rixse@alaska.gov). The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please immediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. 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): 14,021 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, ADL0388583, ADL0391283 211-127 C.O. 639 NIKAITCHUQ SP23-N03 3800 Centerpoint Dr, Suite 1400 Anchorage, AK 99503 50-629-23456-00-00 Hilcorp Alaska, LLC Length Size Proposed Pools: 3,806 13,967 3,807 1,326 SCHRADER BLUFF OIL SCHRADER BLUFF OIL 160' 160' 6.5# / L-80 TVD Burst 5,978' MD NA NA 6,369' 5,020psi 5,750psi 2,480' 3,895' 3,807' 2,748' 6,369' Slotted Liner 160' 20" 13-3/8" 9-5/8" 2,748' 5-1/2"7,598' Slotted Liner 907-777-8438 keith.lopez@hilcorp.com Operations Manager January 1, 2025 2-7/8" Perforation Depth MD (ft): NIKAITCHUQ SLXP Liner Hanger Packer, four oil swell packers, and NA 6,005' MD/ 3,874' TVD, see schematic for swell packers, and NA NA 13,967' 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 12:52 pm, Dec 12, 2024 Digitally signed by Sara Hannegan (2519) DN: cn=Sara Hannegan (2519) Date: 2024.12.12 10:38:08 - 09'00' Sara Hannegan (2519) 324-696 SFD 12/13/2024 DSR-12/16/24MGR23DEC2024 * BOPE test to 3500 psi. Annular to 2500 psi. * All workstring operations to be performed with 2-7/8" pipe body tubulars. * Pipe ram size of 2-7/8" X 5" approved for operations. 10-404 MEUIRUMOF Gregory C. Wilson Digitally signed by Gregory C. Wilson Date: 2024.12.27 14:27:58 -09'00'12/27/24 Well: SP-23 PTD: 211-127 API: 50-629-23456-00-00 Well Name:SP-23 API Number:50-629-23456-00-00 Current Status:Producer Rig:Doyon 15 Estimated Start Date:01/1/2025 Estimated Duration:15 days Regulatory Contact:Darci Horner Permit to Drill Number:211-127 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: 1,713 psi @ 3,871’ TVD |8.5 PPGE Max Potential Surface Pressure: 1,326 psi Gas Column Gradient (0.1 psi/ft) Max Angle: 86° Sail Angle from 5,235’ MD to ESP setting depth of 5,978’ MD Brief Well Summary: SP23 was drilled and completed in January 2013 as a Schrader Bluff OA producer with an ESP completion. A second lateral to the well was added in March 2021 and an ESP installed. A RWO was conducted in May 2024 to replace the ESP and the well came on at 100% WC. A second RWO in July 2024 found a casing leak @ 4,615 and gravel in the wellbore. An expandable casing patch was set and the well came back online for 10 days before the water returned. The zone at the casing leak depth is capable of flowing >4,000 bwpd. Objectives: Pull ESP completion, mill out patch, cement squeeze casing leak, set a new patch, run VAC tool to remove sand from ESP setting depth and 1,800’ into liner top, run new ESP completion. Notes Regarding Wellbore Condition: x Expandable casing patch installed @ 4,615’ in July 2024. x Casing test of patch and 9-5/8” passed to 1500 psi for 30 minutes on 07/01/24. x It is likely that the casing patch has failed. 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 (45 bbls) of injection water inhibited with biocide. b. Pump 130% annulus volume (520 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. Well: SP-23 PTD: 211-127 API: 50-629-23456-00-00 9. Run 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 2-7/8” test joint with blanking plug. 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 injection water inhibited with biocide down the annulus throughout the operations to maintain well kill. 15. POOH with 2-7/8” ESP completion laying down 1,800’ of tubing and standing back the rest. Lay down ESP. Record number of clamps recovered. 16. RU Slickline with PCE and lubricator. 17. RIH with eline 60 arm caliper to deviation to evaluate condition of expandable casing patch and casing. 18. RIH with 4,100’ of 2-7/8” tubing as kill string. 19. Land tubing hanger and lay down landing joint. 20. Set BPV. 21. ND BOPE and NU tree. 22. RDMO Doyon 15. Brief RWO Procedure – RU #2 23. MIRU Doyon 15 WO Rig, ancillary equipment, and lines. 24. Kill well by bullheading the tubing string and the IA while monitoring the OA. 25. Flow check for 30 min to ensure the well is killed. 26. Nipple down X-mas tree. 27. Make up blanking plug on top of tubing hanger as per Vault procedure. 28. Nipple up BOP. 29. Run 2-7/8” test joint and engage tubing hanger blanking plug. b. 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. 30. Pull 2-7/8” test joint with blanking plug. 31. Pull BPV from the tubing hanger per Vault procedure. 32. POOH w/ 2-7/8” kill string standing back. 33. RIH with perf guns and perforate expandable casing patch @ 4,630’ or mill out and retrieve casing patch. 34. RIH and 9-5/8” HEX on 2-7/8” tubing and set at 4,675’. Circulate sand on top of plug. 35. RIH with 9-5/8” packer on 2-7/8” tubing and set at 4,585’. Pressure test IA to 1,500 psi. Conduct injection test into damaged casing zone. 36. MIRU Halliburton cement pump and bulk unit. Mix up Class G cement with additives in bulk unit (volume TBD). Cement squeeze casing leak to 1,500 psi. If cement at the leak does not begin building pressure, conduct hesitation squeeze as necessary. 37. Release packer and reverse circulate clean. 38. RDMO Halliburton cement. 39. POOH with 9-5/8” packer on 2-7/8” tubing. Well: SP-23 PTD: 211-127 API: 50-629-23456-00-00 40. RIH with 8.625” rock bit and 9 x 5-1/2” drill collars and tag cement top after cure time. Drillout cement to top of sand on HEX plug. POOH and lay down bit and drill collars. 41. Pressure test casing to 1,500 psi for 30 minutes. 42. RIH with HEX plug retrieving tool. Circulate sand off HEX plug @ 4,675’. Latch, release, and POOH with HEX plug. 43. RIH with 9-5/8” Saltel casing patch on 2-7/8” tubing to 4,635’ (20’ below expected patch setting depth. 44. RU Eline and run E-line correlation log through tubing. 45. Position Saltel patch @ 4,615’ – 4,675’ and set per Schlumberger setting procedure. POOH and lay down setting tools. 46. RIH with Cleanout/VACS assembly on 2-7/8” tubing as outlined below: 47. 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. 48. 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. 49. PU and RIH with 5-1/2” liner cleanout assembly as outlined below: Well: SP-23 PTD: 211-127 API: 50-629-23456-00-00 50. RIH until BHA is approximately 30’ above liner top. Break circulation and record working parameters of VACS. 51. 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. 52. POOH with VACS cleanout BHA laying down 2-7/8” snorkel pipe. a. Break down BHA capturing sand in containment. Report amount of sand captured in daily report. Inspect and empty washpipe and VACS tool. 53. Call Operations Engineer after each cleanout run to discuss sand returns. 54. RIH with 2-7/8” 6.5# Hyd563 and ESP completion w/ motor shroud to +/- 5,978’ 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 55. Land tubing hanger. Use extra caution to not damage cable. 56. Lay down landing joint. 57. Set BPV. 58. ND BOPE and NU tree. 59. Test tubing hanger void to 500 psi low/5,000 psi high. Pull BPV. 60. RDMO Doyon 15. Well: SP-23 PTD: 211-127 API: 50-629-23456-00-00 Well: SP-23 PTD: 211-127 API: 50-629-23456-00-00 Attachments: 1. Current Wellbore Schematic 2. Proposed Wellbore Schematic 3.BOPE Schematic 2-7/8” 6.5 ppf Hyd563 ProductionTubingSP23-N03Dual Lateral Producerwith ESP LiftNikaitchuq Field –Spy IslandAs Completed07/12/2024L1 - Baker SLXP LinerHanger/Packer6,005' MD / 3,874' TVD~6,052' - 6,069' MD,Casing Exit Window2-7/8” cable clamps, for ESP PowerCable, (2) 3/8" Chem Inj Line5,978' MD, 3871' TVD, 86º Inc – Bottom of ShroudCentrilift, 250HP 562XP Motor 82stage Flex27sxd pump 20stage Ginpsh pump 538 GasSeparator Tandem 513 seal sections Conventional ESPTD 8 3/4”14,021' MD,3,806' TVD 91.5º Inc.Silver Bullet Ecc. NoseGuide Closed Shoe13,576/’ MD / 3,798' TVDTD 8 1/2”13592' MD3797' TVD92.52 Inc.5-½” 15.5/17 ppfL80 Slotted LinerSealbore Receptacle4.75" ID4-½” x 9-5/8" RAMSeal Bore Diverterw/ 3.68" Seal BoreDrift 3.65"Bottom of Seal Assembly4 ½” Lateral Entry Module (LEM) w/3.68 Seal Bore, drift 3.63"Baker MLXP LinerHanger/Packer5-½” Silver Bullet Ecc. Nose GuideShoe13,967' MD, 3807' TVD,91.5º Inc. Interm. Casing9-5/8", 40#6369' MD, 3895' TVD89º Inc.Zonal Isolation SwellPackersSwell Packer MD’s (ft):#1) 7,486#2 8,535#3) 9,417#4) 11,4266176' MD, 3,888TVD - Baker SLXPLiner Hanger/PackerSurf. Casing13-3/8", 68 # BTC2,748' MD, 2,481' TVD49º Inc.5,904' MD/ 3,867' DGU5,859' MD/ 3,862' TVD SLB XN Nipple 2.313" IDACSaltel Casing Patch Top: 4,615.3' and Bottom: 4,640.6' ID of the Patch : 8.079" installed 7/1/24 2-7/8” 6.5 ppf Hyd563 ProductionTubingSP23-N03Dual Lateral Producerwith ESP LiftNikaitchuq Field –Spy IslandProposedDec 2024L1 - Baker SLXP LinerHanger/Packer6,005' MD / 3,874' TVD~6,052' - 6,069' MD,Casing Exit Window2-7/8” cable clamps, for ESP PowerCable, (2) 3/8" Chem Inj Line~5,978' MD, ~3871' TVD, 86º Inc – Bottom of ShroudCentrilift, 250HP 562XP Motor ESPTD 8 3/4”14,021' MD,3,806' TVD 91.5º Inc.Silver Bullet Ecc. NoseGuide Closed Shoe13,576/’ MD / 3,798' TVDTD 8 1/2”13592' MD3797' TVD92.52 Inc.5-½” 15.5/17 ppfL80 Slotted LinerSealbore Receptacle4.75" ID4-½” x 9-5/8" RAMSeal Bore Diverterw/ 3.68" Seal BoreDrift 3.65"Bottom of Seal Assembly4 ½” Lateral Entry Module (LEM) w/3.68 Seal Bore, drift 3.63"Baker MLXP LinerHanger/Packer5-½” Silver Bullet Ecc. Nose GuideShoe13,967' MD, 3807' TVD,91.5º Inc. Interm. Casing9-5/8", 40#6369' MD, 3895' TVD89º Inc.Zonal Isolation SwellPackersSwell Packer MD’s (ft):#1) 7,486#2 8,535#3) 9,417#4) 11,4266176' MD, 3,888TVD - Baker SLXPLiner Hanger/PackerSurf. Casing13-3/8", 68 # BTC2,748' MD, 2,481' TVD49º Inc.~5,904' MD/ 3,867' DGU~5,859' MD/ ~3,862' TVD SLB XN Nipple 2.313" IDACSaltel Casing Patch Top: ~4,615' to ~ 4,675' 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): 14,021 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, ADL0388583, ADL0391283 211-127 C.O. 639 NIKAITCHUQ SP23-N03 3800 Centerpoint Dr, Suite 1400 Anchorage, AK 99503 50-629-23456-00-00 Hilcorp Alaska, LLC Length Size Proposed Pools: 3,806 13,967 3,807 1,326 SCHRADER BLUFF OIL SCHRADER BLUFF OIL 160' 160' 6.5# / L-80 TVD Burst 5,978' MD NA NA 6,369' 5,020psi 5,750psi 2,480' 3,895' 3,807' 2,748' 6,369' Slotted Liner 160' 20" 13-3/8" 9-5/8" 2,748' 5-1/2"7,598' Slotted Liner 907-777-8438 keith.lopez@hilcorp.com Operations Manager January 1, 2025 2-7/8" Perforation Depth MD (ft): NIKAITCHUQ SLXP Liner Hanger Packer, four oil swell packers, and NA 6,005' MD/ 3,874' TVD, see schematic for swell packers, and NA NA 13,967' 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 12:52 pm, Dec 12, 2024 Digitally signed by Sara Hannegan (2519) DN: cn=Sara Hannegan (2519) Date: 2024.12.12 10:38:08 - 09'00' Sara Hannegan (2519) 324-696 SFD 12/13/2024 DSR-12/16/24MGR23DEC2024 * BOPE test to 3500 psi. Annular to 2500 psi. * All workstring operations to be performed with 2-7/8" pipe body tubulars. * Pipe ram size of 2-7/8" X 5" approved for operations. 10-404 MEUIRUMOF Gregory C. Wilson Digitally signed by Gregory C. Wilson Date: 2024.12.27 14:27:58 -09'00'12/27/24 RBDMS JSB 123024 Well: SP-23 PTD: 211-127 API: 50-629-23456-00-00 Well Name:SP-23 API Number:50-629-23456-00-00 Current Status:Producer Rig:Doyon 15 Estimated Start Date:01/1/2025 Estimated Duration:15 days Regulatory Contact:Darci Horner Permit to Drill Number:211-127 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: 1,713 psi @ 3,871’ TVD |8.5 PPGE Max Potential Surface Pressure: 1,326 psi Gas Column Gradient (0.1 psi/ft) Max Angle: 86° Sail Angle from 5,235’ MD to ESP setting depth of 5,978’ MD Brief Well Summary: SP23 was drilled and completed in January 2013 as a Schrader Bluff OA producer with an ESP completion. A second lateral to the well was added in March 2021 and an ESP installed. A RWO was conducted in May 2024 to replace the ESP and the well came on at 100% WC. A second RWO in July 2024 found a casing leak @ 4,615 and gravel in the wellbore. An expandable casing patch was set and the well came back online for 10 days before the water returned. The zone at the casing leak depth is capable of flowing >4,000 bwpd. Objectives: Pull ESP completion, mill out patch, cement squeeze casing leak, set a new patch, run VAC tool to remove sand from ESP setting depth and 1,800’ into liner top, run new ESP completion. Notes Regarding Wellbore Condition: x Expandable casing patch installed @ 4,615’ in July 2024. x Casing test of patch and 9-5/8” passed to 1500 psi for 30 minutes on 07/01/24. x It is likely that the casing patch has failed. 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 (45 bbls) of injection water inhibited with biocide. b. Pump 130% annulus volume (520 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. Well: SP-23 PTD: 211-127 API: 50-629-23456-00-00 9. Run 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 2-7/8” test joint with blanking plug. 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 injection water inhibited with biocide down the annulus throughout the operations to maintain well kill. 15. POOH with 2-7/8” ESP completion laying down 1,800’ of tubing and standing back the rest. Lay down ESP. Record number of clamps recovered. 16. RU Slickline with PCE and lubricator. 17. RIH with eline 60 arm caliper to deviation to evaluate condition of expandable casing patch and casing. 18. RIH with 4,100’ of 2-7/8” tubing as kill string. 19. Land tubing hanger and lay down landing joint. 20. Set BPV. 21. ND BOPE and NU tree. 22. RDMO Doyon 15. Brief RWO Procedure – RU #2 23. MIRU Doyon 15 WO Rig, ancillary equipment, and lines. 24. Kill well by bullheading the tubing string and the IA while monitoring the OA. 25. Flow check for 30 min to ensure the well is killed. 26. Nipple down X-mas tree. 27. Make up blanking plug on top of tubing hanger as per Vault procedure. 28. Nipple up BOP. 29. Run 2-7/8” test joint and engage tubing hanger blanking plug. b. 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. 30. Pull 2-7/8” test joint with blanking plug. 31. Pull BPV from the tubing hanger per Vault procedure. 32. POOH w/ 2-7/8” kill string standing back. 33. RIH with perf guns and perforate expandable casing patch @ 4,630’ or mill out and retrieve casing patch. 34. RIH and 9-5/8” HEX on 2-7/8” tubing and set at 4,675’. Circulate sand on top of plug. 35. RIH with 9-5/8” packer on 2-7/8” tubing and set at 4,585’. Pressure test IA to 1,500 psi. Conduct injection test into damaged casing zone. 36. MIRU Halliburton cement pump and bulk unit. Mix up Class G cement with additives in bulk unit (volume TBD). Cement squeeze casing leak to 1,500 psi. If cement at the leak does not begin building pressure, conduct hesitation squeeze as necessary. 37. Release packer and reverse circulate clean. 38. RDMO Halliburton cement. 39. POOH with 9-5/8” packer on 2-7/8” tubing. Well: SP-23 PTD: 211-127 API: 50-629-23456-00-00 40. RIH with 8.625” rock bit and 9 x 5-1/2” drill collars and tag cement top after cure time. Drillout cement to top of sand on HEX plug. POOH and lay down bit and drill collars. 41. Pressure test casing to 1,500 psi for 30 minutes. 42. RIH with HEX plug retrieving tool. Circulate sand off HEX plug @ 4,675’. Latch, release, and POOH with HEX plug. 43. RIH with 9-5/8” Saltel casing patch on 2-7/8” tubing to 4,635’ (20’ below expected patch setting depth. 44. RU Eline and run E-line correlation log through tubing. 45. Position Saltel patch @ 4,615’ – 4,675’ and set per Schlumberger setting procedure. POOH and lay down setting tools. 46. RIH with Cleanout/VACS assembly on 2-7/8” tubing as outlined below: 47. 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. 48. 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. 49. PU and RIH with 5-1/2” liner cleanout assembly as outlined below: Well: SP-23 PTD: 211-127 API: 50-629-23456-00-00 50. RIH until BHA is approximately 30’ above liner top. Break circulation and record working parameters of VACS. 51. 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. 52. POOH with VACS cleanout BHA laying down 2-7/8” snorkel pipe. a. Break down BHA capturing sand in containment. Report amount of sand captured in daily report. Inspect and empty washpipe and VACS tool. 53. Call Operations Engineer after each cleanout run to discuss sand returns. 54. RIH with 2-7/8” 6.5# Hyd563 and ESP completion w/ motor shroud to +/- 5,978’ 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 55. Land tubing hanger. Use extra caution to not damage cable. 56. Lay down landing joint. 57. Set BPV. 58. ND BOPE and NU tree. 59. Test tubing hanger void to 500 psi low/5,000 psi high. Pull BPV. 60. RDMO Doyon 15. Well: SP-23 PTD: 211-127 API: 50-629-23456-00-00 Well: SP-23 PTD: 211-127 API: 50-629-23456-00-00 Attachments: 1. Current Wellbore Schematic 2. Proposed Wellbore Schematic 3.BOPE Schematic 2-7/8” 6.5 ppf Hyd563 ProductionTubingSP23-N03Dual Lateral Producerwith ESP LiftNikaitchuq Field –Spy IslandAs Completed07/12/2024L1 - Baker SLXP LinerHanger/Packer6,005' MD / 3,874' TVD~6,052' - 6,069' MD,Casing Exit Window2-7/8” cable clamps, for ESP PowerCable, (2) 3/8" Chem Inj Line5,978' MD, 3871' TVD, 86º Inc – Bottom of ShroudCentrilift, 250HP 562XP Motor 82stage Flex27sxd pump 20stage Ginpsh pump 538 GasSeparator Tandem 513 seal sections Conventional ESPTD 8 3/4”14,021' MD,3,806' TVD 91.5º Inc.Silver Bullet Ecc. NoseGuide Closed Shoe13,576/’ MD / 3,798' TVDTD 8 1/2”13592' MD3797' TVD92.52 Inc.5-½” 15.5/17 ppfL80 Slotted LinerSealbore Receptacle4.75" ID4-½” x 9-5/8" RAMSeal Bore Diverterw/ 3.68" Seal BoreDrift 3.65"Bottom of Seal Assembly4 ½” Lateral Entry Module (LEM) w/3.68 Seal Bore, drift 3.63"Baker MLXP LinerHanger/Packer5-½” Silver Bullet Ecc. Nose GuideShoe13,967' MD, 3807' TVD,91.5º Inc. Interm. Casing9-5/8", 40#6369' MD, 3895' TVD89º Inc.Zonal Isolation SwellPackersSwell Packer MD’s (ft):#1) 7,486#2 8,535#3) 9,417#4) 11,4266176' MD, 3,888TVD - Baker SLXPLiner Hanger/PackerSurf. Casing13-3/8", 68 # BTC2,748' MD, 2,481' TVD49º Inc.5,904' MD/ 3,867' DGU5,859' MD/ 3,862' TVD SLB XN Nipple 2.313" IDACSaltel Casing Patch Top: 4,615.3' and Bottom: 4,640.6' ID of the Patch : 8.079" installed 7/1/24 2-7/8” 6.5 ppf Hyd563 ProductionTubingSP23-N03Dual Lateral Producerwith ESP LiftNikaitchuq Field –Spy IslandProposedDec 2024L1 - Baker SLXP LinerHanger/Packer6,005' MD / 3,874' TVD~6,052' - 6,069' MD,Casing Exit Window2-7/8” cable clamps, for ESP PowerCable, (2) 3/8" Chem Inj Line~5,978' MD, ~3871' TVD, 86º Inc – Bottom of ShroudCentrilift, 250HP 562XP Motor ESPTD 8 3/4”14,021' MD,3,806' TVD 91.5º Inc.Silver Bullet Ecc. NoseGuide Closed Shoe13,576/’ MD / 3,798' TVDTD 8 1/2”13592' MD3797' TVD92.52 Inc.5-½” 15.5/17 ppfL80 Slotted LinerSealbore Receptacle4.75" ID4-½” x 9-5/8" RAMSeal Bore Diverterw/ 3.68" Seal BoreDrift 3.65"Bottom of Seal Assembly4 ½” Lateral Entry Module (LEM) w/3.68 Seal Bore, drift 3.63"Baker MLXP LinerHanger/Packer5-½” Silver Bullet Ecc. Nose GuideShoe13,967' MD, 3807' TVD,91.5º Inc. Interm. Casing9-5/8", 40#6369' MD, 3895' TVD89º Inc.Zonal Isolation SwellPackersSwell Packer MD’s (ft):#1) 7,486#2 8,535#3) 9,417#4) 11,4266176' MD, 3,888TVD - Baker SLXPLiner Hanger/PackerSurf. Casing13-3/8", 68 # BTC2,748' MD, 2,481' TVD49º Inc.~5,904' MD/ 3,867' DGU~5,859' MD/ ~3,862' TVD SLB XN Nipple 2.313" IDACSaltel Casing Patch Top: ~4,615' to ~ 4,675' CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:Brooks, Phoebe L (OGC) To:Rig 15 Cc:Regg, James B (OGC) Subject:RE: Rig 15 BOP test SP23-N3 7-6-24 Date:Friday, August 9, 2024 3:06:45 PM Attachments:Doyon 15 07-06-24 Revised.xlsx Tom, Attached is a revised report adding the # of Nitgn. Bottles (10). Please update your copy. Thank you, Phoebe Phoebe Brooks Research Analyst Alaska Oil and Gas Conservation Commission Phone: 907-793-1242 CONFIDENTIALITY NOTICE:This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Phoebe Brooks at 907-793-1242 or phoebe.brooks@alaska.gov. From: Rig 15 <rig15@doyondrilling.com> Sent: Monday, July 8, 2024 8:27 AM To: Regg, James B (OGC) <jim.regg@alaska.gov>; Brooks, Phoebe L (OGC) <phoebe.brooks@alaska.gov>; DOA AOGCC Prudhoe Bay <doa.aogcc.prudhoe.bay@alaska.gov>; DOA AOGCC Prudhoe Bay <doa.aogcc.prudhoe.bay@alaska.gov> Subject: Rig 15 BOP test SP23-N3 7-6-24 Tom Shones Rig 15 Toolpusher 907-685-0716 Attached is a revised report adding the # of Nitgn. Bottles (10). Please update your copy. STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION *All BOPE reports are due to the agency within 5 days of testing* Su bm it to :jim.regg@alaska.gov; AOGCC.Inspectors@alaska.gov; phoebe.brooks@alaska.gov Rig Owner: Rig No.:15 DATE: 7/6/24 Rig Rep.: Rig Email: Operator: Operator Rep.: Op. Rep Email: Well Name: PTD #2111270 Sundry #324-336 Operation: Drilling: Workover: X Explor.: Test: Initial: Weekly: X Bi-Weekly: Other: Rams:250-3000 Annular:250-3000 Valves:250-3000 MASP:712 MISC. INSPECTIONS: TEST DATA FLOOR SAFETY VALVES: Test Result/Type Test Result Quantity Test Result Housekeeping P Well Sign P Upper Kelly 1 P Permit On Location P Hazard Sec.P Lower Kelly 1 P Standing Order Posted P Misc.P Ball Type 1 P Test Fluid Water Inside BOP 1 P FSV Misc 0 NA BOP STACK:Quantity Size/Type Test Result MUD SYSTEM:Visual Alarm Stripper 0 NA Trip Tank P P Annular Preventer 1 13-5/8"P Pit Level Indicators P P #1 Rams 1 2-7/8 x 5"P Flow Indicator P P #2 Rams 1 Blind/Shear P Meth Gas Detector P P #3 Rams 1 2-7/8 x 5"P H2S Gas Detector P P #4 Rams 0 NA MS Misc 0 NA #5 Rams 0 NA #6 Rams 0 NA ACCUMULATOR SYSTEM: Choke Ln. Valves 2 3-1/8"5k P Time/Pressure Test Result HCR Valves 4 3-1/8"5k P System Pressure (psi)3000 P Kill Line Valves 4 3-1/8"5k P Pressure After Closure (psi)2150 P Check Valve 0 NA 200 psi Attained (sec)9 P BOP Misc 0 NA Full Pressure Attained (sec)38 P Blind Switch Covers: All stations Yes CHOKE MANIFOLD:Bottle Precharge:P Quantity Test Result Nitgn. Bottles # & psi (Avg.): 10@4000 P No. Valves 15 P ACC Misc 0 NA Manual Chokes 1 P Hydraulic Chokes 1 P Control System Response Time:Time (sec) Test Result CH Misc 0 NA Annular Preventer 9 P #1 Rams 7 P Coiled Tubing Only:#2 Rams 7 P Inside Reel valves 0 NA #3 Rams 7 P #4 Rams 0 NA Test Results #5 Rams 0 NA #6 Rams 0 NA Number of Failures:0 Test Time:5.5 HCR Choke 2 P Repair or replacement of equipment will be made within days. HCR Kill 2 P Remarks: AOGCC Inspection 24 hr Notice Yes Date/Time 7-03-24@07:12 Waived By Test Start Date/Time:7/5/2024 21:30 (date) (time)Witness Test Finish Date/Time:7/6/2024 3:00 BOPE Test Report Notify the AOGCC of repairs with written confirmation to: AOGCC.Inspectors@alaska.gov Kam StJohn Doyon All test performed with test plug, Test Annular with 2-7/8 and 5" test jt.250-3000/5min., Blind/Shear 250-3000/5min., Upper & Lower Preventors 250-3000/5min.ea., Valves 250-3000/5min. T.Shones / J.Vanderpool E.N.I. S.Lawerence / D. Smith NIK SP23-N3 Test Pressure (psi): rig15@doyondrilling.com Form 10-424 (Revised 08/2022) 2024-0706_BOP_Doyon15_Nikaitchuq_SP23-N3 Eni US Operating Co, Inc WELL LOG/DATA TRANSMITTAL To: ůĂƐŬĂKŝůĂŶĚ'ĂƐŽŶƐĞƌǀĂƚŝŽŶŽŵŵŝƐƐŝŽ 333 W. 7th Ave, Anchorage, AK 99501 July 26, 2024 Well:SP23-N3 LWD/MWD Logs PDF LAS DLIS Excel Mudlogs E-line logs 9-5/8" CAST x x PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Amjad Chaudhry Mail: amjad.chaudhry@eni.com Received By: ___________________________________Date:____________ Eni US Operating Co, Inc. 211-127 T39304 Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2024.07.26 11:09:22 -08'00' New Plugback Esets 7/15/2024 Well Name API Number PTD Number ESet Number Date CRU C1-07 PB2 50-103-20478-71-00 203-225 T39188 1-29-2007 CRU CD2-467 PB1 50-103-20579-70-00 208-114 T39189 10-31-2008 CRU CD4-12 PB1 50-103-20414-70-00 210-091 T39190 9-20-2010 CRU CD4-210A PB1 50-103-20533-70-00 211-072 T39191 9-9-2011 KRU 1B-15AL3 PB1 50-029-22465-72-00 207-067 T39192 11-23-2009 KRU 1E-12L1 PB1 50-029-20736-70-00 210-004 T39193 5-24-2010 KRU 1E-12L2-01 PB1 50-029-20736-72-00 210-007 T39194 5-24-2010 KRU 3H-12A PB1 50-103-20088-70-00 211-081 T39195 9-9-2012 KRU 3I-11AL2 PB1 50-029-21932-70-00 210-076 T39196 11-1-2010 ODSK-33 PB1 50-703-20562-70-00 207-183 T39197 6-20-2008 OI11-01 50-029-23430-70-00 210-106 T39198 11-2-2010 OP04-07 PB1 50-029-23409-70-00 208-199 T39200 7-6-2010 OP08-04 PB1 50-029-23424-70-00 210-041 T39201 7-28-2010 PBU 06-02A PB1 50-029-20282-70-00 211-026 T39202 7-25-2011 PBU 15-05B PB1 50-029-20731-71-00 211-057 T39203 8-20-2011 PBU 15-16B PB1 50-029-21115-70-00 210-020 T39204 7-8-2010 PBU 18-04B PB1 50-029-20875-70-00 201-090 T39205 12-6-2002 PBU J-16B PB1 50-029-20967-70-00 212-014 T39206 9-28-2012 PBU K-05D PB1 50-029-21418-71-00 211-077 T39207 1-20-2012 PBU V-204L1 50-029-23217-60-00 204-132 T39208 11-13-2006 PBU W-19B PB1 50-029-22006-72-00 210-065 T39209 1-13-2011 PBU W-19BL1 PB1 50-029-22006-73-00 210-066 T39210 1-18-1011 SP23-N03 PB1 50-629-23456-70-00 211-127 T39211 3-5-2012 TBU M-10 PB1 50-733-20588-70-00 209-154 T39212 4-23-2010 SP23-N03 PB1 50-629-23456-70-00 211-127 T39211 3-5-2012 1. Operations Susp Well Insp Plug Perforations Fracture Stimulate Pull Tubing Operations shutdown Performed: Install Whipstock Perforate Other Stimulate Alter Casing Change Approved Program Mod Artificial Lift Perforate New Pool Repair Well Coiled Tubing Ops Other: _ESP Changeout Development Exploratory Stratigraphic Service 6. API Number: 7. Property Designation (Lease Number):8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071):10. Field/Pool(s): 11. Present Well Condition Summary: Total Depth measured 14,021 feet N/A feet true vertical 3,806 feet N/A feet Effective Depth measured 13,967 feet N/A feet true vertical 3,807 feet N/A feet Perforation depth Measured depth 6369-13967 feet True Vertical depth 3895-3807 feet Tubing (size, grade, measured and true vertical depth)2-7/8"L-80 5,852' 3,860' Packers and SSSV (type, measured and true vertical depth)N/A N/A N/A N/A 12. Stimulation or cement squeeze summary:N/A Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13a. Prior to well operation: Subsequent to operation: 13b. Pools active after work:Schrader Bluff 15. Well Class after work: Daily Report of Well Operations Exploratory Development Service Stratigraphic Copies of Logs and Surveys Run 16. Well Status after work: Oil Gas WDSPL Electronic Fracture Stimulation Data GSTOR GINJ SUSP SPLUG Sundry Number or N/A if C.O. Exempt: Authorized Name and Giorgio Iannucci 7/24/2024 Digital Signature with Date:Contact Name: Contact Email: Authorized Title:Well Operations Project Manager Contact Phone: 20" 2270 4,760 5,020 6,870 Production Liner 6,369' 7,598' Casing Structural 3,895' 5.5" 6,369' 13,967'3,807' Length 160' 2,748' 160' 2,748'2,480' Conductor Surface Intermediate 13.375" logs data will be uploaded on FTP site 5. Permit to Drill Number:2. Operator Name 4. Well Class Before Work: ADL 391283, 3885833, 388574 Nikaitchuq/ Schrader Bluff Eni US Operating CO. Inc. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 211-127 50-629-23456-00-00 Size 160' measured TVD Plugs Junk measured Burst Collapse 9.625" Slotted 3700 Centerpoint Dr, Ste, 500, Anchorage, AK, 99503 3. Address: SP23-N3 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 337 Gas-Mcf MD 9 measured true vertical Packer Representative Daily Average Production or Injection Data Casing Pressure Tubing Pressure 989 6818 0 324-336 Sr Pet Eng: Slotted Sr Pet Geo:Sr Res Eng: WINJ WAG 3.3 Water-BblOil-Bbl 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. 1663958 188 Amjad Chaudhry amjad.chaudhry@eni.com 907-865-3379 p k ft t Fra O s 211 6. A G L PG , Form 10-404 Revised 10/2022 Due Within 30 days of Operations Submit in PDF format to aogcc.permitting@alaska.gov io Iannucci 7/ By Grace Christianson at 8:11 am, Jul 29, 2024 DSR-7/31/24 RBDMS JSB 073124 2-7/8” 6.5 ppf Hyd563 Production TubingSP23-N3Dual Lateral Producer with ESP LiftNikaitchuq Field –Spy IslandAs Completed07/12/2024L1 - Baker SLXP Liner Hanger/Packer6,005' MD / 3,874' TVD~6,052' - 6,069' MD, Casing Exit Window2-7/8” cable clamps, for ESP Power Cable, (2) 3/8" Chem Inj Line 5,978' MD, 3871' TVD, 86º Inc – Bottom of Shroud Centrilift, 250HP 562XP Motor 82stage Flex27sxd pump 20stage Ginpsh pump 538 Gas Separator Tandem 513 seal sections Conventional ESPTD 8 3/4” 14,021' MD,3,806' TVD 91.5º Inc.Silver Bullet Ecc. Nose Guide Closed Shoe13,576/’ MD / 3,798' TVD TD 8 1/2” 13592' MD 3797' TVD92.52 Inc.5-½” 15.5/17 ppf L80 Slotted Liner Sealbore Receptacle4.75" ID4-½” x 9-5/8" RAMSeal Bore Diverterw/ 3.68" Seal BoreDrift 3.65"Bottom of Seal Assembly4 ½” Lateral Entry Module (LEM) w/ 3.68 Seal Bore, drift 3.63"Baker MLXP LinerHanger/Packer5-½” Silver Bullet Ecc. Nose Guide Shoe13,967' MD, 3807' TVD,91 5ºInc Interm. Casing 9-5/8", 40#6369' MD, 3895' TVD89ºIncZonal Isolation Swell PackersSwell Packer MD’s (ft):#1) 7,486#2 8,535#3) 9,417#4) 11,4266176' MD, 3,888 TVD - Baker SLXP Liner Hanger/PackerSurf. Casing13-3/8", 68 # BTC2,748' MD, 2,481' TVD49º Inc.5,904' MD/ 3,867' DGU 5,859' MD/ 3,862' TVD SLB XN Nipple 2.313" IDACSaltel Casing Patch Top: 4,614.6' and Bottom: 4,640.6' ID of the Patch : 8.079" Well Name: SP23-N3 OR Wellbore Name: SP23-N3 Well Code: 26152 Job: WORKOVER WCEI Level: LEVEL 3 Daily Report Date: 6/11/2024 Report #: 1 Page: 1 of 1 Well Header Permit/Concession N° ADL-388583 Operator ENI PETROLEUM Subsidiary ENI Petroleum Co. Inc. Initial Lahee Code DEVELOPMENT WELL Rotary Table Elevation (ft) 40.89 Ground Level (ft) First Flange (ft) 4.09 RKB - Base Flange (ft) 36.80 RKB - Tubing Spool (ft) 31.91 Rig Information Rig Name RIG 15 Contractor DOYON Rig Type LAND RIG Rig Num 0723 Daily Information Weather Overcast Temperature (°F) 30.9 Wind NE @ 18 MPH Days LTI (days) 1,620.00 Days RI (days) POB 42.0 Daily Summary Operations 24h Forecast Complete berming around and prep rig to bring on 8.6 ppg KCL/NaCl, test lines and perform well kill as per program. Monitor well and nipple down tree. 24h Summary Prep and move rig from SP42 to SP23. Operation at 07.00 Setting accumulator hoses, suitcase, and bringing on 8.6 ppg KCL/NaCl. Time Log Start Time End Time Dur (hr) Cum Dur (hr)Phase Opr. Act. Plan Oper. Descr. 00:00 03:00 3.00 3.00 MOB A 2 P PJSM – Disconnect choke interconnects on roof and under rig floor, complete floor skidding checklist. 03:00 04:00 1.00 4.00 MOB A 2 P PJSM - Skid rig floor/cantilever into travelling position. 04:00 04:30 0.50 4.50 MOB A 2 P PJSM - Raise stompers off base beam and prep to move pits away from sub. 04:30 07:00 2.50 7.00 MOB A 2 P PJSM - Move pits away from sub, turn tires on pits and hook up remote on back of sub. 07:00 10:30 3.50 10.50 MOB A 2 P PJSM –Back sub off of well bay, set down, and turn tires. Crab sub over and position sub on dance floor in front of SP23, set down, turn tires and pull up to well bay and spot over SP23. 10:30 12:00 1.50 12.00 MOB A 2 P PJSM - Crab pits and position on dance floor next to sub. 12:00 16:00 4.00 16.00 MOB A 2 P PJSM - Shim up pits and set down on mats, set stompers on base beam, and skid rig floor back to drilling position. 16:00 21:00 5.00 21.00 MOB A 2 P PJSM - Lock rig floor in place, reinstall handrails, begin connecting interconnects, and assist electrician plug top drive cables up, and continue to rig up of service lines. Raise and secure support braces in pipe shed. Unsecured top drive and break off pup joint. Note: Notified AOGC for BOP test on 06-13-2024 at 14:00 hrs. at 18:03 hours. AOGC reply at 1807 hrs. and waived witness. 21:00 00:00 3.00 24.00 MOB A 2 P Continue making up interconnects between modules and rig floor. Make-up services line from suit case lines to rig module and choke line on roof of pit module. Remove scaffolding. Berm and spot accumulator unit. Set loader ramp on long side of pipe shed. Test suitcase with air (good test). Start install berming around rig. Daily Contacts Position Contact Name Company Title Email Office Mobile Company Representative Steve Lawrence ASRC Energy Services Drilling Supv. siddrilling@eni.com 907-685-0715 Company Representative David Smith ASRC Energy Services Drilling Supv. siddrilling@eni.com 907-685-0715 Company Representative Adam Groendyke ASRC Energy Services Rig Clerk AKRigClerksDoyon15@eni.com 907-685-0722 Safety Representative Levi Karns ASRC Energy Services HSE Levi.Karns@external.eni.com 907-685-0721 Safety Representative Derek Ambrose Doyon Drilling HSE rig15@doyondrilling.com 907-685-0796 Tool Push Jerad Vanderpool Doyon Drilling Tool Pusher rig15@doyondrilling.com 907-685-0727 Tool Push Tom Shones Doyon Drilling Tool Pusher rig15@doyondrilling.com 907-685-0727 Last Casing Seat Cas. Type OD (in) ID (in) Grade Top (ftKB) Bottom (ftKB) TVD Bot. (ftKB) Landing Date LINER 5 1/2 4.95 L80 -13,937.1 13,996.9 3,786.6 1/31/2012 Well Name: SP23-N3 OR Wellbore Name: SP23-N3 Well Code: 26152 Job: WORKOVER WCEI Level: LEVEL 3 Daily Report Date: 6/12/2024 Report #: 2 Page: 1 of 1 Well Header Permit/Concession N° ADL-388583 Operator ENI PETROLEUM Subsidiary ENI Petroleum Co. Inc. Initial Lahee Code DEVELOPMENT WELL Rotary Table Elevation (ft) 40.89 Ground Level (ft) First Flange (ft) 4.09 RKB - Base Flange (ft) 36.80 RKB - Tubing Spool (ft) 31.91 Rig Information Rig Name RIG 15 Contractor DOYON Rig Type LAND RIG Rig Num 0723 Daily Information Weather Clear Temperature (°F) 33.3 Wind NE @ 17 MPH Days LTI (days) 1,621.00 Days RI (days) POB 44.0 Daily Summary Operations 24h Forecast Perform well kill as per program. Monitor well. Nipple down tree. Nipple up BOPE. Test BOPE as per AOGCC. 24h Summary Prep and move rig from SP42-NE4 to SP23-N3. Finish rig up. Bring on 800 BBLS of 8.6 PPG brine. Rig up well kill hoses and test lines. Perform derrick inspection. Service rig. Troubleshoot PVT system with Totco technician. Operation at 07.00 Nippling up BOPE. Time Log Start Time End Time Dur (hr) Cum Dur (hr)Phase Opr. Act. Plan Oper. Descr. 00:00 03:30 3.50 3.50 MOB A 2 P PJSM. Continue making-up interconnection between modules. Hook-up choke line, flow line, flange-up poor boy vent, install degasser vent line. Raise top of beaver slide. Berm around rig and install steps for entry and egress points. Start running accumulator hoses from accumulator to rig. 03:30 07:30 4.00 7.50 MOB A 2 P PJSM. Bring on 800 BBL of 8.6 PPG NaCl/ 3%KCL brine inhibited with biocide. Continue to make up interconnects, continue to run accumulator hose from accumulator to rig. Straighten and adjust berm around rig. 07:30 15:00 7.50 15.00 MOB A 2 P PJSM. Continue to run accumulator hoses. Rig up high pressure hoses on tubing and A annulus to perform well kill. Install lids on top suitcases, ensure that all entrances and exits had adequate landings coming out of doors. 15:00 16:00 1.00 16.00 MOB A 1 P Perform derrick inspection. 16:00 17:00 1.00 17.00 MOB A 1 P Rig service: grease blocks, wash pipe, crown, top drive, torque wrench and check hydraulic oil. 17:00 00:00 7.00 24.00 MOB A 25 TR99 Troubleshoot PVT system with Totco technician. Clean and organize rig floor. Organize pipe shed. Daily Contacts Position Contact Name Company Title Email Office Mobile Company Representative Steve Lawrence ASRC Energy Services Drilling Supv. siddrilling@eni.com 907-685-0715 Company Representative Mike Grubb ASRC Energy Services Drilling Supv. siddrilling@eni.com 907-685-0715 Company Representative Adam Groendyke ASRC Energy Services Rig Clerk AKRigClerksDoyon15@eni.com 907-685-0722 Company Representative Yelyzaveta Saprykina ASRC Energy Services Rig Clerk AKRigClerksDoyon15@eni.com 907-685-0722 Safety Representative Levi Karns ASRC Energy Services HSE Levi.Karns@external.eni.com 907-685-0721 Safety Representative Derek Ambrose Doyon Drilling HSE rig15@doyondrilling.com 907-685-0796 Tool Push Jerad Vanderpool Doyon Drilling Tool Pusher rig15@doyondrilling.com 907-685-0727 Tool Push Tom Shones Doyon Drilling Tool Pusher rig15@doyondrilling.com 907-685-0727 Last Casing Seat Cas. Type OD (in) ID (in) Grade Top (ftKB) Bottom (ftKB) TVD Bot. (ftKB) Landing Date LINER 5 1/2 4.95 L80 -13,937.1 13,996.9 3,786.6 1/31/2012 Well Name: SP23-N3 OR Wellbore Name: SP23-N3 Well Code: 26152 Job: WORKOVER WCEI Level: LEVEL 3 Daily Report Date: 6/13/2024 Report #: 3 Page: 1 of 1 Well Header Permit/Concession N° ADL-388583 Operator ENI PETROLEUM Subsidiary ENI Petroleum Co. Inc. Initial Lahee Code DEVELOPMENT WELL Rotary Table Elevation (ft) 40.89 Ground Level (ft) First Flange (ft) 4.09 RKB - Base Flange (ft) 36.80 RKB - Tubing Spool (ft) 31.91 Rig Information Rig Name RIG 15 Contractor DOYON Rig Type LAND RIG Rig Num 0723 Daily Information Weather Clear Temperature (°F) 34.7 Wind NE @ 22 MPH Days LTI (days) 1,622.00 Days RI (days) POB 45.0 Daily Summary Operations 24h Forecast Nipple up BOPE. Perform BOPE test with 2-7/8” and 5” test joints. Pull test joint with blanking plug. Pull back pressure valve. Rig up for de-completion. Make up landing joint to tubing hanger. Retract lockdown screws. Pull hanger free and to rotary table. Disconnect cable penetrator and control lines. Lay down tubing hanger. Pull out of hole with 2-7/8” tubing. 24h Summary Perform well kill operation, bull heading 8.6 ppg brine down tubing and annulus A. Nipple down tree. Nipple up riser and set BOP stack. Complete repairs and change out piston seals in the annular. Continue nippling up BOPE. Operation at 07.00 Rig up to test BOPE. Time Log Start Time End Time Dur (hr) Cum Dur (hr)Phase Opr. Act. Plan Oper. Descr. 00:00 05:30 5.50 5.50 W.O. L 9 P PJSM. Test well kill lines to 1500 psi, good test. Bull head 50 BBLS of 8.6 PPG NaCl/ 3%KCL brine inhibited with biocide down tubing at 1.13 BPM at 410 psi (tubing pressure at wellhead). Pressure dropped to -13 after 20 minutes. Bullhead 550 BBLS down A annulus at 3 BPM at 20 psi dropping to vacuum after pumping 70 BBLS. Shut down with both tubing and A annulus going on a vacuum. 05:30 07:00 1.50 7.00 W.O. L 1 P Monitor pressure for 1 hour with both tubing and A annulus on vacuum. 07:00 09:30 2.50 9.50 W.O. C 5 P PJSM. Blow down lines and rig down high pressure hose from tubing. Install BPV, nipple down tree, install test dart in top of tubing hanger and prep capillary lines for decompletion. Pump 10 BPH of 8.6 PPG NaCl/3%KCL brine inhibited with biocide down A annulus. 09:30 12:00 2.50 12.00 W.O. C 5 P Install high pressure riser on top of wellhead and make up Gray-Lock clamp. Nipple up BOP stack onto high pressure riser. Pump 10 BPH of 8.6 PPG NaCl/3%KCL brine inhibited with biocide down A annulus. 12:00 21:00 9.00 21.00 W.O. C 20 P PJSM. Install potato masher and remove top of annular preventer. Rig up and set annular top on floor of BOP deck, remove and replace seals. Some scoring on piston that required some buffing to remove. Install piston and element. Make up annular top. Rig down potato masher. Make up annular hoses and function test, bleed air and check for leak. Pump 10 BPH of 8.6 PPG NaCl/3%KCL brine inhibited with biocide down A annulus. 21:00 00:00 3.00 24.00 W.O. C 5 P Continue nipple up BOPE. Rig up choke 1 and 2 HCR and manual block. Nipple up primary kill HCR and manual block. Pump 10 BPH of 8.6 PPG NaCl/3%KCL brine inhibited with biocide down A annulus. Note: 24 Hour Loss of 8.6 ppg Brine = 262 BBLs Total Loss of 8.6 ppg Brine = 262 BBLs Daily Contacts Position Contact Name Company Title Email Office Mobile Company Representative Steve Lawrence ASRC Energy Services Drilling Supv. siddrilling@eni.com 907-685-0715 Company Representative Mike Grubb ASRC Energy Services Drilling Supv. siddrilling@eni.com 907-685-0715 Company Representative Yelyzaveta Saprykina ASRC Energy Services Rig Clerk AKRigClerksDoyon15@eni.com 907-685-0722 Safety Representative Levi Karns ASRC Energy Services HSE Levi.Karns@external.eni.com 907-685-0721 Safety Representative John Lettow Doyon Drilling HSE rig15@doyondrilling.com 907-685-0796 Tool Push Jerad Vanderpool Doyon Drilling Tool Pusher rig15@doyondrilling.com 907-685-0727 Tool Push Tom Shones Doyon Drilling Tool Pusher rig15@doyondrilling.com 907-685-0727 Last Casing Seat Cas. Type OD (in) ID (in) Grade Top (ftKB) Bottom (ftKB) TVD Bot. (ftKB) Landing Date LINER 5 1/2 4.95 L80 -13,937.1 13,996.9 3,786.6 1/31/2012 Well Name: SP23-N3 OR Wellbore Name: SP23-N3 Well Code: 26152 Job: WORKOVER WCEI Level: LEVEL 3 Daily Report Date: 6/14/2024 Report #: 4 Page: 1 of 1 Well Header Permit/Concession N° ADL-388583 Operator ENI PETROLEUM Subsidiary ENI Petroleum Co. Inc. Initial Lahee Code DEVELOPMENT WELL Rotary Table Elevation (ft) 40.89 Ground Level (ft) First Flange (ft) 4.09 RKB - Base Flange (ft) 36.80 RKB - Tubing Spool (ft) 31.91 Rig Information Rig Name RIG 15 Contractor DOYON Rig Type LAND RIG Rig Num 0723 Daily Information Weather Overcast Temperature (°F) 32.7 Wind NE @ 12 MPH Days LTI (days) 1,623.00 Days RI (days) POB 48.0 Daily Summary Operations 24h Forecast Finish rigging up for de-completion. Pull back pressure valve. Make up landing joint to tubing hanger. Retract lockdown screws. Pull hanger free and to rotary table. Disconnect cable penetrator and control lines. Lay down tubing hanger. Pull out of hole with 2-7/8” tubing. 24h Summary Finish nippling up BOPE. Perform BOPE test wit 2-7/8” and 5” test joints. Rig down test equipment. Start rig up for de-completion. Operation at 07.00 Pulling out of hole with 2-7/8" tubing at 5685'. Time Log Start Time End Time Dur (hr) Cum Dur (hr)Phase Opr. Act. Plan Oper. Descr. 00:00 06:00 6.00 6.00 W.O. C 1 P Continue nippling up BOPE. Rig up Kill HCR and Manual, choke and kill line, Bell nipple, flow line Clams shells in drip pan, splash guard on bell nipple. Rig up accumulator hoses to BOP stack. Install chain falls on stack and center. Pump 10 BPH of 8.6 PPG NaCl/3%KCL brine inhibited with biocide. 06:00 09:00 3.00 9.00 W.O. C 20 P Rig up to test BOPE. Make up test joint to blanking plug. Make up TIW and dart valve. Install test cap on top drive and rig up test hoses. Flood stack and fill choke with water, circulate out air and bleed off. Attempt to perform preform shell test, blanking plug leaking. Pump 10 BPH of 8.6 PPG NaCl/3%KCL brine inhibited with biocide. 09:00 11:00 2.00 11.00 W.O. C 5 P Pulled planking plug and BPV, install TWC, and torqued upper and lower blanking plug to 12K. Install 5” test joint with blanking plug. Flood stack and perform shell test to 250 PSI low and 3000 PSI high for 5 minute each. Pump 10 BPH of 8.6 PPG NaCl/3%KCL brine inhibited with biocide. 11:00 19:00 8.00 19.00 W.O. C 12 P Test BOPE 250/3000 psi for 5 minutes with 2-7/8” and 5” test joints. Test gas alarms. Test PVT and flow alarms. Perform accumulator draw down test. Starting pressure=2950 psi, after function=2200 psi, 200 psi increase=9 seconds, full pressure recovery=39 seconds. Nitrogen back up 10 bottles 4150 psi average. No failures. Witness waived by AOGCC rep Kam StJohn. Pump 10 BPH of 8.6 PPG NaCl/3%KCL brine inhibited with biocide. 19:00 20:00 1.00 20.00 W.O. C 1 P Rig down test equipment. Lay down test joint, break down subs. Blow down choke manifold, surface lines and top drive. 20:00 00:00 4.00 24.00 W.O. L 1 P Rig up for de-completion. Stage Baker equipment to pick up. Stage GBR equipment. Install cap tube and ESP cable sheaves in derrick. Install pollution hose to ESP sheave. Run rope through cap tube sheave. Pump 10 BPH of 8.6 PPG NaCl/3%KCL brine inhibited with biocide. Note: 24 Hour Loss of 8.6 ppg Brine = 127 BBLs Total Loss of 8.6 ppg Brine = 389 BBLs Daily Contacts Position Contact Name Company Title Email Office Mobile Company Representative Steve Lawrence ASRC Energy Services Drilling Supv. siddrilling@eni.com 907-685-0715 Company Representative Mike Grubb ASRC Energy Services Drilling Supv. siddrilling@eni.com 907-685-0715 Company Representative Yelyzaveta Saprykina ASRC Energy Services Rig Clerk AKRigClerksDoyon15@eni.com 907-685-0722 Safety Representative Levi Karns ASRC Energy Services HSE Levi.Karns@external.eni.com 907-685-0721 Safety Representative John Lettow Doyon Drilling HSE rig15@doyondrilling.com 907-685-0796 Tool Push Jerad Vanderpool Doyon Drilling Tool Pusher rig15@doyondrilling.com 907-685-0727 Tool Push Tom Shones Doyon Drilling Tool Pusher rig15@doyondrilling.com 907-685-0727 Last Casing Seat Cas. Type OD (in) ID (in) Grade Top (ftKB) Bottom (ftKB) TVD Bot. (ftKB) Landing Date LINER 5 1/2 4.95 L80 -13,937.1 13,996.9 3,786.6 1/31/2012 Well Name: SP23-N3 OR Wellbore Name: SP23-N3 Well Code: 26152 Job: WORKOVER WCEI Level: LEVEL 3 Daily Report Date: 6/15/2024 Report #: 5 Page: 1 of 1 Well Header Permit/Concession N° ADL-388583 Operator ENI PETROLEUM Subsidiary ENI Petroleum Co. Inc. Initial Lahee Code DEVELOPMENT WELL Rotary Table Elevation (ft) 40.89 Ground Level (ft) First Flange (ft) 4.09 RKB - Base Flange (ft) 36.80 RKB - Tubing Spool (ft) 31.91 Rig Information Rig Name RIG 15 Contractor DOYON Rig Type LAND RIG Rig Num 0723 Daily Information Weather Clear Temperature (°F) 34.7 Wind N @ 3 MPH Days LTI (days) 1,624.00 Days RI (days) POB 48.0 Daily Summary Operations 24h Forecast Finish loading 193 joints of 5” drill pipe in pipe shed. Strap drill pipe in pipe shed. Pick up and make up cleanout BHA #1. Single in hole with cleanout BHA #1 on 5” drill pipe and complete cleanout run as per wellplan. Pull out of hole standing drill pipe back in derrick. 24h Summary Finish rigging up for de-completion. Vault pull back pressure valve. Make up landing joint to tubing hanger. Retract lockdown screws. Pull hanger free and to rotary table. Disconnect cable penetrator and control lines. Lay down tubing hanger. Pull out of hole with 2-7/8” tubing. Cleaning and clearing the rig floor. Continue loading 5” drill pipe in pipe shed. Operation at 07.00 Pick up and make up cleanout BHA #1. Time Log Start Time End Time Dur (hr) Cum Dur (hr)Phase Opr. Act. Plan Oper. Descr. 00:00 01:30 1.50 1.50 W.O. L 1 P Rig up GBR and Baker for de-completion. Spot GBR power pack. Mobilize GBR power tongs to rig floor and rig up tongs. Pick up thread protectors. Pump 10 BPH of 8.6 PPG NaCl/3%KCL brine inhibited with biocide. 01:30 02:30 1.00 2.50 W.O. L 20 P Pick up T-bar and pull two way check valve. Observed fluid level dropping slowly. Make up landing joint. Back out lock down screws. Stage up weight from 90 k to 120 k in 10 k increments and pull tubing hanger off seat, up weight at 103 k. Pull tubing hanger to rig floor. Pump 10 BPH of 8.6 PPG NaCl/3%KCL brine inhibited with biocide. 02:30 04:00 1.50 4.00 W.O. L 20 P Lay down hanger. Lay down landing joint, pup and upper swivel joint. Cut ESP cable below penetrator and remove penetrator. Strip back Cable and crimp on connectors and swivel, connect to rope. Cut dual cap tube and reconnect pulling rings and connect to rope. Pump 10 BPH of 8.6 PPG NaCl/3%KCL brine inhibited with biocide. 04:00 12:00 8.00 12.00 W.O. L 4 P PJSM. Pull out of hole with 2-7/8” L-80 completion tubing from 5945’ to 3006’, UW 85K. Superior thread rep inspecting pipe as it is laid down. Pump 10 BPH of 8.6 PPG NaCl/3%KCL brine inhibited with biocide. 12:00 17:00 5.00 17.00 W.O. L 4 P PJSM. Pull out of hole with 2-7/8” L-80 completion tubing from 3006’ to ESP assembly, UW 65K. Superior thread rep inspecting pipe as it is laid down. Recovered all clamps, 201 total. Pump 10 BPH of 8.6 PPG NaCl/3%KCL brine inhibited with biocide. 17:00 20:30 3.50 20.50 W.O. L 20 P PJSM. Lay down ESP assembly. Lay down DGU, pump 1, pump 2, Gas separator, intake, upper and lower seals, motor, MG and centralizer. Lay down shroud. Checked all shaft rotations, good. Checked oil in upper and lower seals, good. Checked oil in motor, good. Found a piece of cement 1.5“ long x 1” x 1” X ¾” in one of the gas separator ports. 20:30 22:30 2.00 22.50 W.O. L 1 P Spool back dual cap tube and ESP cable to spooler. Rig down elephant trunk. Clean rig floor. Send all baker and GBR equipment off rig floor. 22:30 00:00 1.50 24.00 W.O. M 1 P Set boards and bring in 193 joints of TT525 drill pipe int pipe shed and strap. Note: 24 Hour Loss of 8.6 ppg Brine = 166 BBLs Total Loss of 8.6 ppg Brine = 495 BBLs Daily Contacts Position Contact Name Company Title Email Office Mobile Company Representative Steve Lawrence ASRC Energy Services Drilling Supv. siddrilling@eni.com 907-685-0715 Company Representative Mike Grubb ASRC Energy Services Drilling Supv. siddrilling@eni.com 907-685-0715 Company Representative Yelyzaveta Saprykina ASRC Energy Services Rig Clerk AKRigClerksDoyon15@eni.com 907-685-0722 Safety Representative Levi Karns ASRC Energy Services HSE Levi.Karns@external.eni.com 907-685-0721 Safety Representative John Lettow Doyon Drilling HSE rig15@doyondrilling.com 907-685-0796 Tool Push Jerad Vanderpool Doyon Drilling Tool Pusher rig15@doyondrilling.com 907-685-0727 Tool Push Tom Shones Doyon Drilling Tool Pusher rig15@doyondrilling.com 907-685-0727 Last Casing Seat Cas. Type OD (in) ID (in) Grade Top (ftKB) Bottom (ftKB) TVD Bot. (ftKB) Landing Date LINER 5 1/2 4.95 L80 -13,937.1 13,996.9 3,786.6 1/31/2012 Well Name: SP23-N3 OR Wellbore Name: SP23-N3 Well Code: 26152 Job: WORKOVER WCEI Level: LEVEL 3 Daily Report Date: 6/16/2024 Report #: 6 Page: 1 of 1 Well Header Permit/Concession N° ADL-388583 Operator ENI PETROLEUM Subsidiary ENI Petroleum Co. Inc. Initial Lahee Code DEVELOPMENT WELL Rotary Table Elevation (ft) 40.89 Ground Level (ft) First Flange (ft) 4.09 RKB - Base Flange (ft) 36.80 RKB - Tubing Spool (ft) 31.91 Rig Information Rig Name RIG 15 Contractor DOYON Rig Type LAND RIG Rig Num 0723 Daily Information Weather Clear Temperature (°F) 57.2 Wind N 2 @ 13 MPH Days LTI (days) 1,625.00 Days RI (days) POB 48.0 Daily Summary Operations 24h Forecast Pick up BHA #2 with Retrievamatic Packer and run in hole to 4616’. Test 9-5/8” casing to 1500 psi. Run in hole to 5955’ and test 9-5/8” casing. Pull out of hole with BHA #2. 24h Summary Finish loading 193 joints of 5” drill pipe, strap drill pipe in pipe shed. Pick up and make up cleanout BHA #1 with string mill and junk mill. Single in hole with 5” drill pipes to 5636’. Wash in hole from 5636’ to 5998’, stroke and scrape casing from 5998’ to 5907’MD three times. Pull out of hole from 5998’. Stand back drill pipe and lay down Cleanout BHA #1. Operation at 07.00 Run in hole with BHA #2 at 2910'. Time Log Start Time End Time Dur (hr) Cum Dur (hr)Phase Opr. Act. Plan Oper. Descr. 00:00 03:30 3.50 3.50 W.O. M 1 P Finish loading and strapping the 193 joints of TT525 drill pipe in pipe shed. Pump 10 BPH of NaCl/3%KCL brine inhibited with biocide down hole. 03:30 04:30 1.00 4.50 W.O. M 20 P Break down TIW. Set wear ring. 04:30 06:30 2.00 6.50 W.O. M 5 P PJSM. Pick up clean out BHA #1 with string mill and junk mill and stage on rig floor. Make up BHA #1 as per Baker. Pump 10 BPH of NaCl/3%KCL brine inhibited with biocide down hole. 06:30 07:30 1.00 7.50 W.O. M 4 P Trip in hole with BHA#1 clean out assembly to 530’. Pump 10 BPH of NaCl/3%KCL brine inhibited with biocide down hole. 07:30 08:30 1.00 8.50 W.O. M 25 TR03 Attempt to bring on second generator and lost power to rig, trouble shoot and bring rig back on line. 08:30 13:00 4.50 13.00 W.O. M 4 P Single in hole with 5' drill pipe and BHA#1 clean out assembly from 530’ to 4630’, UW 130K, DW 130K. Pump 10 BPH of NaCl/3%KCL brine inhibited with biocide down hole. 13:00 13:30 0.50 13.50 W.O. M 4 P Reciprocate pipe from 4630’ to 4536’ 3 times, pull out of hole and stand back 4 stands 4623’ to 4257’. UW 138K, DW135K. 13:30 16:00 2.50 16.00 W.O. M 4 P Single in hole with BHA#1 cleanout assembly from 4257’ to 5636’, UW 133 K, DW 133 K. Pump 10 BPH of NaCl/3%KCL brine inhibited with biocide down hole. 16:00 17:30 1.50 17.50 W.O. M 19 P Wash in hole from 5636’ to 5998’ at 5 BPM, 200 psi. 17:30 18:00 0.50 18.00 W.O. M 9 P Stroke and scrape casing from 5998’ to 5907’MD at 25 ft/min, 8.75 BPM, 300 psi. Pumped 239 bbls with 38% returns. 18:00 18:30 0.50 18.50 W.O. M 1 P Monitor well, fluid level dropping. Install air slips. 18:30 22:00 3.50 22.00 W.O. M 4 P Pull out of hole from 5998’ to 66’. Racking back stands of 5” drill pipe in derrick. Pump 10 BPH of NaCl/3%KCL brine inhibited with biocide down hole. 22:00 00:00 2.00 24.00 W.O. M 20 P PJSM. Lay down Baker BHA #1 from 66’ to surface. Lay down jars, bumper sub, 2 Baker magnets, Razor back scraper, string mill, XO and junk mill. Ports on junk mill were open, not plugged. BHA had thick oil with sand stuck to it about 1/16”-1/8” thick. Recovered fines to medium metal shavings of 20 pounds total on the 2 Baker magnets, no large or long pieces cuttings style. Note: 24 Hour Loss of 8.6 ppg Brine = 223 BBLs Total Loss of 8.6 ppg Brine = 718 BBLs Daily Contacts Position Contact Name Company Title Email Office Mobile Company Representative Steve Lawrence ASRC Energy Services Drilling Supv. siddrilling@eni.com 907-685-0715 Company Representative Mike Grubb ASRC Energy Services Drilling Supv. siddrilling@eni.com 907-685-0715 Company Representative Yelyzaveta Saprykina ASRC Energy Services Rig Clerk AKRigClerksDoyon15@eni.com 907-685-0722 Safety Representative Levi Karns ASRC Energy Services HSE Levi.Karns@external.eni.com 907-685-0721 Safety Representative John Lettow Doyon Drilling HSE rig15@doyondrilling.com 907-685-0796 Tool Push Jerad Vanderpool Doyon Drilling Tool Pusher rig15@doyondrilling.com 907-685-0727 Tool Push Tom Shones Doyon Drilling Tool Pusher rig15@doyondrilling.com 907-685-0727 Last Casing Seat Cas. Type OD (in) ID (in) Grade Top (ftKB) Bottom (ftKB) TVD Bot. (ftKB) Landing Date LINER 5 1/2 4.95 L80 -13,937.1 13,996.9 3,786.6 1/31/2012 Well Name: SP23-N3 OR Wellbore Name: SP23-N3 Well Code: 26152 Job: WORKOVER WCEI Level: LEVEL 3 Daily Report Date: 6/17/2024 Report #: 7 Page: 1 of 1 Well Header Permit/Concession N° ADL-388583 Operator ENI PETROLEUM Subsidiary ENI Petroleum Co. Inc. Initial Lahee Code DEVELOPMENT WELL Rotary Table Elevation (ft) 40.89 Ground Level (ft) First Flange (ft) 4.09 RKB - Base Flange (ft) 36.80 RKB - Tubing Spool (ft) 31.91 Rig Information Rig Name RIG 15 Contractor DOYON Rig Type LAND RIG Rig Num 0723 Daily Information Weather Clear Temperature (°F) 35.4 Wind NE @ 16 MPH Days LTI (days) 1,626.00 Days RI (days) POB 57.0 Daily Summary Operations 24h Forecast Pull out of hole from 5977’ to 4616’. Wash and ream in hole from 4549’ to 5980’ MD. Circulate hole with 2 bottoms up. Pull out of hole to surface. Pick up packer BHA #4, run in hole. 24h Summary Pick up BHA #2 with Retrievamatic Packer and run in hole to 4599’ and test 9-5/8” casing to 1500 psi. Unseat packer and run in hole from to 4833’, observed drag up to 25K. Pull out of hole lay down packer BHA #2. Pick up cleanout BHA #3 with magnets and scrapers, run in to 4549’, wash and ream from 4549’ to 5980’. Start circulating. Operation at 07.00 Circulate bottoms up. Time Log Start Time End Time Dur (hr) Cum Dur (hr)Phase Opr. Act. Plan Oper. Descr. 00:00 01:00 1.00 1.00 W.O. M 1 P PJSM. Clear floor of BHA #1. Pump 10 BPH of 8.6 PPG NaCl/3%KCL brine inhibited with biocide down hole. 01:00 02:00 1.00 2.00 W.O. M 5 P PJSM. Pick up and make up BHA #2 Retrievamatic test packer assembly. Trip in hole from surface to 114’. 02:00 02:30 0.50 2.50 W.O. M 1 P Service rig, Grease crown, blocks, draw works and top drive. Pump 10 BPH of 8.6 PPG NaCl/3%KCL brine inhibited with biocide down hole. 02:30 05:00 2.50 5.00 W.O. M 4 P Trip in hole with BHA #2 on 5” drill pipe from 114’ to 2724’, DW 113K. Pump 10 BPH of 8.6 PPG NaCl/3%KCL brine inhibited with biocide down hole. 05:00 06:30 1.50 6.50 W.O. M 25 TR99 Troubleshoot ST100 Iron Roughneck. The control for the makeup and break out had gotten wet, switches were replaced. Pump 10 BPH of 8.6 PPG NaCl/3%KCL brine inhibited with biocide down hole. 06:30 08:30 2.00 8.50 W.O. M 4 P Trip in hole with BHA #2 on 5” drill pipe from 2724’ to 4608’, DW 130K. Pump 10 BPH of 8.6 PPG NaCl/3%KCL brine inhibited with biocide down hole. 08:30 10:00 1.50 10.00 W.O. M 19 P Set Baker Retrievamatic test packer, with center of element at 4599’ perform casing test to 1500 psi, in 500 PSI increments for 5 minutes each and at 1500 PSI for 30 minutes. Good test. 10:00 11:00 1.00 11.00 W.O. M 4 P Release Baker Retrievamatic test packer, and trip in hole 4599’ to 4833’ Began to see 20-25K drag, picked up sticky with. 25K over pull UW 140K, DW 130K. 11:00 15:00 4.00 15.00 W.O. M 4 P Pull out of hole with Baker Retrievamatic test packer from 4833’ to 4120’ pulling wet. Continue to pull out of hole to BHA. Pump 10 BPH of 8.6 PPG NaCl/3%KCL brine inhibited with biocide down hole. 15:00 16:30 1.50 16.50 W.O. M 20 P PJSM. Lay down BHA #2, Retrivamatic packer. Clean and clear floor. 16:30 18:00 1.50 18.00 W.O. M 4 P PJSM. Pick up BHA #3, magnets, jars, jars, scraper #1, pup joint, scraper #2, bumper sub, make up 8.5” tri-cone bit. Run in hole to 75’. 18:00 20:30 2.50 20.50 W.O. M 4 P Trip in hole from 75’ to 4549’ MD. DW=104 k. Pump 10 BPH of 8.6 PPG NaCl/3%KCL brine inhibited with biocide down hole. 20:30 23:30 3.00 23.50 W.O. M 9 P Fill pipe and wash down from 4549’ to 5980’ MD, 5.7 BPM, 160 psi, 40 RPM, TQ=2-4 k. No obstructions observed. 23:30 00:00 0.50 24.00 W.O. M 7 P Start circulating and reciprocating from 5980’ to 5948’, 5.7 BPM, 160 psi, 40 RPM, TQ=2-4 K. Pump 10 BPH of 8.6 PPG NaCl/3%KCL brine inhibited with biocide down hole. Note: 24 Hour Loss of 8.6 ppg Brine = 596 BBLs Total Loss of 8.6 ppg Brine = 1314 BBLs Daily Contacts Position Contact Name Company Title Email Office Mobile Company Representative Steve Lawrence ASRC Energy Services Drilling Supv. siddrilling@eni.com 907-685-0715 Company Representative Mike Grubb ASRC Energy Services Drilling Supv. siddrilling@eni.com 907-685-0715 Company Representative Yelyzaveta Saprykina ASRC Energy Services Rig Clerk AKRigClerksDoyon15@eni.com 907-685-0722 Safety Representative Levi Karns ASRC Energy Services HSE Levi.Karns@external.eni.com 907-685-0721 Safety Representative John Lettow Doyon Drilling HSE rig15@doyondrilling.com 907-685-0796 Tool Push Jerad Vanderpool Doyon Drilling Tool Pusher rig15@doyondrilling.com 907-685-0727 Tool Push Tom Shones Doyon Drilling Tool Pusher rig15@doyondrilling.com 907-685-0727 Last Casing Seat Cas. Type OD (in) ID (in) Grade Top (ftKB) Bottom (ftKB) TVD Bot. (ftKB) Landing Date LINER 5 1/2 4.95 L80 -13,937.1 13,996.9 3,786.6 1/31/2012 Well Name: SP23-N3 OR Wellbore Name: SP23-N3 Well Code: 26152 Job: WORKOVER WCEI Level: LEVEL 3 Daily Report Date: 6/18/2024 Report #: 8 Page: 1 of 1 Well Header Permit/Concession N° ADL-388583 Operator ENI PETROLEUM Subsidiary ENI Petroleum Co. Inc. Initial Lahee Code DEVELOPMENT WELL Rotary Table Elevation (ft) 40.89 Ground Level (ft) First Flange (ft) 4.09 RKB - Base Flange (ft) 36.80 RKB - Tubing Spool (ft) 31.91 Rig Information Rig Name RIG 15 Contractor DOYON Rig Type LAND RIG Rig Num 0723 Daily Information Weather Clear Temperature (°F) 34.7 Wind NE @ 20 MPH Days LTI (days) 1,627.00 Days RI (days) POB 55.0 Daily Summary Operations 24h Forecast Continue to trip in hole to 4500’. Wash down from 4500’ to 5970’ at 2.5 BPM, 60 ft/min. Set packer at 5970’, stage pressure up to 1500 psi (Charted), and test at 1500 psi for 30 minutes. Pull out of hole, rack back drill pipe, lay down BHA #4 test packer. 24h Summary Continue circulating. Pull out of hole from to 4600’. Wash and ream in hole from 4600’ to 5979’ MD. Circulate hole. Pull out of hole to 4600’. Trip in hole to 5979’ to ensure clean. Pull out of hole to surface. Pick up BHA #4 packer assembly and run in hole to 2520’. Test 9-5/8” casing to 1000 psi for 15 minutes, good test. Unseat packer and trip in hole from 2520’ to 4000’ MD. Operation at 07.00 Test casing at 4577'. Time Log Start Time End Time Dur (hr) Cum Dur (hr)Phase Opr. Act. Plan Oper. Descr. 00:00 01:00 1.00 1.00 W.O. M 7 P Continue circulating and reciprocating from 5980’ to 5948’, 5.7 BPM, 160 psi, 40 RPM, TQ=2-4 K. Pump 10 BPH of 8.6 PPG NaCl/3%KCL brine inhibited with biocide down hole. 01:00 02:30 1.50 2.50 W.O. M 4 P PJSM. Pull out of hole from 5977’ to 4600’ on elevators. UW 140K, DW 130K. Observed 7K overpull from 4665’ to 4641’. Pump 10 BPH plus metal displacement of 8.6 PPG NaCl/3%KCL brine inhibited with biocide down hole. 02:30 05:30 3.00 5.50 W.O. M 6 P Wash and ream from 4600’ to 5979, at 6.2 BPM, 190 PSI, 40 RPM, 4-7K TQ., ROT 140K. 05:30 10:00 4.50 10.00 W.O. M 7 P Circulate and reciprocate from 5949’ to 5979’, at 6.2 BPM, 190 PSI, 40 RPM 3-6K TQ., UW 150K, DW 133K, ROT 140K, final circulating rate 7.25 BPM. Partial returns throughout circulation varied from 51% to 75%, pumped a total of 1890 BBL. 10:00 12:30 2.50 12.50 W.O. M 4 P Perform wiper trip pull out of hole from 5979’ to 4600’, trip back in hole to 5979’. UW = 145K, DW = 130K. Pump 10 BPH of 8.6 PPG NaCl/3%KCL brine inhibited with biocide down hole. 12:30 16:30 4.00 16.50 W.O. M 4 P Pull out of hole with clean out BHA #3 from 4979’ to BHA at 74’. Had 5K over pull from 4700’ to 4650’. Pump 10 BPH plus metal displacement of 8.6 PPG NaCl/3%KCL brine inhibited with biocide down hole. 16:30 18:30 2.00 18.50 W.O. M 20 P Pull out of hole laying down BHA #3 from 74’ to surface. Lay down 8.5” bit, bit sub, 2 razor back scrapers and pup, 2 magnets and jars. Clean and clear floor. Pump 10 BPH plus metal displacement of 8.6 PPG NaCl/3%KCL brine inhibited with biocide down hole. 18:30 19:00 0.50 19.00 W.O. M 1 P Service rig: grease draw works, top drive and ST-80. 19:00 19:30 0.50 19.50 W.O. M 5 P PJSM. Pick up and run in hole with BHA #4 test retrievamatic test packer from surface to 24’. 19:30 22:00 2.50 22.00 W.O. M 19 P Trip in hole from 24’ to 2520’ with retrievamatic test packer BHA #4 on TT525 drill pipe on elevators. Set test packer at 2510’ center of element. Test 9-5/8” casing to 1000 psi for 15 minutes, good test (charted). Stage pressure up in 500 psi increments. Unseat packer. Pump 10 BPH of 8.6 PPG NaCl/3%KCL brine inhibited with biocide down hole. 22:00 00:00 2.00 24.00 W.O. M 4 P Trip in hole from 2520’ to 4000’ MD, DW=117. Pump 10 BPH of 8.6 PPG NaCl/3%KCL brine inhibited with biocide down hole. Note: 24 Hour Loss of 8.6 ppg Brine = 1618 BBLs Total Loss of 8.6 ppg Brine = 2932 BBLs Daily Contacts Position Contact Name Company Title Email Office Mobile Company Representative Steve Lawrence ASRC Energy Services Drilling Supv. siddrilling@eni.com 907-685-0715 Company Representative Mike Grubb ASRC Energy Services Drilling Supv. siddrilling@eni.com 907-685-0715 Company Representative Yelyzaveta Saprykina ASRC Energy Services Rig Clerk AKRigClerksDoyon15@eni.com 907-685-0722 Safety Representative Levi Karns ASRC Energy Services HSE Levi.Karns@external.eni.com 907-685-0721 Tool Push Jerad Vanderpool Doyon Drilling Tool Pusher rig15@doyondrilling.com 907-685-0727 Tool Push Tom Shones Doyon Drilling Tool Pusher rig15@doyondrilling.com 907-685-0727 Last Casing Seat Cas. Type OD (in) ID (in) Grade Top (ftKB) Bottom (ftKB) TVD Bot. (ftKB) Landing Date LINER 5 1/2 4.95 L80 -13,937.1 13,996.9 3,786.6 1/31/2012 Well Name: SP23-N3 OR Wellbore Name: SP23-N3 Well Code: 26152 Job: WORKOVER WCEI Level: LEVEL 3 Daily Report Date: 6/19/2024 Report #: 9 Page: 1 of 1 Well Header Permit/Concession N° ADL-388583 Operator ENI PETROLEUM Subsidiary ENI Petroleum Co. Inc. Initial Lahee Code DEVELOPMENT WELL Rotary Table Elevation (ft) 40.89 Ground Level (ft) First Flange (ft) 4.09 RKB - Base Flange (ft) 36.80 RKB - Tubing Spool (ft) 31.91 Rig Information Rig Name RIG 15 Contractor DOYON Rig Type LAND RIG Rig Num 0723 Daily Information Weather Clear Temperature (°F) 35.2 Wind NE @ 7 MPH Days LTI (days) 1,628.00 Days RI (days) POB 54.0 Daily Summary Operations 24h Forecast Run in hole to re-run with CAST logging tool from 5050 to 4600’. Pull out of hole and lay down tools, rig down Halliburton and Welltec. Clean and clear floor. Remove wear bushing. Rig up hoses to pump 10 BBLS brine down annulus every hour. Test BOPE to 250/3000 psi. 24h Summary Continue to trip in hole from 4000’ to 4500’. Wash down from 4500’ to 5980’ at 2.5 BPM, 60 ft/min. Set packer at 5969’, attempt to test 9-5/8” casing no success. Attempt to test at 4750’ packer would not set. Set packer at 4829’ attempt test with no success. Pull up to 4577’ set packer and pressured 9-5/8” casing to 500 PSI for 5 minutes, 1000 PSI for 15 minutes to confirm no leaks across packer. Good test. Release packer and pull out of hole, lay down BHA. Rig up wire line. RIH with CAST logging tool, log from 5955’ to surface. Send in logs to be interpreted. Running in hole for re-run with CAST logging tool. Operation at 07.00 Rig up to test BOPE. Time Log Start Time End Time Dur (hr) Cum Dur (hr)Phase Opr. Act. Plan Oper. Descr. 00:00 01:00 1.00 1.00 W.O. M 4 P Trip in hole from 4000’ to 4500’ MD, DW=117. Pump 10 BPH of 8.6 PPG NaCl/3%KCL brine inhibited with biocide down hole. 01:00 03:00 2.00 3.00 W.O. M 9 P Wash down from 4500’ to 5980’ MD, at 2-2.5 BPM. No obstructions observed. 03:00 04:30 1.50 4.50 W.O. M 19 P Set packer center of element at 5969’. Set 35K on packer, fill hole and shut annular. Attempt to test 9-5/8” casing pumping at 0.5 BPM for a total of 10 BBLs pumped, did not pressure up past 30 psi. Open annular to check and make sure all air was out and retested with same result, pumping 8 BBLs. Check surface equipment to insure proper alignment, set another 15K down for a total of 50K, and attempt to test with no success. 04:30 05:30 1.00 5.50 W.O. M 4 P Release packer and pull out of hole from 5980’ to 4759’ MD. UW 140K. Pump 10 BPH plus metal displacement of 8.6 PPG NaCl/3%KCL brine inhibited with biocide down hole. 05:30 06:30 1.00 6.50 W.O. M 19 P At 4750’ MD, made attempt to set packer without success, trip in hole to 4829’, and set test packer with 40K down weight. Filled stack with brine and watched fluid level fall down hole. Applied another 10K for a total of 50K down weight filled the stack with the same results. Timed rate of fluid falling with packer set 44 seconds from the flow line to upper rams, with packer released fluid fell in 28 seconds. 06:30 08:00 1.50 8.00 W.O. M 19 P Unseat packer and pull out of hole with BHA #4 Baker Retrievamatic test packer from 4829’ to 4577’, and set test packer. Pressure test casing to 500 PSI for 5 minutes, 1000 PSI for 15 minutes to confirm no leaks across packer. Good test. 08:00 11:00 3.00 11.00 W.O. M 4 P Release packer and pull out of hole to surface with BHA #4 Baker Retrievamatic test packer. Pump 10 BPH plus metal displacement of 8.6 PPG NaCl/3%KCL brine inhibited with biocide down hole. 11:00 12:00 1.00 12.00 W.O. M 5 P Lay down BHA #4. Pump 10 BPH of 8.6 PPG NaCl/3%KCL brine inhibited with biocide down hole. 12:00 12:30 0.50 12.50 W.O. M 1 P Clean and clear rig floor of BHA. Pump 10 BPH of 8.6 PPG NaCl/3%KCL brine inhibited with biocide down hole. 12:30 14:30 2.00 14.50 W.O. R 1 P PJSM with Doyon, Halliburton, and Weltec. Rig up Halliburton CAST logging tool, with Weltec tractor, and surface test tools all good. Pump 10 BPH of 8.6 PPG NaCl/3%KCL brine inhibited with biocide down hole. 14:30 16:30 2.00 16.50 W.O. R 4 P RIH with CAST logging tool to 4849’ and engage Weltec tractor, tractor to 5955’. Pump 10 BPH of 8.6 PPG NaCl/3%KCL brine inhibited with biocide down hole. SIMOPS: General housekeeping. Seal up draw works housing. Clean ST-100. Perform pump inventory. Change out water feed valves for testing on rig floor. 16:30 23:30 7.00 23.50 W.O. J 11 P Log up with Cast tool from 5955’ to surface at 10-18 Ft/min. Pump 10 BPH of 8.6 PPG NaCl/3%KCL brine inhibited with biocide down hole. Clean and scrub around pipe skate. Remove skate cylinder for repair. 23:30 00:00 0.50 24.00 W.O. R 4 P RIH from surface to 500’ for rerun with CAST logging tool from 5050’ to 4600’. Note: 24 Hour Loss of 8.6 ppg Brine = 534 BBLs Total Loss of 8.6 ppg Brine = 3466 BBLs Daily Contacts Position Contact Name Company Title Email Office Mobile Company Representative Steve Lawrence ASRC Energy Services Drilling Supv. siddrilling@eni.com 907-685-0715 Company Representative Mike Grubb ASRC Energy Services Drilling Supv. siddrilling@eni.com 907-685-0715 Company Representative Yelyzaveta Saprykina ASRC Energy Services Rig Clerk AKRigClerksDoyon15@eni.com 907-685-0722 Safety Representative Levi Karns ASRC Energy Services HSE Levi.Karns@external.eni.com 907-685-0721 Tool Push Jerad Vanderpool Doyon Drilling Tool Pusher rig15@doyondrilling.com 907-685-0727 Tool Push Tom Shones Doyon Drilling Tool Pusher rig15@doyondrilling.com 907-685-0727 Last Casing Seat Cas. Type OD (in) ID (in) Grade Top (ftKB) Bottom (ftKB) TVD Bot. (ftKB) Landing Date LINER 5 1/2 4.95 L80 -13,937.1 13,996.9 3,786.6 1/31/2012 Well Name: SP23-N3 OR Wellbore Name: SP23-N3 Well Code: 26152 Job: WORKOVER WCEI Level: LEVEL 3 Daily Report Date: 6/20/2024 Report #: 10 Page: 1 of 1 Well Header Permit/Concession N° ADL-388583 Operator ENI PETROLEUM Subsidiary ENI Petroleum Co. Inc. Initial Lahee Code DEVELOPMENT WELL Rotary Table Elevation (ft) 40.89 Ground Level (ft) First Flange (ft) 4.09 RKB - Base Flange (ft) 36.80 RKB - Tubing Spool (ft) 31.91 Rig Information Rig Name RIG 15 Contractor DOYON Rig Type LAND RIG Rig Num 0723 Daily Information Weather Clear Temperature (°F) 32.2 Wind NE @ 5 MPH Days LTI (days) 1,629.00 Days RI (days) POB 53.0 Daily Summary Operations 24h Forecast Finish picking up BHA #5 VACs tool and 2-7/8” stinger joints and run in hole. Run in hole with 2-7/8” BHA #5 on 5” drill pipe to Liner top. Wash and ream down 1500’ into liner top and clean lateral. Pull out hole and clean VACs tool. 24h Summary Run in hole from 500’ to 5076’. Rerun log from 5060’ to 4600’. Pull out of hole and lay down tools, rig down Halliburton and Welltec. Test BOPE 250/3000 psi. Rig down test equipment. Rig up to run in hole with BHA #5 with VACs tools. Operation at 07.00 Run in hole with BHA #5 at 4527'. Time Log Start Time End Time Dur (hr) Cum Dur (hr)Phase Opr. Act. Plan Oper. Descr. 00:00 03:00 3.00 3.00 W.O. R 4 P Run in hole for re-run with CAST logging tool from 500’ to 4908’. Engage Welltec tractor, tractor to 5076’. Pump 10 BPH of 8.6 PPG NaCl/3%KCL brine inhibited with biocide down hole. 03:00 05:00 2.00 5.00 W.O. J 4 P Log up with CAST tool from 5060’ to 4600’ at 15 ft/min. Pull out of hole with E-line and Welltec tractor. 05:00 07:00 2.00 7.00 W.O. R 1 P Rig down and lay down Halliburton and Welltec tools. Clean and clear floor. 07:00 12:00 5.00 12.00 W.O. C 20 P Rig up and pull wear ring. Rig up hose on annulus A to add 10 BPH to well while testing. Make up 5” test joint, flood stack and choke manifold. Replace 2 valves on test manifold. Shell test BOPE, good test. 12:00 20:30 8.50 20.50 W.O. C 12 P Testing BOPE. Test with 2-7/8” test joint 250/3000 psi for 5 minutes each. Test annular, upper and lower variable rams 2-7/8” X 5”. Test Choke manifold valves 1, 2, 5, 6, 7, 8, 9, 10, 11, 12, 13, 14, and 15. Test upper and lower IBOP. Test primary and secondary Demco kill valves, primary and secondary HCR kill valves and primary and secondary manual kill valves. Test 2- 7/8” floor valve and dart valve. Test 2-7/8” floor valve and dart valve. Test Choke manifold valves 3 and 4. Test blind ram. Function test hydraulic and manual choke. Test annular, upper and lower Variable rams ( 2-7/8” X 5” ) with 5” test joint. Test gas alarms. Test PVT and flow alarms. Preform accumulator draw down test. Starting pressure=2950 psi, after function=2150 psi, 200 psi increase=9 seconds, Full recovery=39 seconds, Nitrogen back up 10 bottles with 4000 psi average. All test good. Witness waived by AOGCC rep Guy Cook. Continue filling annulus at 10 BPH of 8.6 PPG NaCl/ 3% KCL brine inhibited with Biocide. 20:30 22:00 1.50 22.00 W.O. C 1 P Rig down test equipment. Pull test plug. Set wear ring. Blow down choke manifold, top drive and all surface equipment. Clean and clear floor. 22:00 00:00 2.00 24.00 W.O. M 1 P PJSM with GBR and Baker. Rig up GBR power tongs. Pick up cross overs and staged BHA components to rig floor. Note: 24 Hour Loss of 8.6 ppg Brine = 534 BBLs Total Loss of 8.6 ppg Brine = 3466 BBLs Daily Contacts Position Contact Name Company Title Email Office Mobile Company Representative Bruce Simonson ASRC Energy Services Drilling Supv. siddrilling@eni.com 907-685-0715 Company Representative Mike Grubb ASRC Energy Services Drilling Supv. siddrilling@eni.com 907-685-0715 Company Representative Yelyzaveta Saprykina ASRC Energy Services Rig Clerk AKRigClerksDoyon15@eni.com 907-685-0722 Safety Representative Mark Hubler ASRC Energy Services HSE mark.hubler@external.eni.com 907-685-0721 Last Casing Seat Cas. Type OD (in) ID (in) Grade Top (ftKB) Bottom (ftKB) TVD Bot. (ftKB) Landing Date LINER 5 1/2 4.95 L80 -13,937.1 13,996.9 3,786.6 1/31/2012 Well Name: SP23-N3 OR Wellbore Name: SP23-N3 Well Code: 26152 Job: WORKOVER WCEI Level: LEVEL 3 Daily Report Date: 6/21/2024 Report #: 11 Page: 1 of 1 Well Header Permit/Concession N° ADL-388583 Operator ENI PETROLEUM Subsidiary ENI Petroleum Co. Inc. Initial Lahee Code DEVELOPMENT WELL Rotary Table Elevation (ft) 40.89 Ground Level (ft) First Flange (ft) 4.09 RKB - Base Flange (ft) 36.80 RKB - Tubing Spool (ft) 31.91 Rig Information Rig Name RIG 15 Contractor DOYON Rig Type LAND RIG Rig Num 0723 Daily Information Weather Clear Temperature (°F) 37.0 Wind N @ 9 MPH Days LTI (days) 1,630.00 Days RI (days) POB 59.0 Daily Summary Operations 24h Forecast Run in hole with BHA #6, VACs tool and 2-7/8” stinger joints (250’). Wash and ream down into liner top from 6099’ to 6250'. Pull out hole and clean VACs tool. Prepare and run Hex plug. Pull out of hole and prepare to run retievamatic packer. 24h Summary Pick up and run in hole with BHA #5. Finish picking up BHA #5, VACs tool and 2-7/8” stinger joints and run in hole. Run in hole with 2-7/8” BHA #5 on 5” drill pipe to Liner top. Wash and ream down 94’ into liner top and clean lateral. Pull out hole and clean VACs tool. Make up BHA #6 VACs tool with 250’ snorkel and run in hole from surface to 1150’ MD. Operation at 07.00 Cutting and slipping drill line. Time Log Start Time End Time Dur (hr) Cum Dur (hr)Phase Opr. Act. Plan Oper. Descr. 00:00 00:30 0.50 0.50 W.O. M 1 P Service drawworks. Continue filling annulus at 10 BPH of 8.6 PPG NaCl/ 3% KCL brine inhibited with Biocide. 00:30 05:30 5.00 5.50 W.O. M 5 P Pick up BHA #5, pick up Mule shoe and flapper assembly. Make up PH6 joints and GBR make up with power tongs to 4K, run in hole from surface to 1507’. Pick up BHA #5 upper assembly, VACs tool, magnets and jars. Run in hole from 1507’ to 1651’. Continue filling annulus at 10 BPH of 8.6 PPG NaCl/ 3% KCL brine inhibited with Biocide. 05:30 07:30 2.00 7.50 W.O. M 4 P Run in hole with VACs tool on 5” drill pipe from 1651’ to 5833’. PU=148 k, SO=131. Continue filling annulus at 10 BPH of 8.6 PPG NaCl/ 3% KCL brine inhibited with Biocide. 07:30 10:30 3.00 10.50 W.O. M 9 P Wash down from 5833’ to 6062’ at 3 BPM, 340 psi. Start taking weight (10K). Orient pipe and attempt to wash through. Wash from 6062’ to 6074’, taking 10K weight, start rotation 20-30 rpm, 3-5K torque, wash and ream from 6074’ to 6099’ taking weight, attempt to work though without success. Decision made to pull out of hole. 10:30 14:00 3.50 14.00 W.O. M 4 P Pull to 6016’. Monitor well at 6016’. Blow down top drive. PJSM, pull out of hole on elevators from 6016’ to 1600’ MD, PU=80 K. Continue filling annulus at 10 BPH plus metal displacement with 8.6 PPG NaCl/ 3% KCL brine inhibited with Biocide 14:00 16:00 2.00 16.00 W.O. M 5 P PJSM. Lay down BHA #5 from 1600’ to 1500’. 16:00 16:30 0.50 16.50 W.O. M 25 P Change out tubing elevators, safety latch not latching, bad spring. Continue filling annulus at 10 BPH plus metal displacement with 8.6 PPG NaCl/ 3% KCL brine inhibited with Biocide. 16:30 20:00 3.50 20.00 W.O. M 5 P Continue laying down BHA #5 from 1500’ to surface. Lay down PH6 tubing, Clean magnets ( recover 5 LBS of fines), VACs tool, wash pipe. 155’ of compacted sand in PH6 tubing, 0.9 bbl, recovered gravel from on top of lower flapper some pieces up to ½” size. Continue filling annulus at 10 BPH with 8.6 PPG NaCl/ 3% KCL brine inhibited with Biocide. 20:00 21:00 1.00 21.00 W.O. M 1 P Clean and clear rig floor. 21:00 23:30 2.50 23.50 W.O. M 5 P PJSM. Pick up and run in hole BHA #6 from surface to 250’. Pick up PH6 snorkel 300’, VACS tool, magnets, scraper, oil jars. Continue filling annulus at 10 BPH plus metal displacement with 8.6 PPG NaCl/ 3% KCL brine inhibited with Biocide. 23:30 00:00 0.50 24.00 W.O. M 4 P Run in hole with VACs tool on 5” drill pipe from 300’ to 1150’ MD, PU=103K, SO=103K. Note: 24 Hour Loss of 8.6 ppg Brine = 522 BBLs Total Loss of 8.6 ppg Brine = 3988 BBLs Daily Contacts Position Contact Name Company Title Email Office Mobile Company Representative Bruce Simonson ASRC Energy Services Drilling Supv. siddrilling@eni.com 907-685-0715 Company Representative Mike Grubb ASRC Energy Services Drilling Supv. siddrilling@eni.com 907-685-0715 Company Representative Yelyzaveta Saprykina ASRC Energy Services Rig Clerk AKRigClerksDoyon15@eni.com 907-685-0722 Safety Representative Mark Hubler ASRC Energy Services HSE mark.hubler@external.eni.com 907-685-0721 Tool Push Robert Krug Doyon Drilling Tour Pusher rig15@doyondrilling.com 907-685-0716 Last Casing Seat Cas. Type OD (in) ID (in) Grade Top (ftKB) Bottom (ftKB) TVD Bot. (ftKB) Landing Date LINER 5 1/2 4.95 L80 -13,937.1 13,996.9 3,786.6 1/31/2012 Well Name: SP23-N3 OR Wellbore Name: SP23-N3 Well Code: 26152 Job: WORKOVER WCEI Level: LEVEL 3 Daily Report Date: 6/22/2024 Report #: 12 Page: 1 of 1 Well Header Permit/Concession N° ADL-388583 Operator ENI PETROLEUM Subsidiary ENI Petroleum Co. Inc. Initial Lahee Code DEVELOPMENT WELL Rotary Table Elevation (ft) 40.89 Ground Level (ft) First Flange (ft) 4.09 RKB - Base Flange (ft) 36.80 RKB - Tubing Spool (ft) 31.91 Rig Information Rig Name RIG 15 Contractor DOYON Rig Type LAND RIG Rig Num 0723 Daily Information Weather Clear Temperature (°F) 34.7 Wind NE @ 14 MPH Days LTI (days) 1,631.00 Days RI (days) POB 60.0 Daily Summary Operations 24h Forecast Wash down into liner top from 6101’ to 6250. Pull out hole and clean VACs tool. Prepare and run Hex plug. Pull out of hole and prepare and run retievamatic packer. 24h Summary Run in hole with BHA #6. Wash and ream down to 6101’ MD. Pull out of hole to 4779’. Slip and cut drilling line. Continue pulling out of hole. Lay down BHA #6 and recover 0.5 bbls of sand. Make up BHA #7 with VACs and magnets. Run in hole to 5990’ MD. Wash down from 5990’ to 6100’. Operation at 07.00 Laying down BHA #7. Time Log Start Time End Time Dur (hr) Cum Dur (hr)Phase Opr. Act. Plan Oper. Descr. 00:00 02:30 2.50 2.50 W.O. M 4 P Run in hole with VACs tool on 5” drill pipe from 1150’ to 5712’ MD, PU=152K, SO=128K, started washing slight hole drag of 5K. 02:30 05:00 2.50 5.00 W.O. M 9 P Wash down from 5712’ to 6101’, 20 ft/min, 3.7 BPM, 365 psi. Entering liner top without indication of resistance. Started taking weight at 6101’ MD. Stroked up and down without rotation with same results, taking weight (10K) at 6101’. Stroked several times pumping at 3.7 BPM. Stroked up and started rotation at 15-20 RPM, 3.8K-4.2K. Stroked up and down several times and stalling out at 6.2K torque at 6101’. Increased torque limiter to 8K. Made a few more attempts stalled out, bumped up flow to 6 BPM and stroked without success. Over pull to 15K at 6101’. Pull up to 6082’ and prepare to pull out of hole. 05:00 05:30 0.50 5.50 W.O. M 1 P Monitor well, blow down top drive. 05:30 06:30 1.00 6.50 W.O. M 4 P PJSM. Pull out of hole from 6082’ to 4779’. PU=147K. Continue filling annulus at 10 BPH plus metal displacement with 8.6 PPG NaCl/ 3% KCL brine inhibited with Biocide. 06:30 09:30 3.00 9.50 W.O. M 20 P Slip and cut 98’ of drilling line. Calibrate block height. Rig service, lube top drive, crown and blocks. 09:30 11:30 2.00 11.50 W.O. M 4 P Pull out of hole with BHA #6 from 4779’ to 399’ MD. Continue filling annulus at 10 BPH plus metal displacement with 8.6 PPG NaCl/ 3% KCL brine inhibited with Biocide. 11:30 17:00 5.50 17.00 W.O. M 20 P Lay down BHA #6, lay down Vacs tool. Rig up GBR, lay down 2-7/8” drill pipe. Last 3 joints full of sand (.5 bbls of sand recovered). Break down flapper assembly from pups. Recover 3 LBS of fines on magnets. No scaring on mule shoe. Clean and clear floor. 17:00 19:00 2.00 19.00 W.O. M 5 P Make up BHA #7 run in hole from surface to 399’, mule shoe with bent joint (OD=3.62”), double flapper valves, 2-7/8” pup joint, 8 joints of 2-7/8” PH6, GBR make up to 4K with power tongs. Pick up VACs tool, scraper, magnets, oil jars and bumper sub. 19:00 23:00 4.00 23.00 W.O. M 4 P Run in hole from 399’ to 5990’ MD, PU=150K, SO=123K. 23:00 00:00 1.00 24.00 W.O. M 9 P Fill pipe, wash down from 5990 to 6100', 3.7 BPM, 350 psi, 61% returns. Stroke from 6085 to 6100’ MD, (taking 10K weight) in attempt to work through. Pull up and turn pipe 360° and work turn down, continue stroking. Note: 24 Hour Loss of 8.6 ppg Brine = 533 BBLs Total Loss of 8.6 ppg Brine = 4,521 BBLs Daily Contacts Position Contact Name Company Title Email Office Mobile Company Representative Bruce Simonson ASRC Energy Services Drilling Supv. siddrilling@eni.com 907-685-0715 Company Representative Mike Grubb ASRC Energy Services Drilling Supv. siddrilling@eni.com 907-685-0715 Company Representative Yelyzaveta Saprykina ASRC Energy Services Rig Clerk AKRigClerksDoyon15@eni.com 907-685-0722 Safety Representative Mark Hubler ASRC Energy Services HSE mark.hubler@external.eni.com 907-685-0721 Tool Push Grant Neuharth Doyon Drilling Tool Pusher rig15@doyondrilling.com 907-685-0727 Safety Representative Derek Ambrose Doyon Drilling HSE rig15@doyondrilling.com 907-685-0796 Last Casing Seat Cas. Type OD (in) ID (in) Grade Top (ftKB) Bottom (ftKB) TVD Bot. (ftKB) Landing Date LINER 5 1/2 4.95 L80 -13,937.1 13,996.9 3,786.6 1/31/2012 Well Name: SP23-N3 OR Wellbore Name: SP23-N3 Well Code: 26152 Job: WORKOVER WCEI Level: LEVEL 3 Daily Report Date: 6/23/2024 Report #: 13 Page: 1 of 1 Well Header Permit/Concession N° ADL-388583 Operator ENI PETROLEUM Subsidiary ENI Petroleum Co. Inc. Initial Lahee Code DEVELOPMENT WELL Rotary Table Elevation (ft) 40.89 Ground Level (ft) First Flange (ft) 4.09 RKB - Base Flange (ft) 36.80 RKB - Tubing Spool (ft) 31.91 Rig Information Rig Name RIG 15 Contractor DOYON Rig Type LAND RIG Rig Num 0723 Daily Information Weather Clear Temperature (°F) 33.3 Wind NE @ 10 MPH Days LTI (days) 1,632.00 Days RI (days) POB 60.0 Daily Summary Operations 24h Forecast Finish trouble shooting ST-100. Run in hole with BHA #8, VACs tool, polish mill and wash down from 4500’ to liner top. Pull out hole and clean VACs tool. Prepare and run Hex plug. 24h Summary Attempt to wash down L1, wash down to 6108’, started taking weight of 10K. Pull out of hole from 6108’ to surface and lay down BHA #7, Vacs tool. Troubleshoot ST-100, iron roughneck. Operation at 07.00 Troubleshoot ST-100, iron roughneck. Time Log Start Time End Time Dur (hr) Cum Dur (hr)Phase Opr. Act. Plan Oper. Descr. 00:00 02:30 2.50 2.50 W.O. M 19 P PJSM. Rack back stand #22, pick up single. Continue to attempt to wash down past 6101’ MD. Pumping at 3.5 BPM, 345 psi. Pick up to 6045’ orient pipe 90°, wash down to 6062’, took 10K weight, pull up to 6045’. Turn off top drive brake and wash down to 6108’, started taking weight of 10K. Pick up and turn pipe 90° working turn down hole past 6108’. Returns at 93%. 02:30 03:00 0.50 3.00 W.O. M 1 P Lay down single, blow down top drive and monitor well. 03:00 06:30 3.50 6.50 W.O. M 4 P PJSM. Pull out of hole with BHA #7 from 6082’ to 399’. Continue filling annulus at 10 BPH plus metal displacement with 8.6 PPG NaCl/ 3% KCL brine inhibited with Biocide. 06:30 09:30 3.00 9.50 W.O. M 20 P Lay down Vacs tool BHA #7 from 399’ to surface. Recover 3 lbs of metal fines from magnets. Lay down 8 joints of PH6 and flappers, no sand recovered. Continue filling annulus at 10 BPH plus metal displacement with 8.6 PPG NaCl/ 3% KCL brine inhibited with Biocide. 09:30 12:00 2.50 12.00 W.O. M 1 P Clean and clear floor. Rig service. Continue filling annulus at 10 BPH with 8.6 PPG NaCl/ 3% KCL brine inhibited with Biocide. 12:00 00:00 12.00 24.00 W.O. M 25 TR99 PJSM. Work on ST-100. Remove spinner frame from ST- 100 and take to weld shop. Weld and repair spinner head bolt bracket for spinner frame. Reinstall spinner head. Change out kicker cylinder. Troubleshoot electrical issue. SIMOPS: Pressure wash and cleaning rig. Prepare BHA #8 to pick up. Continue filling annulus at 10 BPH 8.6 PPG NaCl/ 3% KCL brine inhibited with Biocide. Note: 24 Hour Loss of 8.6 ppg Brine = 300 BBLs Total Loss of 8.6 ppg Brine = 4,821 BBLs Daily Contacts Position Contact Name Company Title Email Office Mobile Company Representative Bruce Simonson ASRC Energy Services Drilling Supv. siddrilling@eni.com 907-685-0715 Company Representative Mike Grubb ASRC Energy Services Drilling Supv. siddrilling@eni.com 907-685-0715 Company Representative Yelyzaveta Saprykina ASRC Energy Services Rig Clerk AKRigClerksDoyon15@eni.com 907-685-0722 Safety Representative Mark Hubler ASRC Energy Services HSE mark.hubler@external.eni.com 907-685-0721 Tool Push Grant Neuharth Doyon Drilling Tool Pusher rig15@doyondrilling.com 907-685-0727 Safety Representative Derek Ambrose Doyon Drilling HSE rig15@doyondrilling.com 907-685-0796 Last Casing Seat Cas. Type OD (in) ID (in) Grade Top (ftKB) Bottom (ftKB) TVD Bot. (ftKB) Landing Date LINER 5 1/2 4.95 L80 -13,937.1 13,996.9 3,786.6 1/31/2012 Well Name: SP23-N3 OR Wellbore Name: SP23-N3 Well Code: 26152 Job: WORKOVER WCEI Level: LEVEL 3 Daily Report Date: 6/24/2024 Report #: 14 Page: 1 of 1 Well Header Permit/Concession N° ADL-388583 Operator ENI PETROLEUM Subsidiary ENI Petroleum Co. Inc. Initial Lahee Code DEVELOPMENT WELL Rotary Table Elevation (ft) 40.89 Ground Level (ft) First Flange (ft) 4.09 RKB - Base Flange (ft) 36.80 RKB - Tubing Spool (ft) 31.91 Rig Information Rig Name RIG 15 Contractor DOYON Rig Type LAND RIG Rig Num 0723 Daily Information Weather Clear Temperature (°F) 36.3 Wind NE @ 14 MPH Days LTI (days) 1,633.00 Days RI (days) POB 58.0 Daily Summary Operations 24h Forecast Finish trouble shooting ST-100. Run in hole with BHA #8, VACs tool, polish mill and wash down from 4500’ to liner top. Pull out hole and clean VACs tool. Prepare and run Hex plug. 24h Summary Continue to troubleshoot ST-100, iron roughneck. Operation at 07.00 Continue to troubleshoot ST-100, iron roughneck. Time Log Start Time End Time Dur (hr) Cum Dur (hr)Phase Opr. Act. Plan Oper. Descr. 00:00 06:00 6.00 6.00 W.O. M 25 TR99 PJSM. Work on ST-100, Iron rough neck. Troubleshoot electrical issue. SIMOPS: Pressure wash and cleaning rig. Prepare BHA #8 to pick up. Continue filling annulus top off annulus with 1-1.5 BPH 8.6 PPG NaCl/ 3% KCL brine inhibited with Biocide. 06:00 12:00 6.00 12.00 W.O. M 25 TR99 Continue to troubleshoot ST-100, communication issue. SIMOPS: Prepare BHA #8 to pick up. Clean and organize around rig. General rig maintenance. Continue filling annulus top off annulus with 1-1.5 BPH 8.6 PPG NaCl/ 3% KCL brine inhibited with Biocide. 12:00 18:00 6.00 18.00 W.O. M 25 TR99 Continue to troubleshoot ST-100, communication issue. SIMOPS: Clean and organize around rig. Continue filling annulus top off annulus with 1-1.5 BPH 8.6 PPG NaCl/ 3% KCL brine inhibited with Biocide. 18:00 00:00 6.00 24.00 W.O. M 25 TR99 Continue to troubleshoot ST-100, communication issue. Checking with IT and programs. SIMOPS: Continue to Clean and organize rig. Continue filling annulus top off annulus with 1-1.5 BPH 8.6 PPG NaCl/ 3% KCL brine inhibited with Biocide. Note: 24 Hour Loss of 8.6 ppg Brine = 0 BBLs Total Loss of 8.6 ppg Brine = 4,821 BBLs Daily Contacts Position Contact Name Company Title Email Office Mobile Company Representative Bruce Simonson ASRC Energy Services Drilling Supv. siddrilling@eni.com 907-685-0715 Company Representative Mike Grubb ASRC Energy Services Drilling Supv. siddrilling@eni.com 907-685-0715 Company Representative Yelyzaveta Saprykina ASRC Energy Services Rig Clerk AKRigClerksDoyon15@eni.com 907-685-0722 Safety Representative Mark Hubler ASRC Energy Services HSE mark.hubler@external.eni.com 907-685-0721 Tool Push Grant Neuharth Doyon Drilling Tool Pusher rig15@doyondrilling.com 907-685-0727 Safety Representative Derek Ambrose Doyon Drilling HSE rig15@doyondrilling.com 907-685-0796 Last Casing Seat Cas. Type OD (in) ID (in) Grade Top (ftKB) Bottom (ftKB) TVD Bot. (ftKB) Landing Date LINER 5 1/2 4.95 L80 -13,937.1 13,996.9 3,786.6 1/31/2012 Well Name: SP23-N3 OR Wellbore Name: SP23-N3 Well Code: 26152 Job: WORKOVER WCEI Level: LEVEL 3 Daily Report Date: 6/25/2024 Report #: 15 Page: 1 of 1 Well Header Permit/Concession N° ADL-388583 Operator ENI PETROLEUM Subsidiary ENI Petroleum Co. Inc. Initial Lahee Code DEVELOPMENT WELL Rotary Table Elevation (ft) 40.89 Ground Level (ft) First Flange (ft) 4.09 RKB - Base Flange (ft) 36.80 RKB - Tubing Spool (ft) 31.91 Rig Information Rig Name RIG 15 Contractor DOYON Rig Type LAND RIG Rig Num 0723 Daily Information Weather Clear Temperature (°F) 35.8 Wind NE @ 16 MPH Days LTI (days) 1,634.00 Days RI (days) POB 49.0 Daily Summary Operations 24h Forecast Continue pulling out of hole. Lay down BHA #8 Baker VACs tool and mill. Prepare and run Hex plug. POOH setting tool to surface. 24h Summary Finish trouble shooting ST-100. Pick-up and run in hole with BHA #8, Baker VACs tool, polish mill to 4,335’. Wash and ream from 4,335’ to 6,000’. Wash from 6,000’ to 6,005’ to liner top. Circulate bottoms-up. Pull out hole with BHA #8. Operation at 07.00 Pick up BHA #9 with Hex plug and run in hole. Time Log Start Time End Time Dur (hr) Cum Dur (hr)Phase Opr. Act. Plan Oper. Descr. 00:00 06:00 6.00 6.00 W.O. M 25 TR99 PJSM. Work on ST-100, Iron rough neck. Troubleshoot electrical issue. SIMOPS: Pressure wash and cleaning rig. Prepare BHA #8 to picked up. Continue filling annulus top off annulus with 1-1.5 BPH 8.6 PPG NaCl / 3% KCL brine inhibited with Biocide, plus pipe displacement. 06:00 09:00 3.00 9.00 W.O. M 25 TR99 Continue - Work on ST-100, Iron rough neck. Troubleshoot electrical issue. SIMOPS: Pressure wash and cleaning rig. Continue filling annulus top off annulus with 1-1.5 BPH 8.6 PPG NaCl / 3% KCL brine inhibited with Biocide, plus pipe displacement. 09:00 12:00 3.00 12.00 W.O. M 5 P PJSM. Pick-up BHA #8 with Polish mill and VAC tool to 151’ as per Baker rep. 12:00 15:00 3.00 15.00 W.O. M 4 P PJSM. Trip in hole with Baker polish mill and VAC tool from 151’ to 4,335’ Up wt.= 140K, DN wt.=130K. Continue filling annulus top off annulus with 1-1.5 BPH 8.6 PPG NaCl / 3% KCL brine inhibited with Biocide, plus pipe displacement. 15:00 20:30 5.50 20.50 W.O. M 9 P PJSM. Wash and ream from 4,335’ to 6,000’ with pump rate of 4 bpm at 650 psi. Rotating 40 rpm with 2-8K torque, Up wt.= 140K, DN wt.=130K, ROT wt.=122K. With 90% returns at shakers. 20:30 21:00 0.50 21.00 W.O. M 9 P Wash from 6,000’ to 6,005’ with pump rate of 4 bpm at 650 psi. Tag liner top with 20K. Pick-up to 5,995’. 21:00 22:00 1.00 22.00 W.O. M 7 P Circulate bottoms-up 4 bpm at 610 psi. 90% returns at shakers. 22:00 00:00 2.00 24.00 W.O. M 4 P PJSM. Pull out of hole from 5,995’ to 4,000’. Continue filling annulus top off annulus with 1-1.5 BPH 8.6 PPG NaCl / 3% KCL brine inhibited with Biocide, plus pipe displacement. Note: 24 Hour Loss of 8.6 ppg Brine = 101 BBLs Total Loss of 8.6 ppg Brine = 4,922 BBLs Daily Contacts Position Contact Name Company Title Email Office Mobile Company Representative Bruce Simonson ASRC Energy Services Drilling Supv. siddrilling@eni.com 907-685-0715 Company Representative David Smith ASRC Energy Services Drilling Supv. siddrilling@eni.com 907-685-0715 Company Representative Yelyzaveta Saprykina ASRC Energy Services Rig Clerk AKRigClerksDoyon15@eni.com 907-685-0722 Safety Representative Mark Hubler ASRC Energy Services HSE mark.hubler@external.eni.com 907-685-0721 Tool Push Grant Neuharth Doyon Drilling Tool Pusher rig15@doyondrilling.com 907-685-0727 Safety Representative Derek Ambrose Doyon Drilling HSE rig15@doyondrilling.com 907-685-0796 Last Casing Seat Cas. Type OD (in) ID (in) Grade Top (ftKB) Bottom (ftKB) TVD Bot. (ftKB) Landing Date LINER 5 1/2 4.95 L80 -13,937.1 13,996.9 3,786.6 1/31/2012 Well Name: SP23-N3 OR Wellbore Name: SP23-N3 Well Code: 26152 Job: WORKOVER WCEI Level: LEVEL 3 Daily Report Date: 6/26/2024 Report #: 16 Page: 1 of 1 Well Header Permit/Concession N° ADL-388583 Operator ENI PETROLEUM Subsidiary ENI Petroleum Co. Inc. Initial Lahee Code DEVELOPMENT WELL Rotary Table Elevation (ft) 40.89 Ground Level (ft) First Flange (ft) 4.09 RKB - Base Flange (ft) 36.80 RKB - Tubing Spool (ft) 31.91 Rig Information Rig Name RIG 15 Contractor DOYON Rig Type LAND RIG Rig Num 0723 Daily Information Weather Clear Temperature (°F) 39.4 Wind E @ 20 MPH Days LTI (days) 1,635.00 Days RI (days) POB 49.0 Daily Summary Operations 24h Forecast Pick-up BHA #10 clean-out assembly and run in hole and start circulating down at 4,500’ to 6,000, circulate bottoms-up to clean out well bore. Pull out of hole and lay down BHA #10. Perform BOP test. 24h Summary Continue pulling out of hole. Lay down BHA #8 Baker VACs too and mill. Prepare and run Hex plug BHA #9. Run in hole as per Interwell rep breaking circulation every 1,500’ to 5,062’, attempt to circulate, plugged. Pull out to 4,602’ attempt to circulate, no success. Pull out to 3,660’ attempt to circulate, no success. Continue pulling out and lay down BHA #9. Operation at 07.00 Circulate down hole at 4650'. Time Log Start Time End Time Dur (hr) Cum Dur (hr)Phase Opr. Act. Plan Oper. Descr. 00:00 02:30 2.50 2.50 W.O. M 4 P PJSM – Pull out of hole from 4,000’ to 151’. Continue filling annulus with 1-1.5 BPH 8.6 PPG NaCl / 3% KCL brine inhibited with Biocide, plus pipe displacement. 02:30 07:00 4.50 7.00 W.O. M 5 P PJSM – Lay down BHA #8 break down components (recovered 3 lbs. of fine metal shavings) and clean VAC tool (recovered and 1.5 to 2 bbls. thick sand slurry). Flush Baker VAC tool and clean rig floor. Top off annulus every hour with 1-1.5 BPH 8.6 PPG NaCl / 3% KCL brine inhibited with Biocide, plus pipe displacement. 07:00 09:30 2.50 9.50 W.O. M 5 P PJSM – Pick-up BHA #9 HEX plug, make-up hydraulic setting tool, total 29’ length as per Interwell rep. Top off annulus every hour with 1-1.5 BPH 8.6 PPG NaCl / 3% KCL brine inhibited with Biocide. 09:30 15:00 5.50 15.00 W.O. M 4 TW99 PJSM – Trip in hole with Interwell HEX plug from 29’ to 5,067’. Attempt to break circulation, plugged. Max running speed (115’/min). Break circulation every 1,500’ with 2 bpm at 400 psi. Top off annulus every hour with 1-1.5 BPH 8.6 PPG NaCl / 3% KCL brine inhibited with Biocide. 15:00 17:00 2.00 17.00 W.O. M 4 U PJSM – Pull out of hole from 5,067’ to 4,602’ attempt to pump, pipe plugged. 17:00 17:30 0.50 17.50 W.O. M 25 P Service rig, draw-work and top drive., change oil filter on ST-100 roughneck. 17:30 18:30 1.00 18.50 W.O. M 4 U PJSM - Pull out of hole from 4,602’ to 3,660’, attempt to break circulation without success, plugged pipe. UP wt.= 130K 18:30 21:30 3.00 21.50 W.O. M 4 U Pull out of hole from 3,660’ to 29’. Continue filling annulus with 1-1.5 BPH 8.6 PPG NaCl / 3% KCL brine inhibited with Biocide, plus pipe displacement. 21:30 23:00 1.50 23.00 W.O. M 5 U PJSM – Lay Down BHA #9, last drill pipe joint full of sand, clean Hydraulic setting tool, expanding adapter and HEX plug as per Interwell rep. 23:00 00:00 1.00 24.00 W.O. M 1 P Clear floor of Interwell tools and clean floor. Note: 24 Hour Loss of 8.6 ppg Brine = 166 BBLs Total Loss of 8.6 ppg Brine = 5,088 BBLs Daily Contacts Position Contact Name Company Title Email Office Mobile Company Representative Bruce Simonson ASRC Energy Services Drilling Supv. siddrilling@eni.com 907-685-0715 Company Representative David Smith ASRC Energy Services Drilling Supv. siddrilling@eni.com 907-685-0715 Company Representative Yelyzaveta Saprykina ASRC Energy Services Rig Clerk AKRigClerksDoyon15@eni.com 907-685-0722 Safety Representative Mark Hubler ASRC Energy Services HSE mark.hubler@external.eni.com 907-685-0721 Tool Push Grant Neuharth Doyon Drilling Tool Pusher rig15@doyondrilling.com 907-685-0727 Safety Representative Derek Ambrose Doyon Drilling HSE rig15@doyondrilling.com 907-685-0796 Last Casing Seat Cas. Type OD (in) ID (in) Grade Top (ftKB) Bottom (ftKB) TVD Bot. (ftKB) Landing Date LINER 5 1/2 4.95 L80 -13,937.1 13,996.9 3,786.6 1/31/2012 Well Name: SP23-N3 OR Wellbore Name: SP23-N3 Well Code: 26152 Job: WORKOVER WCEI Level: LEVEL 3 Daily Report Date: 6/27/2024 Report #: 17 Page: 1 of 1 Well Header Permit/Concession N° ADL-388583 Operator ENI PETROLEUM Subsidiary ENI Petroleum Co. Inc. Initial Lahee Code DEVELOPMENT WELL Rotary Table Elevation (ft) 40.89 Ground Level (ft) First Flange (ft) 4.09 RKB - Base Flange (ft) 36.80 RKB - Tubing Spool (ft) 31.91 Rig Information Rig Name RIG 15 Contractor DOYON Rig Type LAND RIG Rig Num 0723 Daily Information Weather Clear Temperature (°F) 42.1 Wind NE @ 22 MPH Days LTI (days) 1,636.00 Days RI (days) POB 45.0 Daily Summary Operations 24h Forecast Continue testing BOP. Prep to run Interwell Hex plug assembly as per plan forward. 24h Summary Pick-up BHA #10 clean-out assembly and run in hole and start circulating down at 4,511’ to 6,000’, circulate bottoms-up to clean out well bore. Pull out of hole and lay down BHA #10. Perform BOP test. Operation at 07.00 Rig down test equipment. Time Log Start Time End Time Dur (hr) Cum Dur (hr)Phase Opr. Act. Plan Oper. Descr. 00:00 02:30 2.50 2.50 W.O. M 1 P PJSM – Prep and pick-up BHA #10 clean out assembly. Continue filling annulus with 1.5-2 BPH 8.6 PPG NaCl / 3% KCL brine inhibited with Biocide. 02:30 05:30 3.00 5.50 W.O. M 4 P PJSM – Run in hole with BHA #10 from 37’ to 3,951’ Break circulation at 2,000’ with 9 BPM at 305 psi. UP wt.=138K / DN wt.=131K. Continue filling annulus with 1.5-2 BPH 8.6 PPG NaCl / 3% KCL brine inhibited with Biocide. 05:30 06:00 0.50 6.00 W.O. M 25 P Service rig – Draw works, top drive, ST-100 rough neck. Continue filling annulus with 1.5-2 BPH 8.6 PPG NaCl / 3% KCL brine inhibited with Biocide. 06:00 07:00 1.00 7.00 W.O. M 4 P PJSM – Continue trip in hole form 3,951’ to 4,511’. Continue filling annulus with 1.5-2 BPH 8.6 PPG NaCl / 3% KCL brine inhibited with Biocide. 07:00 11:30 4.50 11.50 W.O. M 6 P PJSM – Wash and ream from 4,511’ to 6,000’ with increasing pump rate 9-12 bpm at 300-550 psi. Monitoring lose rate maintaining 2 BPH, rotating 40-60 rpm with 3-7K torque. UP wt.=138K / DN wt.=131K / ROT wt.=131K. Back ream stands as needed to clean up higher torque section. 11:30 14:30 3.00 14.50 W.O. M 7 P Circulate hole clean with increasing rate 9-11 bpm at 350-500 psi. Rotating 55 rpm with 6-8K torque. Reciprocate pipe from 5,995’ to 5,910’ while circulating. Monitoring return for lose rate. Estimated 100 bbls plus of sand recovered. UP wt.=140K / DN wt.=135K / ROT wt.=135K. 14:30 18:00 3.50 18.00 W.O. M 4 P PJSM - Pull out of hole from 6,000’ to 37’, UP wt.= 130K. Continue filling annulus with 1.5-2 BPH 8.6 PPG NaCl / 3% KCL brine inhibited with Biocide, plus pipe displacement. 18:00 19:30 1.50 19.50 W.O. M 20 P PJSM – Lay down BHA #10 as per Baker rep. Clear rig floor of components and clean. Continue filling annulus with 1.5-2 BPH 8.6 PPG NaCl / 3% KCL brine inhibited with Biocide. 19:30 22:30 3.00 22.50 W.O. C 20 P PJSM – Pick-up stack washing tool and flush BOP equipment. Pull wear bushing and install test plug as per Vault rep. Rig-up test equipment, fluid pack stack, choke manifold and top drive. 22:30 00:00 1.50 24.00 W.O. C 12 P Perform shell test 250 psi and 3000 psi for 5 minutes each. Perform BOP test: Sequence #1 annular, choke valves #1,12,13,14,15, primary and secondary Demco kill valves and upper top drive IBOP vale to 250 psi. low / 300 psi. high for 5 minutes each. Note: 24 Hour Loss of 8.6 ppg Brine = 142 BBLs Total Loss of 8.6 ppg Brine = 5,230 BBLs Daily Contacts Position Contact Name Company Title Email Office Mobile Company Representative Bruce Simonson ASRC Energy Services Drilling Supv. siddrilling@eni.com 907-685-0715 Company Representative David Smith ASRC Energy Services Drilling Supv. siddrilling@eni.com 907-685-0715 Company Representative Yelyzaveta Saprykina ASRC Energy Services Rig Clerk AKRigClerksDoyon15@eni.com 907-685-0722 Safety Representative Mark Hubler ASRC Energy Services HSE mark.hubler@external.eni.com 907-685-0721 Tool Push Grant Neuharth Doyon Drilling Tool Pusher rig15@doyondrilling.com 907-685-0727 Safety Representative Derek Ambrose Doyon Drilling HSE rig15@doyondrilling.com 907-685-0796 Last Casing Seat Cas. Type OD (in) ID (in) Grade Top (ftKB) Bottom (ftKB) TVD Bot. (ftKB) Landing Date LINER 5 1/2 4.95 L80 -13,937.1 13,996.9 3,786.6 1/31/2012 Well Name: SP23-N3 OR Wellbore Name: SP23-N3 Well Code: 26152 Job: WORKOVER WCEI Level: LEVEL 3 Daily Report Date: 6/28/2024 Report #: 18 Page: 1 of 1 Well Header Permit/Concession N° ADL-388583 Operator ENI PETROLEUM Subsidiary ENI Petroleum Co. Inc. Initial Lahee Code DEVELOPMENT WELL Rotary Table Elevation (ft) 40.89 Ground Level (ft) First Flange (ft) 4.09 RKB - Base Flange (ft) 36.80 RKB - Tubing Spool (ft) 31.91 Rig Information Rig Name RIG 15 Contractor DOYON Rig Type LAND RIG Rig Num 0723 Daily Information Weather Clear Temperature (°F) 48.0 Wind W @ 9 MPH Days LTI (days) 1,637.00 Days RI (days) POB 48.0 Daily Summary Operations 24h Forecast Pull out if hole from and lay down BHA #11 as per Interwell rep. Pick-up 9-5/8” Baker clean-out BHA #12, trip in hole to 4,733’ circulate three bottoms-up or until clean. Pull out of hole and lay down BHA #12. Rig-up Halliburton to run Saltel patch. 24h Summary Complete BOP test. Pick-up and run Interwell Hex plug assembly and set at 4,745’ center of element, pull out hole to 1,700’. Operation at 07.00 Run in hole with clean-out BHA #12 at 3,788'. Time Log Start Time End Time Dur (hr) Cum Dur (hr)Phase Opr. Act. Plan Oper. Descr. 00:00 05:30 5.50 5.50 W.O. C 12 P PJSM – Testing BOPE - Sequence #2 thru #8 on 2-7/8” x 5” variable upper and lower rams with a 5” test joint to 250 psi low, 3000 psi high for 5 minutes each. Test Choke manifold valves #2, 5, 6, 7, 8, 9, 10 and 11. Test top drive lower IBOP. Primary and secondary HCR kill/choke valves and primary and secondary manual choke valves. Test floor valve and dart valve. Test choke manifold valves #3 and #4 with blind ram test. Function test hydraulic and manual choke with 2000 psi; observed bleed off. Test annular, upper and lower (2-7/8” X 5”) variable rams with 2-7/8” test joint to 250 psi low, 3000 psi high for 5 minutes each. Test gas alarms. Test PVT and flow alarms. Perform accumulator draw down test. Starting pressure = 2950 psi, after function = 2150 psi, 200 psi increase = 11 seconds, full recovery = 41 seconds, nitrogen back up 10 bottles with 4000 psi average. All tests good. Witness waived by AOGCC rep Austin McLeod. Continue filling annulus at 1.5-2 BPH of 8.6 PPG NaCl/ 3% KCL brine inhibited with Biocide. 05:30 06:30 1.00 6.50 W.O. C 1 P PJSM – Rig down test equipment. Pull test plug. Blow down choke manifold, top drive, and all surface equipment. Clean and clear floor. 06:30 07:30 1.00 7.50 W.O. C 5 P PJSM – Drain/suck out BOP stack and set wear ring as per Vault rep. 07:30 11:00 3.50 11.00 W.O. M 20 P PJSM – Prepare rig floor for BHA #11. Clean and organize around rig. Service pipe skate, draw-works, ST-100 roughneck, top drive, blocks, and crown. 11:00 13:00 2.00 13.00 W.O. M 5 P PJSM – Pick-up BHA #11 HEX plug, make-up hydraulic setting tool, total 29’ length as per Interwell rep. Continue filling annulus at 1.5-2 BPH of 8.6 PPG NaCl/ 3% KCL brine inhibited with Biocide. 13:00 16:30 3.50 16.50 W.O. M 4 P PJSM – Trip in hole with Interwell HEX plug from 29’ to 3,000’. Max running speed (115 ft./min.). Verified by Interwell rep. Break circulation every 1,500’ with 0.5 bpm at 200 psi. 16:30 21:30 5.00 21.50 W.O. M 4 P PJSM – Trip in hole with HEX plug from 3,000’ to 4,690’. Max running speed (115 ft./min.). Break circulation very 30’ with 0.4 bpm at 300 psi. Verified by Interwell rep. Continue filling annulus at 1.5-2 BPH of 8.6 PPG NaCl/ 3% KCL brine inhibited with Biocide. 21:30 22:00 0.50 22.00 W.O. M 19 P Circulating down from 4,690’ to 4,755’ with 0.6 BPM at 83 psi and verified return. Pick-up to 4,750’ putting HEX plug center element at 4,745’. Drop I” ball, pumping it down with 1.2 BPM at 200 psi. Monitor increasing pressure to 1800 psi activating tool and observed sudden pressure drop to set HEX plug with center of element at 4,745’. Tag with 3K weight to confirm HEX plug set. Top of HEX plug at 4,738’ DPM. 22:00 00:00 2.00 24.00 W.O. M 4 P PJSM – Pull out hole from 4,740’ to 1,700’ and lay down setting tool as per Interwell rep. Continue filling annulus with 1.5-2 BPH 8.6 PPG NaCl / 3% KCL brine inhibited with Biocide, plus pipe displacement. Note: 24 Hour Loss of 8.6 ppg Brine = 0 BBLs Total Loss of 8.6 ppg Brine = 5,230 BBLs Daily Contacts Position Contact Name Company Title Email Office Mobile Company Representative Bruce Simonson ASRC Energy Services Drilling Supv. siddrilling@eni.com 907-685-0715 Company Representative David Smith ASRC Energy Services Drilling Supv. siddrilling@eni.com 907-685-0715 Company Representative Yelyzaveta Saprykina ASRC Energy Services Rig Clerk AKRigClerksDoyon15@eni.com 907-685-0722 Safety Representative Mark Hubler ASRC Energy Services HSE mark.hubler@external.eni.com 907-685-0721 Tool Push Grant Neuharth Doyon Drilling Tool Pusher rig15@doyondrilling.com 907-685-0727 Safety Representative Derek Ambrose Doyon Drilling HSE rig15@doyondrilling.com 907-685-0796 Drilling Engineer Alex Vaughan ASRC Energy Services Drilling Engineer Alex.Vaughan@external.eni.com 907-685-0715 Last Casing Seat Cas. Type OD (in) ID (in) Grade Top (ftKB) Bottom (ftKB) TVD Bot. (ftKB) Landing Date LINER 5 1/2 4.95 L80 -13,937.1 13,996.9 3,786.6 1/31/2012 Well Name: SP23-N3 OR Wellbore Name: SP23-N3 Well Code: 26152 Job: WORKOVER WCEI Level: LEVEL 3 Daily Report Date: 6/29/2024 Report #: 19 Page: 1 of 1 Well Header Permit/Concession N° ADL-388583 Operator ENI PETROLEUM Subsidiary ENI Petroleum Co. Inc. Initial Lahee Code DEVELOPMENT WELL Rotary Table Elevation (ft) 40.89 Ground Level (ft) First Flange (ft) 4.09 RKB - Base Flange (ft) 36.80 RKB - Tubing Spool (ft) 31.91 Rig Information Rig Name RIG 15 Contractor DOYON Rig Type LAND RIG Rig Num 0723 Daily Information Weather Overcast Temperature (°F) 36.0 Wind W @ 9 MPH Days LTI (days) 1,638.00 Days RI (days) POB 59.0 Daily Summary Operations 24h Forecast Complete Halliburton rig up and perform a Gamma ray and CCL correlation log. Rig down Halliburton equipment. Rig up Schlumberger to run Saltel casing patch. 24h Summary Pull out if hole from 1,700’ to 18’at setting assembly and lay down as per Interwell rep. Pick-up 9-5/8” Baker clean-out BHA #12 with 8.5” stringmill drift, trip in hole to 4,730’ circulate until clean. Pull out of hole and lay down BHA #12. Rig-up Halliburton E-line to run Gamma ray/CCL logs. Operation at 07.00 Perform a Gamma ray and CCL correlation log. Time Log Start Time End Time Dur (hr) Cum Dur (hr)Phase Opr. Act. Plan Oper. Descr. 00:00 01:30 1.50 1.50 W.O. M 4 P PJSM – Continue pull out hole from 1,700’ to 18’ with BHA #11. Continue filling annulus with 1.5-2 BPH 8.6 PPG NaCl / 3% KCL brine inhibited with Biocide, plus pipe displacement. 01:30 02:00 0.50 2.00 W.O. M 5 P PJSM – Lay down BHA # 11 setting tool as per Interwell rep. Continue filling annulus at 1.5-2 BPH of 8.6 PPG NaCl/ 3% KCL brine inhibited with Biocide. 02:00 03:00 1.00 3.00 W.O. M 20 P PJSM – Pick-up 9-5/8” clean-out assembly BHA #12 with 8.5” stringmill drift, as per Baker rep to 58’. 03:00 04:30 1.50 4.50 W.O. M 4 P PJSM – Trip in hole from 58’ to 1,000’. Up wt.=100K / DN wt. =90K. Monitor hole fill on trip tank. 04:30 05:00 0.50 5.00 W.O. M 25 P PJSM – Service ST-2100 roughneck and Draw-works. Continue filling annulus at 1.5-2 BPH of 8.6 PPG NaCl/ 3% KCL brine inhibited with Biocide. 05:00 07:00 2.00 7.00 W.O. M 4 P PJSM – Trip in hole with BHA # 12 from 1,000’ to 4,065’. Break circulation every 1,500’. Continue filling annulus at 1.5-2 BPH of 8.6 PPG NaCl/ 3% KCL brine inhibited with Biocide. Up wt.=100K / DN wt. =90K. 07:00 08:30 1.50 8.50 W.O. M 9 P PJSM – Wash from 4,065’ to 4,718’, pump rate of 8 bpm at 80-120 psi. Pick-up working single and continue washing to 4,730’. Monitor returns for losses and continue filling annulus at 1.5-2 BPH of 8.6 PPG NaCl/ 3% KCL brine inhibited with Biocide. 08:30 12:00 3.50 12.00 W.O. M 7 P PJSM - Circulating from bottoms-up and clean. Reciprocating string from 4,728’ to 4,655’ pumping 12 BPM at 310 psi with 40 rpm at 3-5K torque. Up wt.=140K / DN wt. =123K / ROT wt.=135K. 12:00 14:00 2.00 14.00 W.O. M 4 P PJSM – Attempt to pull out hole lay working single from 4,730’ to 4,718’. Continue pulling and observed 8-10K drag from 4,655’ to 4,640’ work pipe. Rack back stand to 4,625’. Up wt.=155K / DN wt. =123K / ROT wt.=135K. Continue filling annulus at 1.5-2 BPH of 8.6 PPG NaCl/ 3% KCL brine inhibited with Biocide. Up wt.=100K / DN wt. =90K. 14:00 15:30 1.50 15.50 W.O. M 7 P Circulate bottom-up until clean, reciprocating pipe from 4,625’ to 4,532’ pump rate of 12 BPM at 320 psi. Up wt.=140K / DN wt. =123K / ROT wt.=135K. Estimated 82 bbls. of sand recovered. 15:30 18:00 2.50 18.00 W.O. M 4 P Pull out of hole from 4,532’ to 58’, continue filling annulus at 1.5-2 BPH of 8.6 PPG NaCl/ 3% KCL brine inhibited with Biocide, plus pipe displacement. 18:00 20:30 2.50 20.50 W.O. M 20 P PJSM - Lay down Baker 9-5/8” clean out BHA # 12 down beaver slide and pipe shed. Prep for Halliburton E-line operation. 20:30 00:00 3.50 24.00 W.O. R 1 P PJSM – Rig-up Halliburton E-line sheaves on top drive and pick-up tool string to rig floor, test Gamma tool fail and replace with back up. Note: 24 Hour Loss of 8.6 ppg Brine = 181 BBLs Total Loss of 8.6 ppg Brine = 5,411 BBLs Daily Contacts Position Contact Name Company Title Email Office Mobile Company Representative Bruce Simonson ASRC Energy Services Drilling Supv. siddrilling@eni.com 907-685-0715 Company Representative David Smith ASRC Energy Services Drilling Supv. siddrilling@eni.com 907-685-0715 Company Representative Yelyzaveta Saprykina ASRC Energy Services Rig Clerk AKRigClerksDoyon15@eni.com 907-685-0722 Safety Representative Mark Hubler ASRC Energy Services HSE mark.hubler@external.eni.com 907-685-0721 Tool Push Grant Neuharth Doyon Drilling Tool Pusher rig15@doyondrilling.com 907-685-0727 Safety Representative Derek Ambrose Doyon Drilling HSE rig15@doyondrilling.com 907-685-0796 Drilling Engineer Alex Vaughan ASRC Energy Services Drilling Engineer Alex.Vaughan@external.eni.com 907-685-0715 Last Casing Seat Cas. Type OD (in) ID (in) Grade Top (ftKB) Bottom (ftKB) TVD Bot. (ftKB) Landing Date LINER 5 1/2 4.95 L80 -13,937.1 13,996.9 3,786.6 1/31/2012 Well Name: SP23-N3 OR Wellbore Name: SP23-N3 Well Code: 26152 Job: WORKOVER WCEI Level: LEVEL 3 Daily Report Date: 6/30/2024 Report #: 20 Page: 1 of 1 Well Header Permit/Concession N° ADL-388583 Operator ENI PETROLEUM Subsidiary ENI Petroleum Co. Inc. Initial Lahee Code DEVELOPMENT WELL Rotary Table Elevation (ft) 40.89 Ground Level (ft) First Flange (ft) 4.09 RKB - Base Flange (ft) 36.80 RKB - Tubing Spool (ft) 31.91 Rig Information Rig Name RIG 15 Contractor DOYON Rig Type LAND RIG Rig Num 0723 Daily Information Weather Overcast Temperature (°F) 39.2 Wind NE @ 3 MPH Days LTI (days) 1,639.00 Days RI (days) POB 58.0 Daily Summary Operations 24h Forecast Set Schlumberger Saltle casing patch, perform pressure sequences to expand and set patch. Pull out hole and lay down Schlumberger setting tool assembly. Pressure test 9-5/8” casing. 24h Summary Complete Halliburton rig up and perform a Gamma and CCL correlation log. Rig down Halliburton equipment. Pick-up Schlumberger casing patch and pressure test. Run in hole with Schlumberger Saltel casing patch. Operation at 07.00 Setting Schlumberger Saltle casing patch. Time Log Start Time End Time Dur (hr) Cum Dur (hr)Phase Opr. Act. Plan Oper. Descr. 00:00 04:00 4.00 4.00 W.O. R 1 P PJSM – Complete Halliburton rig up. Pick-up tool string with Gamma/CCL. Load Saltel casing patch in pipe shed. Continue filling annulus with 1.5-2 BPH 8.6 PPG NaCl / 3% KCL brine inhibited with Biocide. 04:00 09:00 5.00 9.00 W.O. J 4 P PJSM – Run in hole with Halliburton to perform correlation log for casing patch. Log from 4,745’ to surface. Continue filling annulus at 1.5-2 BPH of 8.6 PPG NaCl/ 3% KCL brine inhibited with Biocide. 09:00 10:30 1.50 10.50 W.O. R 1 P PJSM – Rig down Halliburton wire line. Continue filling annulus at 1.5-2 BPH of 8.6 PPG NaCl/ 3% KCL brine inhibited with Biocide. 10:30 15:30 5.00 15.50 W.O. M 20 P PJSM – Pick-up Schlumberger casing patch and tool assembly with drill pipe working single. Rig-up and flush line and test equipment. Monitor annulus every hour with 1.5-2 BPH 8.6 PPG NaCl / 3% KCL brine inhibited with Biocide. 15:30 16:30 1.00 16.50 W.O. M 12 P PJSM – Surface test crossover and Schlumberger tools to 500 psi/3000 psi. Continue filling annulus with 1.5-2 BPH 8.6 PPG NaCl / 3% KCL brine inhibited with Biocide. 16:30 19:00 2.50 19.00 W.O. M 4 P PJSM – Trip in hole with BHA #13 Schlumberger Saltel casing patch from 37’ to 2,119’. DW =101K. Continue filling annulus with 1.5-2 BPH 8.6 PPG NaCl / 3% KCL brine inhibited with Biocide. 19:00 20:00 1.00 20.00 W.O. M 12 P PJSM – Perform intermediated tool test at 2,119’ to 500 psi/3000 psi. Continue filling annulus with 1.5-2 BPH 8.6 PPG NaCl / 3% KCL brine inhibited with Biocide. 20:00 00:00 4.00 24.00 W.O. M 4 P PJSM – Continue trip in hole with BHA #13 from 2,119’ to 4,635’. Continue filling annulus with 1.5-2 BPH 8.6 PPG NaCl / 3% KCL brine inhibited with Biocide. DW =128K. Note: 24 Hour Loss of 8.6 ppg Brine = 0 BBLs Total Loss of 8.6 ppg Brine = 5,411 BBLs Daily Contacts Position Contact Name Company Title Email Office Mobile Company Representative Bruce Simonson ASRC Energy Services Drilling Supv. siddrilling@eni.com 907-685-0715 Company Representative David Smith ASRC Energy Services Drilling Supv. siddrilling@eni.com 907-685-0715 Company Representative Yelyzaveta Saprykina ASRC Energy Services Rig Clerk AKRigClerksDoyon15@eni.com 907-685-0722 Safety Representative Mark Hubler ASRC Energy Services HSE mark.hubler@external.eni.com 907-685-0721 Tool Push Grant Neuharth Doyon Drilling Tool Pusher rig15@doyondrilling.com 907-685-0727 Safety Representative Derek Ambrose Doyon Drilling HSE rig15@doyondrilling.com 907-685-0796 Drilling Engineer Alex Vaughan ASRC Energy Services Drilling Engineer Alex.Vaughan@external.eni.com 907-685-0715 Last Casing Seat Cas. Type OD (in) ID (in) Grade Top (ftKB) Bottom (ftKB) TVD Bot. (ftKB) Landing Date LINER 5 1/2 4.95 L80 -13,937.1 13,996.9 3,786.6 1/31/2012 Well Name: SP23-N3 OR Wellbore Name: SP23-N3 Well Code: 26152 Job: WORKOVER WCEI Level: LEVEL 3 Daily Report Date: 7/1/2024 Report #: 21 Page: 1 of 1 Well Header Permit/Concession N° ADL-388583 Operator ENI PETROLEUM Subsidiary ENI Petroleum Co. Inc. Initial Lahee Code DEVELOPMENT WELL Rotary Table Elevation (ft) 40.89 Ground Level (ft) First Flange (ft) 4.09 RKB - Base Flange (ft) 36.80 RKB - Tubing Spool (ft) 31.91 Rig Information Rig Name RIG 15 Contractor DOYON Rig Type LAND RIG Rig Num 0723 Daily Information Weather Most Cloudy Temperature (°F) 40.0 Wind E @ 17 MPH Days LTI (days) 1,640.00 Days RI (days) POB 48.0 Daily Summary Operations 24h Forecast Pull out hole with Interwell HEX plug. Run Baker inflatable packer to liner top to test lower section of 9-5/8” casing to 1500 psi. Pull out of hole and lay down BHA # 15. 24h Summary Run in hole and set Schlumberger Saltle casing patch. Test casing to 1500 psi. Pull out hole and lay down Schlumberger setting assembly. Release Interwell HEX plug. Operation at 07.00 Run in hole with inflatable packer. Time Log Start Time End Time Dur (hr) Cum Dur (hr)Phase Opr. Act. Plan Oper. Descr. 00:00 02:00 2.00 2.00 W.O. M 4 P PJSM – Continue trip in hole with BHA #13 Schlumberger from 4,635’ to 4,739’. Tag HEX packer with 4K. Top filling every 3 stands with clean 8.6 ppg brine. Pull out of hole 107’ to 4,632’ DPM. Calculate transition measurement. UP wt.= 138K / DN wt. =128K. 02:00 09:30 7.50 9.50 W.O. M 19 P PJSM – Schlumberger set casing patch, with 16 pressure steps with max of 4850 psi and drift casing to 7.7” to verity fully set. Pull out of hole to 4,605’. Top of casing patch at 4,614.6' and bottom at 4,640.6'. 09:30 11:30 2.00 11.50 W.O. M 12 P PJSM – Test 9-5/8” casing in 200 psi, increments to 1500 psi hold for 30 minutes charted recorded. Pumped 2.1 bbls to reach 1500 psi, recovered 1.4 bbls. Good test. 11:30 16:00 4.50 16.00 W.O. M 4 P PJSM – Rig down test equipment and pick-up single from pipe shed. Pull out of hole from 4,605’ to 38’. Up wt.= 137K. 16:00 18:00 2.00 18.00 W.O. M 20 P PJSM – Lay own working single and BHA #13 Schlumberger casing set tool, break down in pipe shed, load in boxes. Clear and clean rig floor. 18:00 19:30 1.50 19.50 W.O. M 12 P PJSM –Pick-up BHA #14 Interwell G/S flow thru retrieving tool. Test at surface at 1 bpm at 360 psi. Good test. Continue filling annulus with 1.5-2 BPH 8.6 PPG NaCl / 3% KCL brine inhibited with Biocide. 19:30 23:00 3.50 23.00 W.O. M 4 P PJSM – Trip in hole with BHA #14 Interwell G/S retrieving tool from surface to 4,707’ DPM. Up wt.= 139K / DN wt.= 129K. Continue filling annulus with 1.5-2 BPH 8.6 PPG NaCl / 3% KCL brine inhibited with Biocide. 23:00 00:00 1.00 24.00 W.O. M 19 P Wash down to HEX plug from 4,668’ to 4,738’ pumping 1 bpm at 230 psi. Tag with 5K at 4,738’ and shut down pump for G/S tool to hatch fish neck of HEX plug. Pull 9-10K over to release and wait 30 minutes for the elements to relax. Pick-up to 4,664’ and slack off to 4,745’ to confirm released. Monitor annulus on trip tank with 8.6 PPG NaCl / 3% KCL brine inhibited with Biocide. Flow check. Note: 24 Hour Loss of 8.6 ppg Brine = 165 BBLs Total Loss of 8.6 ppg Brine = 5,576 BBLs Daily Contacts Position Contact Name Company Title Email Office Mobile Company Representative Bruce Simonson ASRC Energy Services Drilling Supv. siddrilling@eni.com 907-685-0715 Company Representative David Smith ASRC Energy Services Drilling Supv. siddrilling@eni.com 907-685-0715 Company Representative Yelyzaveta Saprykina ASRC Energy Services Rig Clerk AKRigClerksDoyon15@eni.com 907-685-0722 Safety Representative Mark Hubler ASRC Energy Services HSE mark.hubler@external.eni.com 907-685-0721 Tool Push Grant Neuharth Doyon Drilling Tool Pusher rig15@doyondrilling.com 907-685-0727 Safety Representative Derek Ambrose Doyon Drilling HSE rig15@doyondrilling.com 907-685-0796 Last Casing Seat Cas. Type OD (in) ID (in) Grade Top (ftKB) Bottom (ftKB) TVD Bot. (ftKB) Landing Date LINER 5 1/2 4.95 L80 -13,937.1 13,996.9 3,786.6 1/31/2012 Well Name: SP23-N3 OR Wellbore Name: SP23-N3 Well Code: 26152 Job: WORKOVER WCEI Level: LEVEL 3 Daily Report Date: 7/2/2024 Report #: 22 Page: 1 of 1 Well Header Permit/Concession N° ADL-388583 Operator ENI PETROLEUM Subsidiary ENI Petroleum Co. Inc. Initial Lahee Code DEVELOPMENT WELL Rotary Table Elevation (ft) 40.89 Ground Level (ft) First Flange (ft) 4.09 RKB - Base Flange (ft) 36.80 RKB - Tubing Spool (ft) 31.91 Rig Information Rig Name RIG 15 Contractor DOYON Rig Type LAND RIG Rig Num 0723 Daily Information Weather Mostly Cloudy Temperature (°F) 41.5 Wind E @ 17 MPH Days LTI (days) 1,641.00 Days RI (days) POB 47.0 Daily Summary Operations 24h Forecast Run BHA # 16 2-7/8” tubing stinger on Baker 5-3/4” Vac tool, attempt to wash into liner. 24h Summary Pull out hole with Interwell HEX plug. Run Baker inflatable packer to 5,985’ above liner and test 9-5/8” casing to 1500 psi. Pull out of hole and lay down BHA # 15. Operation at 07.00 Pick up and run BHA # 16 Time Log Start Time End Time Dur (hr) Cum Dur (hr)Phase Opr. Act. Plan Oper. Descr. 00:00 05:00 5.00 5.00 W.O. M 4 P PJSM – Pull out of hole from 4,724 ’to 20’ with BHA #14 Interwell HEX plug and retrieval tool. (Pull speed at 100 ft./min.). UP wt.= 139K / DN wt. =129K. Lay down HEX plug and G/S tool. Monitor annulus with 8.6 PPG 3% KCL / NaCl brine inhibited with Biocide. 05:00 09:00 4.00 9.00 W.O. M 4 P PJSM – Pick-up BHA # 15 Baker inflatable as per rep, trip in hole from 16’ to 4,583’ MD. UP wt.= 138K / DN wt. =129K. Monitor annulus with 8.6 PPG 3% KCL / NaCl brine inhibited with Biocide. 09:00 10:00 1.00 10.00 W.O. M 7 P PJSM – Wash from 4,583’ to 4,770’ MD pumping 1.5 BPM at 38 psi. Observed under balanced, flow back when breaking out pipe. Circulate one bottoms-up pumping at 3.5 BPM at 90 psi. UP wt.= 140K / DN wt. =129K. Monitor annulus with 8.6 PPG 3% KCL / NaCl brine inhibited with Biocide. 10:00 11:30 1.50 11.50 W.O. M 7 P Continue washing from 4,770’ to 4,956’ MD pumping 1.5 BPM at 38 psi. Observed under balanced, flow back when breaking out pipe. Circulate one drill pipe volume pumping at 3.5 BPM at 90-116 psi. UP wt.= 141K / DN wt. =131K. Monitor annulus with 8.6 PPG 3% KCL / NaCl brine inhibited with Biocide. 11:30 14:30 3.00 14.50 W.O. M 7 P Continue washing from 4,956’ to 5,985’ MD putting Baker inflatable on depth, pumping 1.5 BPM at 45 psi. UP wt.= 147K / DN wt. =128K. Monitor annulus with 8.6 PPG 3% KCL / NaCl brine inhibited with Biocide. 14:30 16:00 1.50 16.00 W.O. M 7 P The Baker rep dropped 2” ball and pumped it down 2.8 BPM at 90 psi. Pressure up in increments of 1000 psi. / 1500 psi. hold for 10 minutes each, blow the ball seat at 3100 psi. setting at packer at 5,985’. Perform push/pull test with 6K set down and 18K over. 16:00 18:30 2.50 18.50 W.O. M 7 P PJSM – Rig-up test equipment and test 9-5/8” casing in 200 psi. increments holding 5 minutes each to 1500 psi. hold for 30 minutes charted recorded, monitor A annulus. (Pumped 2.1 bbls. to reach 1500 psi. and recovered 2 bbls.). (Good Test). Rig- down test equipment. 18:30 19:00 0.50 19.00 W.O. M 7 P PJSM - Baker released inflatable packer and waited 15 minutes to relax. Monitor well, fill hole with 60 bbls. of 8.6 ppg 3% KCL / NaCl brine inhibited with Biocide, well resumed taking fluid. 19:00 00:00 5.00 24.00 W.O. M 7 P PJSM - Pull out of hole from 5,985’ to 16’ with Baker inflatable packer. Lay Down Baker packer, clear and clean rig floor on components. Monitor annulus and adding 10 BPH of 8.6 PPG NaCl / 3% KCL brine inhibited with Biocide, plus pipe displacement. Daily losses to the well 0 bbls. Total losses to the well 5576 bbls. Daily Contacts Position Contact Name Company Title Email Office Mobile Company Representative Bruce Simonson ASRC Energy Services Drilling Supv. siddrilling@eni.com 907-685-0715 Company Representative David Smith ASRC Energy Services Drilling Supv. siddrilling@eni.com 907-685-0715 Company Representative Yelyzaveta Saprykina ASRC Energy Services Rig Clerk AKRigClerksDoyon15@eni.com 907-685-0722 Safety Representative Mark Hubler ASRC Energy Services HSE mark.hubler@external.eni.com 907-685-0721 Tool Push Grant Neuharth Doyon Drilling Tool Pusher rig15@doyondrilling.com 907-685-0727 Safety Representative Derek Ambrose Doyon Drilling HSE rig15@doyondrilling.com 907-685-0796 Company Representative Craig Smith ASRC Energy Services Drilling Supv. siddrilling@eni.com 907-685-0722 Last Casing Seat Cas. Type OD (in) ID (in) Grade Top (ftKB) Bottom (ftKB) TVD Bot. (ftKB) Landing Date LINER 5 1/2 4.95 L80 -13,937.1 13,996.9 3,786.6 1/31/2012 Well Name: SP23-N3 OR Wellbore Name: SP23-N3 Well Code: 26152 Job: WORKOVER WCEI Level: LEVEL 3 Daily Report Date: 7/3/2024 Report #: 23 Page: 1 of 1 Well Header Permit/Concession N° ADL-388583 Operator ENI PETROLEUM Subsidiary ENI Petroleum Co. Inc. Initial Lahee Code DEVELOPMENT WELL Rotary Table Elevation (ft) 40.89 Ground Level (ft) First Flange (ft) 4.09 RKB - Base Flange (ft) 36.80 RKB - Tubing Spool (ft) 31.91 Rig Information Rig Name RIG 15 Contractor DOYON Rig Type LAND RIG Rig Num 0723 Daily Information Weather Overcast Temperature (°F) 42.0 Wind W @ 20 MPH Days LTI (days) 1,642.00 Days RI (days) POB 46.0 Daily Summary Operations 24h Forecast Wash down L1 with 3,000’ 2-7/8” snorkel pipe.Pull out hole. Test BOPE. Prep to run completion. 24h Summary Run 2-7/8” snorkel pipe on Baker VAC tool, wash to 6,231’ Pull out of hole with 5-3/4” VAC tool, total recovered 1/2 bbl. sand slurry. Pick-up BHA #17 run in the hole vac tool w/ 3,000' snorkel pipe to clean out liner. Note: Send AOGCC notification of BOP test Operation at 07.00 Picking up and running 2-7/8" PH-6 Time Log Start Time End Time Dur (hr) Cum Dur (hr)Phase Opr. Act. Plan Oper. Descr. 00:00 01:30 1.50 1.50 W.O. M 4 P Rig-up GBR and make-up BHA #16 2-7/8” PH-6 joint, Baker flat, XO, and bent pup. Monitor annulus and add 10 BPH of 8.6 PPG 3% KCL / NaCl brine inhibited with Biocide. 01:30 02:30 1.00 2.50 W.O. M 25 U Trouble shoot accumulator pump #1 electric motor. 02:30 04:30 2.00 4.50 W.O. M 4 P Continue picking-up BHA #16 ' 2-7/8” of PH-6 snorkle and 5-3/4” Baker VAC tool, to 362’. Monitor annulus and add 10 BPH of 8.6 PPG 3% KCL / NaCl brine inhibited with Biocide. 04:30 08:30 4.00 8.50 W.O. M 4 P Continue Rin in hole w/ BHA # 16 Vacs tool from 362' to 5,964’ MD. Reduce trip speed to 20-50 FPM from 4,556’ to 5,964’. UP wt.= 150K / DN wt. =132K. Monitor annulus and add 10 BPH of 8.6 PPG 3% KCL / NaCl brine inhibited with Biocide. Note: AOGCC notification of BOP test 07-05-2024. 08:30 12:30 4.00 12.50 W.O. M 7 P Wash from 5,964’ to 6,060’ MD pumping 5.25 BPM at 1000 psi. tag with 4K.Start rotating 5 RPM at 3-5K torque to 6,116’ Tag with 5K.’ Re Orientated and slide into L1 from 5,935’ to 6,231’ 5.25 BPM at 1000 psi. UP wt.= 150K / DN wt. =130K. Monitor annulus and add 10 BPH of 8.6 PPG 3% KCL / NaCl brine inhibited with Biocide. 12:30 16:00 3.50 16.00 W.O. M 4 P Pull out of hole from 6,231’ to 362’. UP wt.= 150K / DN wt. = 130K . Monitor annulus and add 10 BPH of 8.6 PPG 3% KCL / NaCl brine inhibited with Biocide, plus pipe displacement. 16:00 18:30 2.50 18.50 W.O. M 4 P Break down Baker VAC tool and clean upper and lower chambers, Clean floor recovered 0.25 barrel of sand. Monitor annulus and add 10 BPH of 8.6 PPG 3% KCL / NaCl brine inhibited with Biocide 18:30 19:00 0.50 19.00 W.O. M 1 P Service rig. Monitor annulus and add 10 BPH of 8.6 PPG 3% KCL / NaCl brine inhibited with Biocide. 19:00 20:00 1.00 20.00 W.O. M 4 P Pull out of hole and lay down 2-7/8” PH-6 pipe with GBR and recovered 0.25 BBL of sand above flapper sub.Total recovered 1/2 bbl. from BHA #16. Monitor annulus and add 10 BPH of 8.6 PPG 3% KCL / NaCl brine inhibited with Biocide. 20:00 00:00 4.00 24.00 W.O. M 1 P Load and prep 2-7/8” PH-6 into pipe shed. Pick-up BHA #17, 2-7/8” with GBR to 280’. Daily losses to the well 643 bbl's. Total losses to the well 6,219 bbl's. Daily Contacts Position Contact Name Company Title Email Office Mobile Company Representative Bruce Simonson ASRC Energy Services Drilling Supv. siddrilling@eni.com 907-685-0715 Company Representative David Smith ASRC Energy Services Drilling Supv. siddrilling@eni.com 907-685-0715 Safety Representative Mark Hubler ASRC Energy Services HSE mark.hubler@external.eni.com 907-685-0721 Tool Push Grant Neuharth Doyon Drilling Tool Pusher rig15@doyondrilling.com 907-685-0727 Safety Representative Craig Medlock Doyon Drilling HSE rig15@doyondrilling.com 907-685-0796 Company Representative Craig Smith ASRC Energy Services Drilling Supv. siddrilling@eni.com 907-685-0722 Last Casing Seat Cas. Type OD (in) ID (in) Grade Top (ftKB) Bottom (ftKB) TVD Bot. (ftKB) Landing Date LINER 5 1/2 4.95 L80 -13,937.1 13,996.9 3,786.6 1/31/2012 Well Name: SP23-N3 OR Wellbore Name: SP23-N3 Well Code: 26152 Job: WORKOVER WCEI Level: LEVEL 3 Daily Report Date: 7/4/2024 Report #: 24 Page: 1 of 1 Well Header Permit/Concession N° ADL-388583 Operator ENI PETROLEUM Subsidiary ENI Petroleum Co. Inc. Initial Lahee Code DEVELOPMENT WELL Rotary Table Elevation (ft) 40.89 Ground Level (ft) First Flange (ft) 4.09 RKB - Base Flange (ft) 36.80 RKB - Tubing Spool (ft) 31.91 Rig Information Rig Name RIG 15 Contractor DOYON Rig Type LAND RIG Rig Num 0723 Daily Information Weather Overcast Temperature (°F) 42.0 Wind W @ 22 MPH Days LTI (days) 1,643.00 Days RI (days) POB 46.0 Daily Summary Operations 24h Forecast Wash down L1F/ 8,606' to 8,799’ with 2-7/8” snorkel pipe and VAC 20’ above liner. Pull out hole. Test BOPE. 24h Summary Pick-up BHA #17 with 3,000’ 2-7/8” snorkel pipe and VAC tool. Trip in hole to 5,996’ rotate and entered L1 and wash to 8,606’. Note: AOGCC Kam Stjohn waived witness of BOP test, Operation at 07.00 Trip out of the hole W/ BHA #17 Time Log Start Time End Time Dur (hr) Cum Dur (hr)Phase Opr. Act. Plan Oper. Descr. 00:00 05:30 5.50 5.50 W.O. M 4 P Rig-up GBR and make-up BHA #17 2-7/8” snorkel pipe from 280’ to 2,999’ Superior thread inspected every connection and make-up. Pick-up remaining Baker VAC tool assembly, bumper sub, and jars to 3,106’. Monitor annulus and add 10 BPH of 8.6 PPG 3% KCL / NaCl brine inhibited with Biocide. 05:30 08:00 2.50 8.00 W.O. M 4 P Trip in hole from 3,106’ to 5,996’. UP wt.=128K / DN wt.=118K. Monitor annulus and add 10 BPH of 8.6 PPG 3% KCL / NaCl brine inhibited with Biocide. 08:00 12:00 4.00 12.00 W.O. M 4 P Obtained parameters pumping 5.25 BPM at 925 psi. UP wt.=129K / DN wt.=118K / Rot wt.=124K. Wash from 5,996’ to 6,002’ tag liner top with 2K. Pick-up and rotate into liner top with 10 RPM at 2.5-5K torque to 6,075’, stop rotation and wash down to 6,179’ confirm in L1. Continue washing to 6,649’. UP wt.=134K / DN wt.=121K. Dynamitic return flow rate calculated at 65%. 12:00 13:00 1.00 13.00 W.O. M 4 P Wash from 6,649’ to 6,740’. MD pumping 5.14 BPM at 975 psi. UP wt.=136K / DN wt.=120K. 13:00 14:00 1.00 14.00 W.O. M 4 P Transfer 8.6 PPG 3% KCL / NaCl brine inhibited with Biocide, from mud plant to rig active pits. 14:00 18:00 4.00 18.00 W.O. M 4 P Wash from 6,740’ to 7,670’ MD pumping 5.46 BPM at 1010 psi. UP wt.=150K / DN wt.=125K 18:00 00:00 6.00 24.00 W.O. M 4 P Continue washing from 7,670’ to 8,606’ MD pumping 5.46 BPM at 1019 psi. UP wt.=160K / DN wt.=119K. Daily losses to the well 703 bbls. Total losses to the well 6,922 bbls. Daily Contacts Position Contact Name Company Title Email Office Mobile Company Representative Steve Lawrence ASRC Energy Services Drilling Supv. siddrilling@eni.com 907-685-0715 Company Representative David Smith ASRC Energy Services Drilling Supv. siddrilling@eni.com 907-685-0715 Safety Representative Mark Hubler ASRC Energy Services HSE mark.hubler@external.eni.com 907-685-0721 Tool Push Grant Neuharth Doyon Drilling Tool Pusher rig15@doyondrilling.com 907-685-0727 Safety Representative Craig Medlock Doyon Drilling HSE rig15@doyondrilling.com 907-685-0796 Company Representative Craig Smith ASRC Energy Services Drilling Supv. siddrilling@eni.com 907-685-0722 Last Casing Seat Cas. Type OD (in) ID (in) Grade Top (ftKB) Bottom (ftKB) TVD Bot. (ftKB) Landing Date LINER 5 1/2 4.95 L80 -13,937.1 13,996.9 3,786.6 1/31/2012 Well Name: SP23-N3 OR Wellbore Name: SP23-N3 Well Code: 26152 Job: WORKOVER WCEI Level: LEVEL 3 Daily Report Date: 7/5/2024 Report #: 25 Page: 1 of 1 Well Header Permit/Concession N° ADL-388583 Operator ENI PETROLEUM Subsidiary ENI Petroleum Co. Inc. Initial Lahee Code DEVELOPMENT WELL Rotary Table Elevation (ft) 40.89 Ground Level (ft) First Flange (ft) 4.09 RKB - Base Flange (ft) 36.80 RKB - Tubing Spool (ft) 31.91 Rig Information Rig Name RIG 15 Contractor DOYON Rig Type LAND RIG Rig Num 0723 Daily Information Weather Rain Temperature (°F) 33.0 Wind NE @ 18 MPH Days LTI (days) 1,644.00 Days RI (days) POB 46.0 Daily Summary Operations 24h Forecast Complete BOP testing. Pick-up BHA #18 with 4,000’ snorkel pipe. Run in hole to clean out L1. 24h Summary Wash down L1 to 8,799’ with 2-7/8” snorkel pipe. Pull out hole lay down BHA #17.and test bope. Operation at 07.00 Continue testing bops Time Log Start Time End Time Dur (hr) Cum Dur (hr)Phase Opr. Act. Plan Oper. Descr. 00:00 02:30 2.50 2.50 W.O. M 7 P Continue washing from 8,606’ to 8,799’ MD pumping 5.46 BPM at 1019 psi. UP wt.=160K / DN wt.=119K. Tagged up, engaged rotary at 5 RPM, 5-7K TQ, ROT wt.=134K and was able to work down to 8,799’. Could not make any additional hole. Decision made to pull out of hole. 02:30 03:30 1.00 3.50 W.O. M 7 P Pump out of hole from 8,799’ to 8,606’ at 5.25 BPM, 1000 PSI, UP wt.=161K, DN wt.=119K. 03:30 06:00 2.50 6.00 W.O. M 4 P Pull out of hole with 5.75” Vacs tool assembly on elevator, from 8,606’ to 3,106’, pumping 10 BPH, plus pipe displacement of 8.6 PPG 3%KCL/ NaCl brine inhibited with biocide. 06:00 08:30 2.50 8.50 W.O. M 4 P Lay down BHA #17, Break down VACS tool and recovered approximately 1 gallon of sandt. Lay down VACS tool to pipe shed. 08:30 09:00 0.50 9.00 W.O. M 25 P Perform rig service. Grease crown / top drive / Traveling blocks / Draw Works. 09:00 16:30 7.50 16.50 W.O. M 4 P Make up XO for safety valve. Rig up GBR and lay down 2.875” snorkel pipe. Pump 10 BPH plus pipe displacement, of 8.6 PPG 3%KCL/ NaCl brine inhibited with biocide. Recovered 1.8 BBL of sand from the last 11 joints. 16:30 18:30 2.00 18.50 W.O. M 1 P Clean and clear rig floor. Pump 10 BPH of 8.6 PPG 3%KCL/ NaCl brine inhibited with biocide. 18:30 21:30 3.00 21.50 W.O. M 12 P Rig-up Bope test equipment, fluid pack BOP stack, choke manifold and top drive. Shell test to 250 psi. lower / 3000 psi. high. 21:30 00:00 2.50 24.00 W.O. M 12 P Testing BOP, Sequence #1 through #5 on 2-7/8” x 5” variable upper and lower rams with a 5” test joint to 250 psi. low/3000 psi. high for 5 minutes each. Test choke manifold valves, Test top drive lower and upper IBOP. Primary and secondary HCR kill/choke valves and primary and secondary manual choke valves. Monitor annulus and pump 10 BPH of 8.6 PPG NaCl/ 3% KCL brine inhibited with Biocide. Daily losses to the well 494 bbls. Total losses to the well 7416 bbls Daily Contacts Position Contact Name Company Title Email Office Mobile Company Representative Steve Lawrence ASRC Energy Services Drilling Supv. siddrilling@eni.com 907-685-0715 Company Representative David Smith ASRC Energy Services Drilling Supv. siddrilling@eni.com 907-685-0715 Safety Representative Mark Hubler ASRC Energy Services HSE mark.hubler@external.eni.com 907-685-0721 Tool Push Grant Neuharth Doyon Drilling Tool Pusher rig15@doyondrilling.com 907-685-0727 Safety Representative Craig Medlock Doyon Drilling HSE rig15@doyondrilling.com 907-685-0796 Company Representative Craig Smith ASRC Energy Services Drilling Supv. siddrilling@eni.com 907-685-0722 Last Casing Seat Cas. Type OD (in) ID (in) Grade Top (ftKB) Bottom (ftKB) TVD Bot. (ftKB) Landing Date LINER 5 1/2 4.95 L80 -13,937.1 13,996.9 3,786.6 1/31/2012 Well Name: SP23-N3 OR Wellbore Name: SP23-N3 Well Code: 26152 Job: WORKOVER WCEI Level: LEVEL 3 Daily Report Date: 7/6/2024 Report #: 26 Page: 1 of 1 Well Header Permit/Concession N° ADL-388583 Operator ENI PETROLEUM Subsidiary ENI Petroleum Co. Inc. Initial Lahee Code DEVELOPMENT WELL Rotary Table Elevation (ft) 40.89 Ground Level (ft) First Flange (ft) 4.09 RKB - Base Flange (ft) 36.80 RKB - Tubing Spool (ft) 31.91 Rig Information Rig Name RIG 15 Contractor DOYON Rig Type LAND RIG Rig Num 0723 Daily Information Weather Overcast Temperature (°F) 33.0 Wind NE @ 7 MPH Days LTI (days) 1,645.00 Days RI (days) POB 46.0 Daily Summary Operations 24h Forecast Continue tripping in the hole wash down to 10,052’ 24h Summary Complete BOP test, pick up BHA 18, Trip in the hole to 5,857' slip and cut drilling line. Continued Trip in the hole to 6,416' Operation at 07.00 Washing down into the L1 to 9,200' Time Log Start Time End Time Dur (hr) Cum Dur (hr)Phase Opr. Act. Plan Oper. Descr. 00:00 04:30 4.50 4.50 W.O. M 12 P Completed BOP testing. (Good test) Rig down test equipment. Remove test plug and install wear bushing. Note: AOGCC Kam Stjohn waived witness of BOP test, 04:30 07:00 2.50 7.00 W.O. M 1 P Load and process an additional 1,000' of 2.875” snorkel pipe in pipe shed. Continue to pump 10 BPH of 8.6 PPG NaCl/ 3% KCL brine inhibited with Biocide. 07:00 12:00 5.00 12.00 W.O. M 4 P Trip in the hole W/ BHA #18, 2.875” snorkel pipe to 3,552’ with GBR and Superior rep. Continue to pump 10 BPH of 8.6 PPG NaCl/ 3% KCL brine inhibited with Biocide. 12:00 14:30 2.50 14.50 W.O. M 4 P Continued Picking up 2.875” snorkel pipe from 3,552’ to 4,086’ with GBR and superior rep. Continue to pump 10 BPH of 8.6 PPG NaCl/ 3% KCL brine inhibited with Biocide. 14:30 15:30 1.00 15.50 W.O. M 4 P Run in the hole W/ 5” drill pipe stands from 4,086’ to 4,179’. Break circulation at increasing rates of 3 BPM at 75 psi. / 4 BPM at 180 psi. / 5.18 BPM at 391 psi. pump two pipe volumes. 15:30 17:30 2.00 17.50 W.O. M 4 P Continue trip in the hole 5” drill pipe stands from 4,179’ to 5,857’ fill pipe at 4 BPM at 235 psi. UP wt.= 115K / DN wt.= 108K. 17:30 21:00 3.50 21.00 W.O. M 25 P Prep floor for slip and cut drilling line. Service rig. Fill 10 BPH of 8.6 PPG NaCl/ 3% KCL brine inhibited with Biocide. 21:00 22:30 1.50 22.50 W.O. M 1 P Transfer 558 BBLS of 8.6 PPG NaCl/ 3% KCL brine inhibited with Biocide from mud plant. Perform block calibration. Replace shaker screens. 22:30 00:00 1.50 24.00 W.O. M 4 P Run in the hole W/ 5” drill pipe stands from 5,857’ to 6,040’. Obtain parameters, pumping 7.53 BPM at 703 psi. / 9 BPM at 1030 psi with returns at 10 RPM at 2K free torque. UP wt.= 120K / DN wt.= 115K / ROT wt. 115K. Continue running hole tag no-go with 2K at 6,116’. Pick-up to 6,040’ orientate 1/2 turn right went down into L1 to 6,416’. Daily losses to the well 208 bbls. Total losses to the well 7,624 bbls. Daily Contacts Position Contact Name Company Title Email Office Mobile Company Representative Steve Lawrence ASRC Energy Services Drilling Supv. siddrilling@eni.com 907-685-0715 Company Representative David Smith ASRC Energy Services Drilling Supv. siddrilling@eni.com 907-685-0715 Safety Representative Mark Hubler ASRC Energy Services HSE mark.hubler@external.eni.com 907-685-0721 Tool Push Grant Neuharth Doyon Drilling Tool Pusher rig15@doyondrilling.com 907-685-0727 Safety Representative Craig Medlock Doyon Drilling HSE rig15@doyondrilling.com 907-685-0796 Company Representative Craig Smith ASRC Energy Services Drilling Supv. siddrilling@eni.com 907-685-0722 Last Casing Seat Cas. Type OD (in) ID (in) Grade Top (ftKB) Bottom (ftKB) TVD Bot. (ftKB) Landing Date LINER 5 1/2 4.95 L80 -13,937.1 13,996.9 3,786.6 1/31/2012 Well Name: SP23-N3 OR Wellbore Name: SP23-N3 Well Code: 26152 Job: WORKOVER WCEI Level: LEVEL 3 Daily Report Date: 7/7/2024 Report #: 27 Page: 1 of 1 Well Header Permit/Concession N° ADL-388583 Operator ENI PETROLEUM Subsidiary ENI Petroleum Co. Inc. Initial Lahee Code DEVELOPMENT WELL Rotary Table Elevation (ft) 40.89 Ground Level (ft) First Flange (ft) 4.09 RKB - Base Flange (ft) 36.80 RKB - Tubing Spool (ft) 31.91 Rig Information Rig Name RIG 15 Contractor DOYON Rig Type LAND RIG Rig Num 0723 Daily Information Weather Partly Cloudy Temperature (°F) 30.0 Wind NE @ 6 MPH Days LTI (days) 1,646.00 Days RI (days) POB 46.0 Daily Summary Operations 24h Forecast Pull out hole lay down BHA # 18. Make up BHA # 19 run in the hole clean out main bore. 24h Summary Continue tripping in hole to wash and Ream to 10,033’ Circulate clean with returns to surface. Pull out hole to BHA # 18 to 4,739' Operation at 07.00 Laying down BHA # 18 Time Log Start Time End Time Dur (hr) Cum Dur (hr)Phase Opr. Act. Plan Oper. Descr. 00:00 04:30 4.50 4.50 W.O. M 4 P Continue to trip in hole with BHA #18 on elevators from 6,416’ to 8,465’, Began to see drag engaged rotary and washed down from 8,465’ to 8,775’ at 8 BPM rate at 1025 psi. UP wt.= 151K / DN wt.= 131K / ROT wt.= 134K. Continue to pump 10 BPH of 8.6 PPG NaCl/ 3% KCL brine inhibited with Biocide. 04:30 13:00 8.50 13.00 W.O. M 4 P Wash and ream from 8,775’ to 10,033’, pump rate of 8 BPM at 1070 psi. rotating at 10 RPM with 6-7K torque. UP wt.= 165K / DN wt.= 115K / ROT wt.= 140K. 13:00 15:00 2.00 15.00 W.O. M 7 P Circulate bottoms up, while rotating and reciprocating pipe from 10,033’ to 9,963’ pump rate 8 BPM at 1090 psi. rotating 10 RPM at 6-7K torque, UP wt.= 165K / DN wt.= 115K / ROT wt.= 140K. Estimated 192 bbls. of sand recovered. Monitor well fluid level falling. 15:00 20:30 5.50 20.50 W.O. M 4 P Pull out of hole with BHA #18 from 10,033’ to 6,136’ UP wt.= 125K / DN wt.= 114K. Monitor annulus to add 10 BPH plus pipe displacement of 8.6 PPG NaCl/ 3% KCL brine inhibited with Biocide. 20:30 23:30 3.00 23.50 W.O. M 7 P Circulate and reciprocating drill pipe from 6,136’ to 6,040’ pumping 10 BPM at 1328 psi. Work drill pipe Pump out hole to 5,946’ Circulate 2 bottom up while reciprocating drill pipe to 5,853’ increasing pump rate to 12 BPM at 1469 psi. Rotating 45 RPM at 4-6K torque. UP wt.= 125K / DN wt.= 110K. / ROT wt.= 115K. 23:30 00:00 0.50 24.00 W.O. M 4 P Pull out of hole with BHA #18 from 5,583’ to 4,739’. UP wt.= 100K / DN wt.= 90K. Monitor annulus to add 10 BPH plus pipe displacement of 8.6 PPG NaCl / 3% KCL brine inhibited with Biocide. Daily losses to the well 1,288 bbls. Total losses to the well 9,549 bbls. Daily Contacts Position Contact Name Company Title Email Office Mobile Company Representative Steve Lawrence ASRC Energy Services Drilling Supv. siddrilling@eni.com 907-685-0715 Company Representative David Smith ASRC Energy Services Drilling Supv. siddrilling@eni.com 907-685-0715 Safety Representative Mark Hubler ASRC Energy Services HSE mark.hubler@external.eni.com 907-685-0721 Tool Push Grant Neuharth Doyon Drilling Tool Pusher rig15@doyondrilling.com 907-685-0727 Safety Representative Craig Medlock Doyon Drilling HSE rig15@doyondrilling.com 907-685-0796 Company Representative Craig Smith ASRC Energy Services Drilling Supv. siddrilling@eni.com 907-685-0722 Last Casing Seat Cas. Type OD (in) ID (in) Grade Top (ftKB) Bottom (ftKB) TVD Bot. (ftKB) Landing Date LINER 5 1/2 4.95 L80 -13,937.1 13,996.9 3,786.6 1/31/2012 Well Name: SP23-N3 OR Wellbore Name: SP23-N3 Well Code: 26152 Job: WORKOVER WCEI Level: LEVEL 3 Daily Report Date: 7/8/2024 Report #: 28 Page: 1 of 1 Well Header Permit/Concession N° ADL-388583 Operator ENI PETROLEUM Subsidiary ENI Petroleum Co. Inc. Initial Lahee Code DEVELOPMENT WELL Rotary Table Elevation (ft) 40.89 Ground Level (ft) First Flange (ft) 4.09 RKB - Base Flange (ft) 36.80 RKB - Tubing Spool (ft) 31.91 Rig Information Rig Name RIG 15 Contractor DOYON Rig Type LAND RIG Rig Num 0723 Daily Information Weather Partly Cloudy Temperature (°F) 33.0 Wind NE @ 12 MPH Days LTI (days) 1,647.00 Days RI (days) POB 46.0 Daily Summary Operations 24h Forecast Pull out hole start to lay down 5' Drill pipe. 24h Summary Pull out hole lay down BHA # 18. Pick-up BHA # 19 run in the hole clean out main well bore to 7,985’. Pull out of hole to 6,000. Operation at 07.00 Laying down 5' Drill pipe. Time Log Start Time End Time Dur (hr) Cum Dur (hr)Phase Opr. Act. Plan Oper. Descr. 00:00 02:00 2.00 2.00 W.O. M 4 P Pull out of hole with BHA #18 from 4,739’ to 4,086’. UP wt.= 45K / DN wt.= 40K. Monitor annulus to add 10 BPH plus pipe displacement of 8.6 PPG 3% KCL / NaCl brine inhibited with Biocide. 02:00 06:30 4.50 6.50 W.O. M 4 P Laydown BHA #18; Note: normal wear on step mill shoe. Pump 10 BPH plus pipe displacement, of 8.6 PPG 3% KCL/ NaCl brine inhibited with biocide. 06:30 07:00 0.50 7.00 W.O. M 25 P Perform rig service. 07:00 10:30 3.50 10.50 W.O. M 4 P Pick up BHA #19 with 3.44” step mill shoe and 2,000’ of 2.875” snorkel pipe, jar, and bumper sub. Change out elevators to 5”. Pump 10 BPH of 8.6 PPG 3%KCL/ NaCl brine inhibited with biocide. 10:30 14:00 3.50 14.00 W.O. M 4 P Trip in hole with BHA #19 from 2,048’ to 5,962’; DN wt.= 120K. Pump 10 BPH of 8.6 PPG 3% KCL / NaCl brine inhibited with biocide. 14:00 15:00 1.00 15.00 W.O. M 1 P Bring on brine to the rig from the mud plant. 15:00 22:00 7.00 22.00 W.O. M 7 P Obtain parameters above liner, enter liner top and trip in hole to 6,055’ and obtained parameters inside of liner, with pumps rate of 8 BPM at 460 psi., slacked off and tagged no-go at 6,116’. Set 6K down and was able to see shoe enter main bore. Once we started into the main bore we had a 1000 PSI spike. Washed down from 6,116’ to 7,985’. Observed loss of returns at 6,235’ and reduced pump rate to 3 BPM at 53 psi. with of trip 10-15 FPM string speed. UP wt.= 167K DN wt.= 120K. Attempt to circulate pumping 8 BPM at 476 psi. with 17% return. 22:00 22:30 0.50 22.50 W.O. M 1 P Monitor well – fluid level falling. 22:30 00:00 1.50 24.00 W.O. M 4 P Pull out of hole from 7,985’ to 6,000’. Pump 10 BPH plus pipe displacement, of 8.6 PPG 3% KCL/ NaCl brine inhibited with biocide, UP wt.= 150K DN wt.= 123K. Daily losses to the well 383 bbls. Total losses to the well 9295 bbls. Daily Contacts Position Contact Name Company Title Email Office Mobile Company Representative Steve Lawrence ASRC Energy Services Drilling Supv. siddrilling@eni.com 907-685-0715 Company Representative David Smith ASRC Energy Services Drilling Supv. siddrilling@eni.com 907-685-0715 Safety Representative Mark Hubler ASRC Energy Services HSE mark.hubler@external.eni.com 907-685-0721 Tool Push Grant Neuharth Doyon Drilling Tool Pusher rig15@doyondrilling.com 907-685-0727 Safety Representative Craig Medlock Doyon Drilling HSE rig15@doyondrilling.com 907-685-0796 Company Representative Craig Smith ASRC Energy Services Drilling Supv. siddrilling@eni.com 907-685-0722 Last Casing Seat Cas. Type OD (in) ID (in) Grade Top (ftKB) Bottom (ftKB) TVD Bot. (ftKB) Landing Date LINER 5 1/2 4.95 L80 -13,937.1 13,996.9 3,786.6 1/31/2012 Well Name: SP23-N3 OR Wellbore Name: SP23-N3 Well Code: 26152 Job: WORKOVER WCEI Level: LEVEL 3 Daily Report Date: 7/9/2024 Report #: 29 Page: 1 of 1 Well Header Permit/Concession N° ADL-388583 Operator ENI PETROLEUM Subsidiary ENI Petroleum Co. Inc. Initial Lahee Code DEVELOPMENT WELL Rotary Table Elevation (ft) 40.89 Ground Level (ft) First Flange (ft) 4.09 RKB - Base Flange (ft) 36.80 RKB - Tubing Spool (ft) 31.91 Rig Information Rig Name RIG 15 Contractor DOYON Rig Type LAND RIG Rig Num 0723 Daily Information Weather Clear Temperature (°F) 30.0 Wind NE @ 25 MPH Days LTI (days) 1,648.00 Days RI (days) POB 45.0 Daily Summary Operations 24h Forecast Pick-up and run ESP completion. 24h Summary Pull out hole Lay down all 5” drill pipe Continue lay down 2.875” snorkel pipe. Rig-up equipment to run ESP completion. Operation at 07.00 Make up ESP pump assembly. Time Log Start Time End Time Dur (hr) Cum Dur (hr)Phase Opr. Act. Plan Oper. Descr. 00:00 00:30 0.50 0.50 W.O. M 7 P Circulate bottoms up pumping 10 BPM at 632 psi. with 26% return, loss rate 360 BPH. 00:30 01:30 1.00 1.50 W.O. M 1 P Remove 2.875” snorkel pipe and VACS tool out of pipe shed. Pump 10 BPH, of 8.6 PPG 3% KCL/ NaCl brine inhibited with biocide. 01:30 08:00 6.50 8.00 W.O. M 4 P Pull out of hole with BHA #19 laying down 5” drill pipe from 6,000’ to 2,048’. UP wt.= 78K. Pump 10 BPH plus pipe displacement, of 8.6 PPG 3% KCL/ NaCl brine inhibited with biocide. 08:00 09:30 1.50 9.50 W.O. M 4 P Trip in hole with remainder of 5” drill pipe in derrick from 2,048’ to 3,914’; UP wt.= 108K / DN wt.= 103K. Pump 10 BPH of 8.6 PPG 3% KCL / NaCl brine inhibited with biocide. 09:30 12:00 2.50 12.00 W.O. M 4 P Continue to pull out of hole with BHA #19, laying down 5” drill pipe from 3,914’ to 2,297’. Pump 10 BPH plus pipe displacement, of 8.6 PPG 3% KCL/ NaCl brine inhibited with biocide. 12:00 14:30 2.50 14.50 W.O. M 1 P Remove 5” drill pipe from pipe shed, continue to pump 10 BPH of 8.6 PPG 3% KCL/ NaCl brine inhibited with biocide. 14:30 15:00 0.50 15.00 W.O. M 4 P Continue to pull out of hole with BHA #19, laying down 5” drill pipe from 2,297’ to 2,048’. Pump 10 BPH plus pipe displacement, of 8.6 PPG 3% KCL/ NaCl brine inhibited with biocide 15:00 16:00 1.00 16.00 W.O. M 4 P Lay down Baker components, bumper sub jars and cross overs, clear BHA off rig floor. Pump 10 BPH of 8.6 PPG 3% KCL/ NaCl brine inhibited with biocide. 16:00 17:00 1.00 17.00 W.O. M 1 P Make-up XO to floor safety valve, change handling equipment to 2.875” and rig-up GBR tongs. Continue to pump 10 BPH of 8.6 PPG 3% KCL/ NaCl brine inhibited with biocide. 17:00 21:00 4.00 21.00 W.O. M 4 P Continue to pull out of hole with BHA #19, laying down 2.875” snorkel pipe from 2,048’ to Baker 3.44” step mill at surface. Pump 10 BPH plus pipe displacement, of 8.6 PPG 3% KCL/ NaCl brine inhibited with biocide. 21:00 23:00 2.00 23.00 W.O. M 1 P Pull wear bushing as per Vault rep. Pick-up stack washing tool, flush BOP equipment and well head. pumping 8 PM at 20 RPM. Lay down stack flushing tool and 5” drill pipe. 23:00 00:00 1.00 24.00 W.O. M 1 P Clear floor of BHA components. Install 4-1/2” elevators on bails, bring Baker ESP job box, and ESP components to run completion Daily losses to the well 1,177 bbls. Total losses to the well 10,472 bbls. Daily Contacts Position Contact Name Company Title Email Office Mobile Company Representative Steve Lawrence ASRC Energy Services Drilling Supv. siddrilling@eni.com 907-685-0715 Company Representative David Smith ASRC Energy Services Drilling Supv. siddrilling@eni.com 907-685-0715 Safety Representative Levi Karns ASRC Energy Services HSE Levi.Karns@external.eni.com 907-685-0721 Tool Push Grant Neuharth Doyon Drilling Tool Pusher rig15@doyondrilling.com 907-685-0727 Safety Representative Craig Medlock Doyon Drilling HSE rig15@doyondrilling.com 907-685-0796 Company Representative Craig Smith ASRC Energy Services Drilling Supv. siddrilling@eni.com 907-685-0722 Last Casing Seat Cas. Type OD (in) ID (in) Grade Top (ftKB) Bottom (ftKB) TVD Bot. (ftKB) Landing Date LINER 5 1/2 4.95 L80 -13,937.1 13,996.9 3,786.6 1/31/2012 Well Name: SP23-N3 OR Wellbore Name: SP23-N3 Well Code: 26152 Job: WORKOVER WCEI Level: LEVEL 3 Daily Report Date: 7/10/2024 Report #: 30 Page: 1 of 1 Well Header Permit/Concession N° ADL-388583 Operator ENI PETROLEUM Subsidiary ENI Petroleum Co. Inc. Initial Lahee Code DEVELOPMENT WELL Rotary Table Elevation (ft) 40.89 Ground Level (ft) First Flange (ft) 4.09 RKB - Base Flange (ft) 36.80 RKB - Tubing Spool (ft) 31.91 Rig Information Rig Name RIG 15 Contractor DOYON Rig Type LAND RIG Rig Num 0723 Daily Information Weather Overcast Temperature (°F) 30.0 Wind NE @ 28 MPH Days LTI (days) 1,649.00 Days RI (days) POB 44.0 Daily Summary Operations 24h Forecast Run in hole with ESP Completion. 24h Summary Complete rigging up of completion equipment. Trip in the hole with ESP completion from 83’ to 1,432’. Performing electrical and gauge checks every 1,000. Monitor capillary lines with 1000 psi. Operation at 07.00 Continue running in hole with ESP Completion. Time Log Start Time End Time Dur (hr) Cum Dur (hr)Phase Opr. Act. Plan Oper. Descr. 00:00 04:30 4.50 4.50 W.O. M 1 P Baker perpairing ESP components from shipping boxes in pipe shed. Pull ESP cable and capillary lines from spooling unit through sheaves in the derrick. 04:30 08:00 3.50 8.00 W.O. K 1 P Perform MLE splice to ESP cable splice and test electrical (Good test). Note: splice witnessed by ENI Electrician. 08:00 20:30 12.50 20.50 W.O. K 4 P Pick-up and service ESP motor and tandem seals, fill with oil, plugs reinstalled and verify rotation. Install check valve and attach capillary tube on centralizer, Pressure test to 500 psi and 1000 psi for 10 minutes each. Continue pressure up open at 3900 psi and close at 2200 psi. Good test. Witness by ENI Company Rep. Maintain 1000 psi on data logger while running in hole. Attached MLE to motor pot head and perform electrical test. Good test. Installed additional protectralizer/centralizer between upper and lower tandem seals, between seal assemblies and at discharge head. MLE and ESP cable splice landed in the middle of joint # 1, install splice clamp. Add 10 BPH to hole with 8.6 ppg 3% KCL / NaCl brine inhibited with biocide. 20:30 00:00 3.50 24.00 W.O. K 4 P Trip in the hole with ESP assembly from 83’ to 1,432’. Perform electrical and gauge checks every 1,000’, Monitor with 1000 psi on capillary lines. Add 10 BPH to the hole with 8.6 ppg 3% KCL / NaCl brine inhibited with biocide. DN wt.= 78K. Note: Daily losses to the well 473 bbls. Total losses to the well 10,945 bbls. Daily Contacts Position Contact Name Company Title Email Office Mobile Company Representative Steve Lawrence ASRC Energy Services Drilling Supv. siddrilling@eni.com 907-685-0715 Company Representative David Smith ASRC Energy Services Drilling Supv. siddrilling@eni.com 907-685-0715 Safety Representative Levi Karns ASRC Energy Services HSE Levi.Karns@external.eni.com 907-685-0721 Tool Push Grant Neuharth Doyon Drilling Tool Pusher rig15@doyondrilling.com 907-685-0727 Company Representative Craig Smith ASRC Energy Services Drilling Supv. siddrilling@eni.com 907-685-0722 Last Casing Seat Cas. Type OD (in) ID (in) Grade Top (ftKB) Bottom (ftKB) TVD Bot. (ftKB) Landing Date LINER 5 1/2 4.95 L80 -13,937.1 13,996.9 3,786.6 1/31/2012 Well Name: SP23-N3 OR Wellbore Name: SP23-N3 Well Code: 26152 Job: WORKOVER WCEI Level: LEVEL 3 Daily Report Date: 7/11/2024 Report #: 31 Page: 1 of 1 Well Header Permit/Concession N° ADL-388583 Operator ENI PETROLEUM Subsidiary ENI Petroleum Co. Inc. Initial Lahee Code DEVELOPMENT WELL Rotary Table Elevation (ft) 40.89 Ground Level (ft) First Flange (ft) 4.09 RKB - Base Flange (ft) 36.80 RKB - Tubing Spool (ft) 31.91 Rig Information Rig Name RIG 15 Contractor DOYON Rig Type LAND RIG Rig Num 0723 Daily Information Weather Overcast Temperature (°F) 30.0 Wind NE @ 20 mph Days LTI (days) 1,650.00 Days RI (days) POB 44.0 Daily Summary Operations 24h Forecast Nipple down BOP stack. Remove pipe rams and valves. Nipple-up tree. Passport test. Hand over well to production. 24h Summary Trip in the hole with ESP completion from 1,432’ to 5,913’. Performing electrical and gauge checks. Monitor capillary lines with 1000 psi. Land hanger and tested void. Rig - down completion equipment from rig floor. Flush BOP and rig components. Operation at 07.00 Nipple down BOP stack. Remove pipe rams and valves. Time Log Start Time End Time Dur (hr) Cum Dur (hr)Phase Opr. Act. Plan Oper. Descr. 00:00 04:00 4.00 4.00 W.O. K 4 P Trip in the hole with ESP assembly from 1,432’ to 3,035’. Baker installed cannon clamps on each connection, perform electrical and gauge checks every 1,000’, maintain 1000 psi. on capillary lines. Add 10 BPH to the hole with 8.6 ppg 3% KCL / NaCl brine inhibited with biocide. DN wt.= 85K. 04:00 04:30 0.50 4.50 W.O. K 9 P Pump tubing volume 18 BBL of 8.6 PPG 3% KCL / NaCl brine inhibited with biocide, at 2 BPM at 95 psi. 04:30 13:30 9.00 13.50 W.O. K 4 P Trip in the hole with ESP assembly from 3,035’ to 5,913’, Baker installed cannon clamps on each connection, perform electrical and gauge checks every 1,000’, maintain 1000 psi. on capillary lines. Add 10 BPH to the hole with 8.6 ppg 3% KCL / NaCl brine inhibited with biocide. DN wt.= 89K. 13:30 18:00 4.50 18.00 W.O. K 12 P Vault terminated capillary lines through tubing hanger pass through ports and test each to 5000 PSI (all good test). Install penetrator adapter and make final splice to penetrator, with ENI electrician witnessing the splice. Install umbilical and perform electrical checks through all prior to landing the tubing hanger. Baker perform capillary line A line 500 and 1000 psi for 10 mins. continue to pump opened at 3700 psi and closed at 1800 psi. B line 500 and 1000 psi for 10 mins. continue to pump opened at 4100 psi and closed at 2300 psi. 18:00 19:30 1.50 19.50 W.O. K 20 P Land tubing hanger with bottom of shroud at 5,978’ UP wt.= 103K, DN wt.= 86K. Perform electrical checks via the umbilical (all good test). Run in lock down screws and test tubing hanger body void seals to 5000 PSI for 15 minutes. Back out and lay down landing joint. Install BPV in hanger. 19:30 00:00 4.50 24.00 W.O. K 1 P Flush mud pumps mud lines, BOP stack, choke manifold /lines with fresh water. Blow down all equipment with air. Remove all completion tools from rig floor. Remove screen from shakers and clean under box. Remove the master bushings and clean drip pan. Note: Daily losses to the well 290 bbls. Total losses to the well 11,059 bbls Daily Contacts Position Contact Name Company Title Email Office Mobile Company Representative Steve Lawrence ASRC Energy Services Drilling Supv. siddrilling@eni.com 907-685-0715 Company Representative David Smith ASRC Energy Services Drilling Supv. siddrilling@eni.com 907-685-0715 Safety Representative Levi Karns ASRC Energy Services HSE Levi.Karns@external.eni.com 907-685-0721 Tool Push Tom Shones Doyon Drilling Tool Pusher rig15@doyondrilling.com 907-685-0727 Company Representative Craig Smith ASRC Energy Services Drilling Supv. siddrilling@eni.com 907-685-0722 Last Casing Seat Cas. Type OD (in) ID (in) Grade Top (ftKB) Bottom (ftKB) TVD Bot. (ftKB) Landing Date LINER 5 1/2 4.95 L80 -13,937.1 13,996.9 3,786.6 1/31/2012 Well Name: SP23-N3 OR Wellbore Name: SP23-N3 Well Code: 26152 Job: WORKOVER WCEI Level: LEVEL 3 Daily Report Date: 7/12/2024 Report #: 32 Page: 1 of 1 Well Header Permit/Concession N° ADL-388583 Operator ENI PETROLEUM Subsidiary ENI Petroleum Co. Inc. Initial Lahee Code DEVELOPMENT WELL Rotary Table Elevation (ft) 40.89 Ground Level (ft) First Flange (ft) 4.09 RKB - Base Flange (ft) 36.80 RKB - Tubing Spool (ft) 31.91 Rig Information Rig Name RIG 15 Contractor DOYON Rig Type LAND RIG Rig Num 0723 Daily Information Weather Partly Cloudy Temperature (°F) 33.0 Wind NE @ 10 MPH Days LTI (days) 1,651.00 Days RI (days) POB 44.0 Daily Summary Operations 24h Forecast Complete passport testing. Handover form to SP23-N3 to production. 24h Summary Nipple BOP stack, Remove rams and valves. Nipple-up tree and test tubing hanger seal void. Baker Centrilift performed the final electrical and gauge (Good test). Vault performed the passport test. Operation at 07.00 Operations Completed on SP23-N3 Time Log Start Time End Time Dur (hr) Cum Dur (hr)Phase Opr. Act. Plan Oper. Descr. 00:00 06:00 6.00 6.00 W.O. K 1 P Continue to clean under drip pan, 2+ BBL of sand to shovel out. Remove choke and kill hoses. 06:00 12:00 6.00 12.00 W.O. K 1 P Nipple down flow riser and flow line. Open ram doors and remove rams, clean out cavities. Disconnect accumulator lines from BOP’s. Remove and separate manual and HCR choke/kill valves from BOP. 12:00 17:00 5.00 17.00 W.O. K 1 P Completed removal of bottom rams and grease all seal areas and closed doors. Remove rams from BOP deck and power wash stack. Grease kill/choke flanges on stack. Nipple down stack and set back on stump, remove from high riser from well head and rack back in cellar. 17:00 20:30 3.50 20.50 W.O. K 1 P Vault rep installed both capillary lines through well head, clean and prepped tubing hanger. Nipple up tree and test tubing hanger seal void to 5000 for 15 minutes (witness ENI company man). Baker Centrilift performed the final electrical and gauge readings (Good test). 20:30 21:30 1.00 21.50 W.O. K 1 P Vault removed BPV and installed a 2-way check valve. Rig-up equipment to perform passport test. 21:30 00:00 2.50 24.00 W.O. K 1 P Passport testing #1 shell test to 3000 psi. for 10 mins; Test #2 swab valve to 3000 psi. for 30 min; Test #3 master/wing valve to 3000 psi. bleed off, cycle and grease valve, Daily losses to the well 190 bbls. Total losses to the well 11,249 bbls. Daily Contacts Position Contact Name Company Title Email Office Mobile Company Representative Steve Lawrence ASRC Energy Services Drilling Supv. siddrilling@eni.com 907-685-0715 Company Representative David Smith ASRC Energy Services Drilling Supv. siddrilling@eni.com 907-685-0715 Safety Representative Levi Karns ASRC Energy Services HSE Levi.Karns@external.eni.com 907-685-0721 Tool Push Tom Shones Doyon Drilling Tool Pusher rig15@doyondrilling.com 907-685-0727 Company Representative Craig Smith ASRC Energy Services Drilling Supv. siddrilling@eni.com 907-685-0722 Last Casing Seat Cas. Type OD (in) ID (in) Grade Top (ftKB) Bottom (ftKB) TVD Bot. (ftKB) Landing Date LINER 5 1/2 4.95 L80 -13,937.1 13,996.9 3,786.6 1/31/2012 Well Name: SP23-N3 OR Wellbore Name: SP23-N3 Well Code: 26152 Job: WORKOVER WCEI Level: LEVEL 3 Daily Report Date: 7/13/2024 Report #: 33 Page: 1 of 1 Well Header Permit/Concession N° ADL-388583 Operator ENI PETROLEUM Subsidiary ENI Petroleum Co. Inc. Initial Lahee Code DEVELOPMENT WELL Rotary Table Elevation (ft) 40.89 Ground Level (ft) First Flange (ft) 4.09 RKB - Base Flange (ft) 36.80 RKB - Tubing Spool (ft) 31.91 Rig Information Rig Name RIG 15 Contractor DOYON Rig Type LAND RIG Rig Num 0723 Daily Information Weather Partly Cloudy Temperature (°F) 33.0 Wind N @ 12 MPH Days LTI (days) 1,652.00 Days RI (days) POB 37.0 Daily Summary Operations 24h Forecast Continue cleaning active pit system and rig. 24h Summary Complete passport testing. Handover form to SP23-N3 to production. Operation at 07.00 Continue cleaning active pit system and rig. Time Log Start Time End Time Dur (hr) Cum Dur (hr)Phase Opr. Act. Plan Oper. Descr. 00:00 01:30 1.50 1.50 W.O. K 12 P Complete passport testing and reinstall 2” freeze protect line to A annulus. 01:30 02:30 1.00 2.50 W.O. K 5 P Rig down and remove ESP cable and capillary line sheaves from derrick. 02:30 12:00 9.50 12.00 W.O. K 2 P Begin cleaning active pits. Hook up drain hoses on the drip pan, begin power washing top drive, torque tube, rig floor, handling equipment. 12:00 18:00 6.00 18.00 W.O. K 2 P Continue to clean pits. Clean and clear handling equipment off rig floor. Clean bell nipple, flow line, mouse hole, pipe rack and rig floor mats. 18:00 00:00 6.00 24.00 W.O. K 2 P Continue cleaning active pits. Clean and clear handling equipment off rig floor. Continue cleaning rig floor mats and deck area of floor. Daily Contacts Position Contact Name Company Title Email Office Mobile Company Representative Steve Lawrence ASRC Energy Services Drilling Supv. siddrilling@eni.com 907-685-0715 Company Representative David Smith ASRC Energy Services Drilling Supv. siddrilling@eni.com 907-685-0715 Safety Representative Levi Karns ASRC Energy Services HSE Levi.Karns@external.eni.com 907-685-0721 Tool Push Tom Shones Doyon Drilling Tool Pusher rig15@doyondrilling.com 907-685-0727 Company Representative Craig Smith ASRC Energy Services Drilling Supv. siddrilling@eni.com 907-685-0722 Last Casing Seat Cas. Type OD (in) ID (in) Grade Top (ftKB) Bottom (ftKB) TVD Bot. (ftKB) Landing Date LINER 5 1/2 4.95 L80 -13,937.1 13,996.9 3,786.6 1/31/2012 Well Name: SP23-N3 OR Wellbore Name: SP23-N3 Well Code: 26152 Job: WORKOVER WCEI Level: LEVEL 3 Daily Report Date: 7/14/2024 Report #: 34 Page: 1 of 1 Well Header Permit/Concession N° ADL-388583 Operator ENI PETROLEUM Subsidiary ENI Petroleum Co. Inc. Initial Lahee Code DEVELOPMENT WELL Rotary Table Elevation (ft) 40.89 Ground Level (ft) First Flange (ft) 4.09 RKB - Base Flange (ft) 36.80 RKB - Tubing Spool (ft) 31.91 Rig Information Rig Name RIG 15 Contractor DOYON Rig Type LAND RIG Rig Num 0723 Daily Information Weather Partly Cloudy Temperature (°F) 35.0 Wind N @ 12 MPH Days LTI (days) 1,653.00 Days RI (days) POB 36.0 Daily Summary Operations 24h Forecast Cleaning and organizing rig and equipment for stack out. 24h Summary Continue cleaning active pit system and rig. Prep cold stack area. Operation at 07.00 Continue prep to move rig. Time Log Start Time End Time Dur (hr) Cum Dur (hr)Phase Opr. Act. Plan Oper. Descr. 00:00 06:00 6.00 6.00 W.O. A 1 P Continue cleaning active pits. Clean and clear handling equipment off the rig floor. Continue cleaning rig floor mats and deck area of floor. Prep and rig down the accumulator. 06:00 12:00 6.00 12.00 W.O. A 1 P Continue to clean pits, and rig floor mats. Pull rig floor mats, clean rig floor and prep for paint. 12:00 18:00 6.00 18.00 W.O. A 1 P Continue to prep rig floor for paint, clean drip pan, clean and paint and accumulator house floor. Suck out rod wash on mud pumps and blow down system. Move the pipe loading ramp away from the rig. Clean cuttings box, and pull drain plugs on centrifugal pumps. Spread Herculite for cold stack location, and lay mats for dance floor. 18:00 00:00 6.00 24.00 W.O. A 1 P Continue prep rig floor for paint, clean drip pans from cleaning floor, paint accumulator unit floor. Scrub and clean on BOP cellar deck area, clean out cutting box. Complete laying out rig mat for cold stack out location. Daily Contacts Position Contact Name Company Title Email Office Mobile Company Representative Steve Lawrence ASRC Energy Services Drilling Supv. siddrilling@eni.com 907-685-0715 Company Representative David Smith ASRC Energy Services Drilling Supv. siddrilling@eni.com 907-685-0715 Safety Representative Levi Karns ASRC Energy Services HSE Levi.Karns@external.eni.com 907-685-0721 Tool Push Tom Shones Doyon Drilling Tool Pusher rig15@doyondrilling.com 907-685-0727 Company Representative Craig Smith ASRC Energy Services Drilling Supv. siddrilling@eni.com 907-685-0722 Last Casing Seat Cas. Type OD (in) ID (in) Grade Top (ftKB) Bottom (ftKB) TVD Bot. (ftKB) Landing Date LINER 5 1/2 4.95 L80 -13,937.1 13,996.9 3,786.6 1/31/2012 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 Changeout__ 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): 14,021 712 N/A N/A Casing Collapse Structural Conductor Surface 2,270 Intermediate 4,760 Production Liner slotted 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: Giorgio Iannucci 6/7/2024 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 Amjad Chaudhry amjad.chaudhry@eni.com 907-865-3300 Well Operations Project Manager Nikaitchuq Schrader bluff Schrader Bluff 3806 13,967 3,807 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 slotted Tubing Grade:Tubing MD (ft): N/A STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL 391283, 3885833, 388574 211-127 3700 Centerpoint Dr, Ste, 500, Anchorage, AK, 99503 50-629-23456-00-00 Eni US Operating CO. Inc. SP23-N3 Length Size Proposed Pools: L80 TVD Burst 5,955 MD 6,870 5,020 160 2480 3895 160 2748 20" 13.375 160 9.6256369 2748 6369-13967 5.5 3895-3807 Perforation Depth TVD (ft): N/A June 9th, 2024 139677598 4 1/2 3807 N/A Perforation Depth MD (ft): 6369 m n P s 2 66 t ouuuuuuuuuuuuuttttttt___ N Form 10-403 Revised 06/2023 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov ucci ue andthe procedure ap 324-336 By Grace Christianson at 12:49 pm, Jun 07, 2024 SFD DSR-6/7/24 Jun 07, 2024 SFD 6/10/2024 June 9th, 2024 BOP test to 3000 psig Annular preventer test to 2500 psig X VTL 6/10/2024 10-404 X *&:JLC 6/11/2024 Brett W. Huber, Sr. Digitally signed by Brett W. Huber, Sr. Date: 2024.06.11 18:50:29 -05'00'06/11/24 RBDMS JSB 061324 3700 Centerpoint Drive Suite 500 Anchorage, Alaska 99503 Phone: 907-865-3300 June 7th, 2024 Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Application for Sundry Approval for SP23-N3 Rig Workover Dear Commissioners, ENI US Operating Co. Inc. hereby applies for a Workover Sundry for well SP23-N3. SP23-N3 was completed on Spy Island on February 3rd, 2012, with an electric submersible pump set at a depth of 5,929’ MD. This ESP producer was completed without a packer. The well started up for production on February 7 th,2012. In 2021, a second lateral was drilled, and the well was completed with a conventional ESP. The well continued producing until March 13 th, 2023, when an ESP failure occurred. A rig workover was performed in April 2024, and the well is currently being produced. The plan is to pull ESP completion, perform logging in 9-5/8” casing, and run a casing patch if needed to complete the well with a new ESP system and tubing. The estimated date for beginning this work is June 9 th, 2024. Please find attached for the review of the Commission forms 10-403 and supporting documentation. If you have any questions or require further information, please contact Amjad Chaudhry at 907- 865-3300. Sincerely, Giorgio Iannucci Well Operations Project Manager Sceey, June 7th, 2024 June 9 th, 2024 SP23-N3 Workover – Summary Page PTD#:211-127 Current Status SP23-N3 is currently being produced. Scope of Work The scope of this workover is to pull out existing tubing, run casing patch if needed and run new tubing and new ESP. General Well info Reservoir Pressure/TVD: This well is expected to have a static max bottom hole pressure of approximately 1100 psi (3,878’ TVD) during the time of workover. SP23-N3 MASP Shut-in BHP (Max) 1,100 psi, 5.5 ppge Depth 3,878 ft. (TVD) Gradient 0.1 psi/ft MASP 712 psi Wellhead type/pressure rating: Vetco Gray, MB-247/5000 psi BOP configuration: Annular/pipe/blind rams/Mudcross/pipe TIFL/MIT-IA/MIT-OA: Intermediate csg 9-5/8” was tested to 800 psi on February 8th, 2021. Well type: Producer Estimated start date: June 9th, 2024. Drilling rig: Doyon 15 Sr. Drilling Engineer: Amjad Chaudhry: Amjad.chaudhry@eni.com Work: 907-865-3300 Well Operations Project Manager: Giorgio Iannucci: Giorgio.Iannucci@eni.com Work: 907-865-3300 Procedure: 1. MIRU Doyon 2. Bullhead 8.6ppg brine down tubing through conventional ESP. 3. Bullhead 8.6ppg brine down the Annulus A 4. Set BPV, ND tree, NU BOPE and test as per AOGCC regulations 5. POOH with ESP completion string 6. Pressure test 9-5/8” casing to 1500psi/30min, charted 7. Contingency: Perform 9-5/8” casing evaluation log 8. Contingency: Install 9-5/8” Saltel casing patch 9. Contingency: RIH with 5-1/2” L1 lateral cleanout assembly 10. RIH with ESP completion string 11. Land hanger 12. Install BPV, ND BOPE, NU Tree 13. Passport test 14. Contingency: bullhead LVT freeze protection 15. RDMO Current schematic of the well: Planned completion will be the same and will be set at the +/- same depth. From:Brooks, Phoebe L (OGC) To:Rig 15 Cc:Regg, James B (OGC) Subject:RE: Rig 15 Spy Island SP23-N3 .xlsx Date:Wednesday, May 29, 2024 11:34:05 AM Attachments:Doyon 15 04-19-24 Revised.xlsx Thank you. I've attached a revised report, changing the Misc. fields to reflect "NA". Please update your copies. Phoebe Brooks Research Analyst Alaska Oil and Gas Conservation Commission Phone: 907-793-1242 CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Phoebe Brooks at 907-793-1242 or phoebe.brooks@alaska.gov. -----Original Message----- From: Rig 15 <rig15@doyondrilling.com> Sent: Wednesday, May 29, 2024 9:56 AM To: Brooks, Phoebe L (OGC) <phoebe.brooks@alaska.gov> Subject: RE: Rig 15 Spy Island SP23-N3 .xlsx Sorry for the delayed reply Rig 15 Toolpusher Shane Michael -----Original Message----- From: Brooks, Phoebe L (OGC) <phoebe.brooks@alaska.gov> Sent: Wednesday, May 29, 2024 9:28 AM To: Rig 15 <rig15@doyondrilling.com> Subject: RE: Rig 15 Spy Island SP23-N3 .xlsx I was following up on this email. Thanks, Phoebe Phoebe Brooks Research Analyst Alaska Oil and Gas Conservation Commission Phone: 907-793-1242 CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact 1LNDLWFKXT631 37' revised report Misc. fields to reflect "NA Phoebe Brooks at 907-793-1242 or phoebe.brooks@alaska.gov. -----Original Message----- From: Brooks, Phoebe L (OGC) Sent: Thursday, May 23, 2024 3:08 PM To: Rig 15 <rig15@doyondrilling.com> Subject: RE: Rig 15 Spy Island SP23-N3 .xlsx The Time the 24 hour notice was given was missing; please advise. Thank you, Phoebe Phoebe Brooks Research Analyst Alaska Oil and Gas Conservation Commission Phone: 907-793-1242 CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Phoebe Brooks at 907-793-1242 or phoebe.brooks@alaska.gov. -----Original Message----- From: Rig 15 <rig15@doyondrilling.com> Sent: Saturday, April 20, 2024 12:44 PM To: Regg, James B (OGC) <jim.regg@alaska.gov>; Brooks, Phoebe L (OGC) <phoebe.brooks@alaska.gov>; DOA AOGCC Prudhoe Bay <doa.aogcc.prudhoe.bay@alaska.gov> Subject: Rig 15 Spy Island SP23-N3 .xlsx CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. Your message is ready to be sent with the following file or link attachments: SP23-N3 .xlsx Note: To protect against computer viruses, e-mail programs may prevent sending or receiving certain types of file attachments. Check your e-mail security settings to determine how attachments are handled. STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION *All BOPE reports are due to the agency within 5 days of testing* SSub m it to :jim.regg@alaska.gov; AOGCC.Inspectors@alaska.gov; phoebe.brooks@alaska.gov Rig Owner: Rig No.:15 DATE: 4/18/24 Rig Rep.: Rig Email: Operator: Operator Rep.: Op. Rep Email: Well Name:PTD #22111270 Sundry #324-165 Operation: Drilling: Workover: X Explor.: Test: Initial: X Weekly: Bi-Weekly: Other: Rams:250-2500 Annular:250-2500 Valves:250-2500 MASP:712 MISC. INSPECTIONS: TEST DATA FLOOR SAFETY VALVES: Test Result/Type Test Result Quantity Test Result Housekeeping P Well Sign P Upper Kelly 1P Permit On Location P Hazard Sec.P Lower Kelly 1P Standing Order Posted P Misc.NA Ball Type 2P Test Fluid Water Inside BOP 2P FSV Misc 0NA BOP STACK:Quantity Size/Type Test Result MUD SYSTEM:Visual Alarm Stripper 0NATrip Tank PP Annular Preventer 1 13-5/8" 5k P Pit Level Indicators PP #1 Rams 1 2-7/8x5"P Flow Indicator PP #2 Rams 1 Blind/Shear P Meth Gas Detector PP #3 Rams 1 2-7/8x5"P H2S Gas Detector PP #4 Rams 0NAMS Misc 0NA #5 Rams 0NA #6 Rams 0NAACCUMULATOR SYSTEM: Choke Ln. Valves 2 3-1/8" 5k P Time/Pressure Test Result HCR Valves 4 3-1/8" 5k P System Pressure (psi)2950 P Kill Line Valves 4 3-1/8" 5k P Pressure After Closure (psi)2175 P Check Valve 0NA200 psi Attained (sec)9 P BOP Misc 0NAFull Pressure Attained (sec)43 P Blind Switch Covers: All stations Yes CHOKE MANIFOLD:Bottle Precharge:P Quantity Test Result Nitgn. Bottles # & psi (Avg.): 10@4200 P No. Valves 15 P ACC Misc 0NA Manual Chokes 1P Hydraulic Chokes 1P Control System Response Time:Time (sec) Test Result CH Misc 0NA Annular Preventer 10 P #1 Rams 7 P Coiled Tubing Only:#2 Rams 7 P Inside Reel valves 0NA #3 Rams 7 P #4 Rams 0 NA Test Results #5 Rams 0 NA #6 Rams 0 NA Number of Failures:0 Test Time:9.0 HCR Choke 2 P Repair or replacement of equipment will be made within 0 days. HCR Kill 2 P Remarks: AOGCC Inspection 24 hr Notice Yes Date/Time 4/16/24 05:26am Waived By Test Start Date/Time:4/18/2024 20:00 (date) (time)Witness Test Finish Date/Time:4/19/2024 5:00 BOPE Test Report Notify the AOGCC of repairs with written confirmation to: AOGCC.Inspectors@alaska.gov Guy Cook Doyon All test performed with hanger and BPV , blanking plug installed, Test Annular with 2-7/8 and 5" test jts. 250-2500psi/5min. Preventers with 2-7/8 & 5" test jts. Choke valves 250-2500psi/5min. Test both 5" and 2-7/8" Floor and Dart Valves 250- 2500psi/5min. T.Shones/T.Kruger ENI S.Lawrence/M.Grubb Nikaitchuq SP23-N03 Test Pressure (psi): rig15@doyondrilling.com Form 10-424 (Revised 08/2022) 2024-0419_BOP_Doyon15_Nikaitchuq_SP23-N3 MEU 9 9 From:Rig 15 To:Regg, James B (OGC); Brooks, Phoebe L (OGC); DOA AOGCC Prudhoe Bay Subject:Rig 15 BOP test 4-26-24 SP23-N3.xlsx Date:Saturday, April 27, 2024 10:28:58 AM Attachments:SP23-N3.xlsx CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. Your message is ready to be sent with the following file or link attachments: SP23-N3.xlsx Note: To protect against computer viruses, e-mail programs may prevent sending or receiving certain types of file attachments. Check your e-mail security settings to determine how attachments are handled. STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION *All BOPE reports are due to the agency within 5 days of testing* Su bm it to :jim.regg@alaska.gov; AOGCC.Inspectors@alaska.gov; phoebe.brooks@alaska.gov Rig Owner: Rig No.:15 DATE: 4/26/24 Rig Rep.: Rig Email: Operator: Operator Rep.: Op. Rep Email: Well Name: PTD #2111270 Sundry #324-165 Operation: Drilling: Workover: X Explor.: Test: Initial: Weekly: X Bi-Weekly: Other: Rams:250-2500 Annular:250-2500 Valves:250-2500 MASP:712 MISC. INSPECTIONS: TEST DATA FLOOR SAFETY VALVES: Test Result/Type Test Result Quantity Test Result Housekeeping P Well Sign P Upper Kelly 1 P Permit On Location P Hazard Sec.P Lower Kelly 1 P Standing Order Posted P Misc.NA Ball Type 1 P Test Fluid Water Inside BOP 1 P FSV Misc 0 P BOP STACK:Quantity Size/Type Test Result MUD SYSTEM:Visual Alarm Stripper 1 NA Trip Tank P P Annular Preventer 1 13-5/8" 5k P Pit Level Indicators P P #1 Rams 1 2-7/8x5"P Flow Indicator P P #2 Rams 1 Blind/Shear P Meth Gas Detector P P #3 Rams 1 2-7/8x5"FP H2S Gas Detector P P #4 Rams 0 NA MS Misc 0 NA #5 Rams 0 NA #6 Rams 0 NA ACCUMULATOR SYSTEM: Choke Ln. Valves 2 3-1/8" 5k P Time/Pressure Test Result HCR Valves 4 3-1/8" 5k P System Pressure (psi)2975 P Kill Line Valves 4 3-1/8" 5k P Pressure After Closure (psi)2175 P Check Valve 0 NA 200 psi Attained (sec)9 P BOP Misc 0 NA Full Pressure Attained (sec)43 P Blind Switch Covers: All stations Yes CHOKE MANIFOLD:Bottle Precharge:P Quantity Test Result Nitgn. Bottles # & psi (Avg.): 10@4300 P No. Valves 15 P ACC Misc 0 NA Manual Chokes 1 P Hydraulic Chokes 1 P Control System Response Time:Time (sec) Test Result CH Misc 0 NA Annular Preventer 10 P #1 Rams 7 P Coiled Tubing Only:#2 Rams 7 P Inside Reel valves 0 NA #3 Rams 7 P #4 Rams 0 NA Test Results #5 Rams 0 NA #6 Rams 0 NA Number of Failures:1 Test Time: HCR Choke 2 P Repair or replacement of equipment will be made within 0 days. HCR Kill 2 P Remarks: AOGCC Inspection 24 hr Notice Yes Date/Time 4-24-24@09:09 Waived By Test Start Date/Time:4/25/2024 22:00 (date) (time)Witness Test Finish Date/Time:4/26/2024 4:30 BOPE Test Report Notify the AOGCC of repairs with written confirmation to: AOGCC.Inspectors@alaska.gov Austin McLeod Doyon All test performed with test plug, test Annular with 2-7/8" test jt. 250-2500psi/5min. Upper and lower preventors 2-7/8 and 5" test jts. 250-2500psi/5min.ea. Blind/Shear Preventor 250-2500psi/5min. Choke Valves 250-2500psi/5min. F/P Lower Preventor low pressure on 2-7/8", Cycled rams and retest - Good test. T.Shones / A.Carlo ENI S.Lawrence / M.Grubb Nikaitchuq SP23-N3 Test Pressure (psi): rig15@doyondrilling.com Form 10-424 (Revised 08/2022) 2024-0426_BOP_Doyon15_Nikaitchuq_SP23-N3 1. Operations Susp Well Insp Plug Perforations Fracture Stimulate Pull Tubing Operations shutdown Performed: Install Whipstock Perforate Other Stimulate Alter Casing Change Approved Program Mod Artificial Lift Perforate New Pool Repair Well Coiled Tubing Ops Other: _ESP Changeout Development Exploratory Stratigraphic Service 6. API Number: 7. Property Designation (Lease Number):8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071):10. Field/Pool(s): 11. Present Well Condition Summary: Total Depth measured 14,021 feet N/A feet true vertical 3,806 feet N/A feet Effective Depth measured 13,967 feet N/A feet true vertical 3,807 feet N/A feet Perforation depth Measured depth 6369-13967 feet True Vertical depth 3895-3807 feet Tubing (size, grade, measured and true vertical depth)2-7/8"L-80 5,908' 3,870' Packers and SSSV (type, measured and true vertical depth)N/A N/A N/A N/A 12. Stimulation or cement squeeze summary:N/A Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13a. Prior to well operation: Subsequent to operation: 13b. Pools active after work:Schrader Bluff 15. Well Class after work: Daily Report of Well Operations Exploratory Development Service Stratigraphic Copies of Logs and Surveys Run 16. Well Status after work: Oil Gas WDSPL Electronic Fracture Stimulation Data GSTOR GINJ SUSP SPLUG Sundry Number or N/A if C.O. Exempt: Authorized Name and Giorgio Iannucci 5/23/2024 Digital Signature with Date:Contact Name: Contact Email: Authorized Title:Well Operations Project Manager Contact Phone: 324-165 Sr Pet Eng: Slotted Sr Pet Geo:Sr Res Eng: WINJ WAG 82 Water-BblOil-Bbl 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. 9.625" Slotted 3700 Centerpoint Dr, Ste, 500, Anchorage, AK, 99503 3. Address: SP23-N3 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 0 Gas-Mcf MD 145 measured true vertical Packer Representative Daily Average Production or Injection Data Casing Pressure Tubing Pressure 4027 103 626 1571333 167 13.375" N/A 5. Permit to Drill Number:2. Operator Name 4. Well Class Before Work: ADL 391283, 3885833, 388574 Nikaitchuq/ Schrader Bluff Eni US Operating CO. Inc. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 211-127 50-629-23456-00-00 Size 160' measured TVD Production Liner 6,369' 7,598' Casing Structural 3,895' 5.5" 6,369' 13,967'3,807' Plugs Junk measured Length 160' 2,748' 160' Amjad Chaudhry amjad.chaudhry@eni.com 907-865-3379 2,748'2,480' Burst Collapse 2270 4,760 5,020 6,870 Conductor Surface Intermediate 20" p k ft t Fra O s 211 6. A G L PG , Form 10-404 Revised 10/2022 Due Within 30 days of Operations Submit in PDF format to aogcc.permitting@alaska.gov Giorgio Iannucci g By Grace Christianson at 9:54 am, May 28, 2024 DSR-5/29/24 2-7/8” 6.5 ppf Hyd563 Production TubingSP23-N3Dual Lateral Producer with ESP LiftNikaitchuq Field –Spy IslandAs Completed05/03/2024L1 - Baker SLXP Liner Hanger/Packer6,005' MD / 3,874' TVD~6,052' - 6,069' MD, Casing Exit Window2-7/8” cable clamps, for ESP Power Cable, (1) 3/8" Chem Inj Line 5,984' MD, 3872' TVD, 86º Inc – Bottom of Motor Centralizer Centrilift, 82stg Flex27, 20stg Ginpsh, 250HP motor Conventional ESPTD 8 3/4” 14,021' MD,3,806' TVD 91.5º Inc.Silver Bullet Ecc. Nose Guide Closed Shoe13,576/’ MD / 3,798' TVD TD 8 1/2” 13592' MD 3797' TVD92.52 Inc.5-½” 15.5/17 ppf L80 Slotted Liner Sealbore Receptacle4.75" ID4-½” x 9-5/8" RAMSeal Bore Diverterw/ 3.68" Seal BoreDrift 3.65"Bottom of Seal Assembly4 ½” Lateral Entry Module (LEM) w/ 3.68 Seal Bore, drift 3.63"Baker MLXP LinerHanger/Packer5-½” Silver Bullet Ecc. Nose Guide Shoe13,967' MD, 3807' TVD,91 5ºInc Interm. Casing 9-5/8", 40#6369' MD, 3895' TVD89ºIncZonal Isolation Swell PackersSwell Packer MD’s (ft):#1) 7,486#2 8,535#3) 9,417#4) 11,4266176' MD, 3,888 TVD - Baker SLXP Liner Hanger/PackerSurf. Casing13-3/8", 68 # BTC2,748' MD, 2,481' TVD49º Inc.5,908' MD/ 3,870' DGU 5,863' MD/ 3,862' TVD SLB XN Nipple Well Name: SP23-N3 OR Wellbore Name: SP23-N3 Well Code: 26152 Job: WORKOVER WCEI Level: LEVEL 3 Daily Report Date: 4/16/2024 Report #: 1 Page: 1 of 1 Well Header Permit/Concession N° ADL-388583 Operator ENI PETROLEUM Subsidiary ENI Petroleum Co. Inc. Initial Lahee Code DEVELOPMENT WELL Rotary Table Elevation (ft) 40.89 Ground Level (ft) First Flange (ft) 4.09 RKB - Base Flange (ft) 36.80 RKB - Tubing Spool (ft) 31.91 Rig Information Rig Name RIG 15 Contractor DOYON Rig Type LAND RIG Rig Num 0723 Daily Information Weather Overcast Temperature (°F) 36.0 Wind S @ 28 MPH Days LTI (days) 1,564.00 Days RI (days) POB 46.0 Daily Summary Operations 24h Forecast Finish rig up. Complete berming and check lists. Bring on 700 BBLS of 8.6 brine to pits. Rig up for well kill operations. Pressure test all lines. Bull head 65 BBLS of brine down tubing and 445 BBLS of 8.6 ppg brine down annulus A for well kill operations. Bleed and monitor well for 1 hour to confirm well is dead. Install BPV. Nipple down tree and nipple up BOPE. 24h Summary Spot and shim pit and pump room module. Skid rig floor to drill position. Spot and power up pump #3. Spot accumulator house. Take on water to rig. Spot cuttings box. Hooking up interconnects. Dress out mud pumps. Continue to berm around rig. Operation at 07.00 Bring on 700 BBLS of 8.6 brine to pits. Time Log Start Time End Time Dur (hr) Cum Dur (hr)Phase Opr. Act. Plan Oper. Descr. 00:00 05:00 5.00 5.00 W.O. A 1 P PJSM. Spot and shim pit and pump room module on SP23-N3. Spot and power up power up pump #3 module. 05:00 08:30 3.50 8.50 W.O. A 1 P PJSM. Make up flow line, steam, air, fuel and water interconnects between pits and sub base. Clear ice and snow from matting boards for spotting pump #3. Skid rig floor to drill position. 08:30 15:00 6.50 15.00 W.O. A 1 P Spot pump #3. Make up choke, flare bluy lines between pits and sub base. Circulate steam to pits, pump room module and rig floor. Make up high pressure mud line and secondary kill line between sub base and pump room. Spot 8’ transition suit case at wheel well. Lower breeze way and install grating for walk way. Start berming up around rig. Install steam traps on rig floor. Take on water to boiler hot well. 15:00 18:00 3.00 18.00 W.O. A 1 P Plug in and power up pump #3 module. Continue to berm around rig. Lay Herkulite and spot accumulator house. Rig up Pump room #3 mud and suction lines. Hook up mud lines to interconnect. Take on water to rig. Spot cuttings box. 18:00 00:00 6.00 24.00 W.O. A 1 P Plug in shop to rig. Dress out mud pumps, re- Install valves, springs, plugs and caps. Berm up around rig. Set stairs for accumulator house. Berm up around accumulator house. Install stairs on pump #3. Spot scissor lift ramp. Hook up brine line and slop tank inter-connects. Hook up water lines in rig. Remove chains on torque tube. Daily Contacts Position Contact Name Company Title Email Office Mobile Company Representative Bruce Simonson ASRC Energy Services Drilling Supv. siddrilling@eni.com 907-685-0715 Company Representative Mike Grubb ASRC Energy Services Drilling Supv. siddrilling@eni.com 907-685-0715 Company Representative Yelyzaveta Saprykina ASRC Energy Services Rig Clerk AKRigClerksDoyon15@eni.com 907-685-0722 Safety Representative Levi Karns ASRC Energy Services HSE Levi.Karns@external.eni.com 907-685-0721 Safety Representative John Lettow Doyon Drilling HSE rig15@doyondrilling.com 907-685-0796 Tool Push Ted Kruger Doyon Drilling Tour Pusher rig15@doyondrilling.com 907-685-0716 Tool Push Tom Shones Doyon Drilling Tool Pusher rig15@doyondrilling.com 907-685-0727 Last Casing Seat Cas. Type OD (in) ID (in) Grade Top (ftKB) Bottom (ftKB) TVD Bot. (ftKB) Landing Date LINER 5 1/2 4.95 L80 -13,937.1 13,996.9 3,786.6 1/31/2012 Well Name: SP23-N3 OR Wellbore Name: SP23-N3 Well Code: 26152 Job: WORKOVER WCEI Level: LEVEL 3 Daily Report Date: 4/17/2024 Report #: 2 Page: 1 of 1 Well Header Permit/Concession N° ADL-388583 Operator ENI PETROLEUM Subsidiary ENI Petroleum Co. Inc. Initial Lahee Code DEVELOPMENT WELL Rotary Table Elevation (ft) 40.89 Ground Level (ft) First Flange (ft) 4.09 RKB - Base Flange (ft) 36.80 RKB - Tubing Spool (ft) 31.91 Rig Information Rig Name RIG 15 Contractor DOYON Rig Type LAND RIG Rig Num 0723 Daily Information Weather Overcast Temperature (°F) 19.0 Wind NE @ 22 MPH Days LTI (days) 1,565.00 Days RI (days) POB 49.0 Daily Summary Operations 24h Forecast Finish nippling up BOPE. Rig up and test BOPE to 2500 psi with 2-7/8” and 5” test joints. Pull back pressure valve. Rig down test equipment. Rig up for de-completion. 24h Summary Finish rig up. Complete berming and check lists. Bring on 700 BBLS of 8.6 brine to pits. Rig up and perform well kill operations. Monitor well to confirm dead. Install Back pressure valve. Nipple down tree. Start nipple up BOPE. Operation at 07.00 Finish nippling up BOPE. Time Log Start Time End Time Dur (hr) Cum Dur (hr)Phase Opr. Act. Plan Oper. Descr. 00:00 06:00 6.00 6.00 W.O. A 1 P Complete berming around rig. Complete landing around rig. Change out suction seal in pit #5. Make up high pressure mud line and choke line under rig floor. Raise supports in pipe shed. Set pipe stops supports on pump #3. Plug in skate and cattle chute lights. Run accumulator lines to wheel well. Turn on water to pits, pump room and sub base. Plug in scissor lift. 06:00 10:00 4.00 10.00 W.O. M 1 P PJSM, pressure test suit case lines. Receive 700 BBLS of 8.6 ppg brine. SIMOPS: Load 120 4.5” tubing joints in pipe shed. Vault hand Install pump in flange on annulus A. Rig up high pressure hoses for bull head well kill operation. 10:00 12:00 2.00 12.00 W.O. M 1 P Prime mud pumps 1, 2 and #3. Install blank flange on primary and secondary. Pressure test high pressure mud lines to 3500 psi, good test. Continue loading 4.5” tubing in pipe shed. 12:00 14:00 2.00 14.00 W.O. M 1 P Line up on secondary kill line. Rig up 2” hose to bleed tank. Install covers on Suit cases. Continue loading 4.5” tubing in pipe shed. 14:00 18:00 4.00 18.00 W.O. M 9 P Pressure test lines on secondary kill line and line up on tree. Pump down tubing at 3 BPM, 0 PSI. Pumped a total of 65 bbls of 8.6 ppg brine down tubing. Bleed off and shut in. Rig up on annulus A at 3 BPM, at 230 psi, pumping a total of 445 BBLS of 8.6 ppg brine. Bled off and shut in to monitor. 18:00 21:00 3.00 21.00 W.O. M 1 P Monitor tubing and annulus A. Bleed off 116 psi off annulus, tubing on vacuum. Shut in and monitor. Annulus A built several psi, tubing slight pressure. Bleed back off tubing and annulus. Monitor well for one hour, pressure at 0 on tubing and vacuum on annulus A. 21:00 23:00 2.00 23.00 W.O. C 20 P PJSM. Set back pressure valve. Nipple down tree. Clean and inspect multibowl and tubing hanger. Install blanking plug. Prepare top of well head for riser installation. 23:00 00:00 1.00 24.00 W.O. C 5 P Nipple up BOPE. Install high pressure riser. Set stack on riser. Note: 24 Hour Loss of 8.6 ppg Brine = 84.61 BBLs Total Loss of 8.6 ppg Brine = 84.61 BBLs Daily Contacts Position Contact Name Company Title Email Office Mobile Company Representative Bruce Simonson ASRC Energy Services Drilling Supv. siddrilling@eni.com 907-685-0715 Company Representative Mike Grubb ASRC Energy Services Drilling Supv. siddrilling@eni.com 907-685-0715 Company Representative Yelyzaveta Saprykina ASRC Energy Services Rig Clerk AKRigClerksDoyon15@eni.com 907-685-0722 Safety Representative Levi Karns ASRC Energy Services HSE Levi.Karns@external.eni.com 907-685-0721 Safety Representative John Lettow Doyon Drilling HSE rig15@doyondrilling.com 907-685-0796 Tool Push Ted Kruger Doyon Drilling Tour Pusher rig15@doyondrilling.com 907-685-0716 Tool Push Tom Shones Doyon Drilling Tool Pusher rig15@doyondrilling.com 907-685-0727 Last Casing Seat Cas. Type OD (in) ID (in) Grade Top (ftKB) Bottom (ftKB) TVD Bot. (ftKB) Landing Date LINER 5 1/2 4.95 L80 -13,937.1 13,996.9 3,786.6 1/31/2012 Well Name: SP23-N3 OR Wellbore Name: SP23-N3 Well Code: 26152 Job: WORKOVER WCEI Level: LEVEL 3 Daily Report Date: 4/18/2024 Report #: 3 Page: 1 of 1 Well Header Permit/Concession N° ADL-388583 Operator ENI PETROLEUM Subsidiary ENI Petroleum Co. Inc. Initial Lahee Code DEVELOPMENT WELL Rotary Table Elevation (ft) 40.89 Ground Level (ft) First Flange (ft) 4.09 RKB - Base Flange (ft) 36.80 RKB - Tubing Spool (ft) 31.91 Rig Information Rig Name RIG 15 Contractor DOYON Rig Type LAND RIG Rig Num 0723 Daily Information Weather Overcast Temperature (°F) 20.3 Wind NE @ 28 MPH Days LTI (days) 1,566.00 Days RI (days) POB 46.0 Daily Summary Operations 24h Forecast Finish testing BOPE to 250/2500 psi with 5” test joint blanking plug and back pressure valve. Rig down test equipment. Rig up for de-completion. Make up landing joint and pull hanger to floor. Lay down tubing hanger. Pull out of hole with 4.5” completion tubing. 24h Summary Finish nippling up BOPE. Rig up and test BOPE to 250/2500 psi with 2-7/8” and 5” test joint. Operation at 07.00 Rigging up for de-completion. Time Log Start Time End Time Dur (hr) Cum Dur (hr)Phase Opr. Act. Plan Oper. Descr. 00:00 03:00 3.00 3.00 W.O. C 20 P Continue to nipple up BOPE. Torque studs on 13-3/8” flange to 2000 ft/lbs. Nipple up primary and secondary kill HCR blocks. SIMOPS: Make up accumulator hoses in wheel well. Clean 4.5” tubing in pipe shed. Obtain RKB measurements. 03:00 09:00 6.00 9.00 W.O. C 5 P Continue to nipple up BOP make up primary and secondary choke and kill lines, and install accumulator hoses. 09:00 12:00 3.00 12.00 W.O. C 5 P Install SRL’s, make up flow nipple and flow line, continue to install accumulator hoses, install rig floor drain hoses, install clam shell in rig floor drip pan, and secure BOP stack. 12:00 20:00 8.00 20.00 W.O. C 20 P Continue to install riser and flow line. Install 2” HP hose to A annulus and begin filling annulus at 10 BPH of 8.6 PPG NaCl/ 3% KCL brine inhibited with Biocide. Make up 2-7/8” test joint and cross overs for FOSV and dart valve. SIMOPS: cleaning 4.5” tubing in pipe shed. Conduct pre-spud derrick inspection. 20:00 00:00 4.00 24.00 W.O. C 12 P Testing BOPE. Test with 2-7/8” test joint 250/2500 psi for 5 Minutes each. Test annular, upper and lower variable rams 2-7/8” X 5”. Test Choke manifold valves 1, 2, 5, 6, 7, 8, 9, 10, 11, 12, 13, 14, and 15. Test upper and lower IBOP. Test primary and secondary Demco kill valves, Primary and secondary HCR kill valves and primary and secondary manual Kill valves. All good test. Witness waived by AOGCC rep Guy Cook. Continue filling annulus at 10 BPH of 8.6 PPG NaCl/ 3% KCL brine inhibited with Biocide. Note: 24 Hour Loss of 8.6 ppg Brine = 18.06 BBLs Total Loss of 8.6 ppg Brine = 102.67 BBLs Daily Contacts Position Contact Name Company Title Email Office Mobile Company Representative Steve Lawrence ASRC Energy Services Drilling Supv. siddrilling@eni.com 907-685-0715 Company Representative Mike Grubb ASRC Energy Services Drilling Supv. siddrilling@eni.com 907-685-0715 Company Representative Yelyzaveta Saprykina ASRC Energy Services Rig Clerk AKRigClerksDoyon15@eni.com 907-685-0722 Safety Representative Levi Karns ASRC Energy Services HSE Levi.Karns@external.eni.com 907-685-0721 Safety Representative John Lettow Doyon Drilling HSE rig15@doyondrilling.com 907-685-0796 Tool Push Ted Kruger Doyon Drilling Tour Pusher rig15@doyondrilling.com 907-685-0716 Tool Push Tom Shones Doyon Drilling Tool Pusher rig15@doyondrilling.com 907-685-0727 Last Casing Seat Cas. Type OD (in) ID (in) Grade Top (ftKB) Bottom (ftKB) TVD Bot. (ftKB) Landing Date LINER 5 1/2 4.95 L80 -13,937.1 13,996.9 3,786.6 1/31/2012 Well Name: SP23-N3 OR Wellbore Name: SP23-N3 Well Code: 26152 Job: WORKOVER WCEI Level: LEVEL 3 Daily Report Date: 4/19/2024 Report #: 4 Page: 1 of 1 Well Header Permit/Concession N° ADL-388583 Operator ENI PETROLEUM Subsidiary ENI Petroleum Co. Inc. Initial Lahee Code DEVELOPMENT WELL Rotary Table Elevation (ft) 40.89 Ground Level (ft) First Flange (ft) 4.09 RKB - Base Flange (ft) 36.80 RKB - Tubing Spool (ft) 31.91 Rig Information Rig Name RIG 15 Contractor DOYON Rig Type LAND RIG Rig Num 0723 Daily Information Weather Overcast Temperature (°F) 28.6 Wind E @ 12 MPH Days LTI (days) 1,567.00 Days RI (days) POB 47.0 Daily Summary Operations 24h Forecast Load 2-7/8” HT PAC work string in pipe shed and process. Rig up for 2-7/8” work string. Preform tubing debris clean out with work string. Confirm plug has been removed by bull head down tubing. 24h Summary Finish testing BOPE to 250/2500 psi with 2-7/8” and 5” test joint. Pull blanking plug and back pressure valve. Rig down test equipment. Rig up for de-completion. Make up landing joint and pull hanger to floor. Lay down tubing hanger. Pull out of hole with 4.5” completion tubing to drilled holes in tubing. Install tubing hanger and land out. Rig up to attempt to pump down tubing. Operation at 07.00 Run in hole with 2-7/8" drill pipe. Time Log Start Time End Time Dur (hr) Cum Dur (hr)Phase Opr. Act. Plan Oper. Descr. 00:00 05:00 5.00 5.00 W.O. C 12 P Continue testing BOPE. Test 2-7/8” floor valve and dart valve. Test Choke manifold valves 3 and 4. Test blind ram. Function test hydraulic and manual choke. Test annular, upper and lower Variable rams ( 2-7/8” X 5” ) with 5” test joint. Test gas alarms. Test PVT and flow alarms. Preform accumulator draw down test. Starting pressure=2950 psi, after function=2175 psi, 200 psi increase=9 seconds, Full recovery=43 seconds, Nitrogen back up 10 bottles with 4200 psi average. All test good. Continue filling annulus at 10 BPH of 8.6 PPG NaCl/ 3% KCL brine inhibited with Biocide. 05:00 06:30 1.50 6.50 W.O. C 20 P Rig down test equipment. Pull 5” test joint and blanking plug, blow down choke and surface equipment. Continue filling annulus at 10 BPH of 8.6 PPG NaCl/ 3% KCL brine inhibited with Biocide. 06:30 08:30 2.00 8.50 W.O. L 5 P PJSM. Install ESP cable and capillary line shears in the derrick. Installed anti pollution hose on ESP cable sheave. Continue filling annulus at 10 BPH of 8.6 PPG NaCl/ 3% KCL brine inhibited with Biocide. 08:30 10:30 2.00 10.50 W.O. L 20 P PJSM. Stage GBR equipment on the rig floor, rig up power tongs and dress handling equipment. Make up crossover on bottom of FOSV, lay liner to contain ESP cable drips while de-completing, and set concrete anchor for capillary sheave. Continue filling annulus at 10 BPH of 8.6 PPG NaCl/ 3% KCL brine inhibited with Biocide. 10:30 12:00 1.50 12.00 W.O. L 5 P PJSM. Vault remove BPV, make up 4.5” landing joint, and begin to back out LDS. Continue filling annulus at 10 BPH of 8.6 PPG NaCl/ 3% KCL brine inhibited with Biocide. 12:00 14:00 2.00 14.00 W.O. L 20 P PJSM. Back out remainder of LDS, pull on tubing hanger with the tubing hanger coming free at 200K, and with a free travelling up weight of 130K. Remove ESP cable and cap lines, plug cap line ports, and remove the tubing hanger. Continue filling annulus at 10 BPH of 8.6 PPG NaCl/ 3% KCL brine inhibited with Biocide. 14:00 15:00 1.00 15.00 W.O. L 25 U Trouble shoot spooling unit power issue. Rig up to portable generator. Continue filling annulus at 10 BPH of 8.6 PPG NaCl/ 3% KCL brine inhibited with Biocide. 15:00 20:00 5.00 20.00 W.O. L 20 P Lay down 4.5” 12.6 ppf, L-80, HYD-563 tubing to perf joint, lay down 80 joints to 3314’. No fluid or sand visible down tubing. Continue filling annulus at 10 BPH of 8.6 PPG NaCl/ 3% KCL brine inhibited with Biocide. 20:00 21:00 1.00 21.00 W.O. L 9 P Rig up head pin and attempt to pump down tubing. Pressure reaching 500 psi with 2 BBLS 8.6 brine pumped . Bled pressure off and rig down pump in sub assembly. Prepare pipe shed to load 2-7/8” HT PAC work string. Continue filling annulus at 10 BPH of 8.6 PPG NaCl/ 3% KCL brine inhibited with Biocide. 21:00 22:00 1.00 22.00 W.O. L 20 P Cut ESP cable and cap tubes, secure to tubing. Loading 2-7/8” work string into pipe shed. Continue filling annulus at 10 BPH of 8.6 PPG NaCl/ 3% KCL brine inhibited with Biocide. 22:00 23:30 1.50 23.50 W.O. L 20 P Make up landing joint, cross overs and tubing hanger. Land out tubing hanger and test seals to 5000 psi for 10 minutes, good test. Loading 2-7/8” work string into pipe shed. Continue filling annulus at 10 BPH of 8.6 PPG NaCl/ 3% KCL brine inhibited with Biocide. 23:30 00:00 0.50 24.00 W.O. L 1 P Rig up to pump down tubing. Loading 2-7/8” work string into pipe shed. Continue filling annulus at 10 BPH of 8.6 PPG NaCl/ 3% KCL brine inhibited with Biocide. Note: 24 Hour Loss of 8.6 ppg Brine = 153.98 BBLs Total Loss of 8.6 ppg Brine = 256.65 BBLs Daily Contacts Position Contact Name Company Title Email Office Mobile Company Representative Steve Lawrence ASRC Energy Services Drilling Supv. siddrilling@eni.com 907-685-0715 Company Representative Mike Grubb ASRC Energy Services Drilling Supv. siddrilling@eni.com 907-685-0715 Company Representative Yelyzaveta Saprykina ASRC Energy Services Rig Clerk AKRigClerksDoyon15@eni.com 907-685-0722 Safety Representative Levi Karns ASRC Energy Services HSE Levi.Karns@external.eni.com 907-685-0721 Safety Representative John Lettow Doyon Drilling HSE rig15@doyondrilling.com 907-685-0796 Tool Push Ted Kruger Doyon Drilling Tour Pusher rig15@doyondrilling.com 907-685-0716 Tool Push Tom Shones Doyon Drilling Tool Pusher rig15@doyondrilling.com 907-685-0727 Last Casing Seat Cas. Type OD (in) ID (in) Grade Top (ftKB) Bottom (ftKB) TVD Bot. (ftKB) Landing Date LINER 5 1/2 4.95 L80 -13,937.1 13,996.9 3,786.6 1/31/2012 Well Name: SP23-N3 OR Wellbore Name: SP23-N3 Well Code: 26152 Job: WORKOVER WCEI Level: LEVEL 3 Daily Report Date: 4/20/2024 Report #: 5 Page: 1 of 1 Well Header Permit/Concession N° ADL-388583 Operator ENI PETROLEUM Subsidiary ENI Petroleum Co. Inc. Initial Lahee Code DEVELOPMENT WELL Rotary Table Elevation (ft) 40.89 Ground Level (ft) First Flange (ft) 4.09 RKB - Base Flange (ft) 36.80 RKB - Tubing Spool (ft) 31.91 Rig Information Rig Name RIG 15 Contractor DOYON Rig Type LAND RIG Rig Num 0723 Daily Information Weather Clear Temperature (°F) 17.2 Wind W @ 8 MPH Days LTI (days) 1,568.00 Days RI (days) POB 49.0 Daily Summary Operations 24h Forecast Preform tubing debris clean out with work string from 2175’ to ESP at 2612’. Pump and circulate clean. Pull out of hole with cleanout assembly and lay down same. Make up landing joint and attempt to pump down through ESP pump. Rig up equipment and resume de-completion. 24h Summary Pressure up tubing to 1500 psi, unable to pump through. Load 2-7/8” HT PAC work string in pipe shed and process. Rig up for 2-7/8” work string. Preform tubing debris clean out with work string. Tripping and washing down as needed, some areas with bridges, from surface to 2175’ inside 4.5” tubing. Operation at 07.00 Laying down 2-7/8" drill pipe. Time Log Start Time End Time Dur (hr) Cum Dur (hr)Phase Opr. Act. Plan Oper. Descr. 00:00 01:00 1.00 1.00 W.O. L 20 P Rig up to pump down tubing. Bring pressure up to 1500 psi, no bleed off. Bleed off pressure and observe some oil on fluid in stack, draining down penetrator hole. Loading 2-7/8” work string into pipe shed. Continue filling annulus at 10 BPH of 8.6 PPG NaCl/ 3% KCL brine inhibited with Biocide. 01:00 03:00 2.00 3.00 W.O. L 25 U Trouble shoot Scissor lift. Simops: Process the 65 joints of HT PAC pipe, work string. 03:00 04:00 1.00 4.00 W.O. M 1 P Stage handing equipment on rig floor. Power up GRR tongs. 04:00 12:00 8.00 12.00 W.O. M 4 P PJSM. Run in hole with 2.875” HT PAC drill pipe and mule shoe from surface to 131’ (3404’). Circulate down drill pipe and back up 4.5” tubing at 1.5 BPM at 66 psi. Fluid draining into annulus A through Penetrator hole. Continue to run in hole to 728’, (4001’) and break circulation at 1.5 BPM, 8.6 PPG NaCl/ 3%KCL brine inhibited with biocide. 740 PSI to break circulation falling off to 0 PSI, pump total of 6 BBLwith clean returns. 12:00 18:00 6.00 18.00 W.O. M 4 P Continue to trip in the hole with 2 7/8” HT PAC, tagged at 1096’ (4369’) make up top drive and wash down to 1113’ (4386’), at 1.5 BPM, 70 PSI, and broke through sand bridge. Continue to trip in hole with 2 7/8” HT PAC cleanout assembly to 1370’ (4643’) tagged bridge and washed down to 1619’ (4892’). 18:00 19:00 1.00 19.00 W.O. M 25 U GBR having trouble with power tongs biting on HT PAC pipe, unable to torque up. Trouble shoot tongs. Pipe slightly worn. 19:00 19:30 0.50 19.50 W.O. M 1 P PJSM. Pick up HT-14 manual tongs and rig up. 19:30 00:00 4.50 24.00 W.O. M 4 P Continue to trip in the hole with 2 7/8” HT PAC, from 1619’ to 1653’. Wash down at 1.6 BPM from 1653’ (4926’) to 1685’ (4957’). Trip in hole to 1716’ (4989’) and wash down to 1782’ (5050’).Trip in hole to 1908’ (5181) and wash down due to taking a little weight, to 1940’ (5213’). Trip in hole to 1958’ (5231’) and wash and work down to 2175’ (5448’). Note: 24 Hour Loss of 8.6 ppg Brine = 266.61 BBLs Total Loss of 8.6 ppg Brine = 523.26 BBLs Daily Contacts Position Contact Name Company Title Email Office Mobile Company Representative Steve Lawrence ASRC Energy Services Drilling Supv. siddrilling@eni.com 907-685-0715 Company Representative Mike Grubb ASRC Energy Services Drilling Supv. siddrilling@eni.com 907-685-0715 Company Representative Yelyzaveta Saprykina ASRC Energy Services Rig Clerk AKRigClerksDoyon15@eni.com 907-685-0722 Safety Representative Levi Karns ASRC Energy Services HSE Levi.Karns@external.eni.com 907-685-0721 Safety Representative John Lettow Doyon Drilling HSE rig15@doyondrilling.com 907-685-0796 Tool Push Ted Kruger Doyon Drilling Tour Pusher rig15@doyondrilling.com 907-685-0716 Tool Push Tom Shones Doyon Drilling Tool Pusher rig15@doyondrilling.com 907-685-0727 Last Casing Seat Cas. Type OD (in) ID (in) Grade Top (ftKB) Bottom (ftKB) TVD Bot. (ftKB) Landing Date LINER 5 1/2 4.95 L80 -13,937.1 13,996.9 3,786.6 1/31/2012 Well Name: SP23-N3 OR Wellbore Name: SP23-N3 Well Code: 26152 Job: WORKOVER WCEI Level: LEVEL 3 Daily Report Date: 4/21/2024 Report #: 6 Page: 1 of 1 Well Header Permit/Concession N° ADL-388583 Operator ENI PETROLEUM Subsidiary ENI Petroleum Co. Inc. Initial Lahee Code DEVELOPMENT WELL Rotary Table Elevation (ft) 40.89 Ground Level (ft) First Flange (ft) 4.09 RKB - Base Flange (ft) 36.80 RKB - Tubing Spool (ft) 31.91 Rig Information Rig Name RIG 15 Contractor DOYON Rig Type LAND RIG Rig Num 0723 Daily Information Weather Clear Temperature (°F) 2.1 Wind W @ 17 MPH Days LTI (days) 1,569.00 Days RI (days) POB 49.0 Daily Summary Operations 24h Forecast Pipe management, loading and processing 5” drill pipe, 2-7/8” PH6 tubing and Baker VAC’s tool. Pick up VACs tool and 1000’ of 2-7/8” PH6 and run in hole with 5” drill pipe. 24h Summary Continue to wash down to top of ESP pump and circulate clean from 2175’ to ESP at 2590’. Pull out of hole with cleanout assembly and lay down to pipe shed. Make up landing joint and attempt to pump down through ESP pump. Rig up equipment and resume de-completion laying down tubing to the pipe shed from 2562’ to 79’. Lay down ESP assembly from 79’ to surface. Clear floor, spool back ESP cable and cap tube to spooling unit. Operation at 07.00 Loading and processing 5” drill pipe. Time Log Start Time End Time Dur (hr) Cum Dur (hr)Phase Opr. Act. Plan Oper. Descr. 00:00 02:30 2.50 2.50 W.O. M 4 P Continue to trip in the hole with 2-7/8” HT PAC, from 2175’ (5448’) to tag at 2590’ (5863’). Take weight from 2175’ to 2490’, from 2490’ to 2590’ much firmer sands.Tagged twice at 2590’ with 6K while pumping 2 BPM at 300 psi. UW=81K, DW=83K, 2 -7/8” work string drifted with 1.125 drift. 02:30 04:00 1.50 4.00 W.O. M 7 P Circulate bottoms up at 2.5 BPM at 480 psi with 8.6 PPG NaCl/ 3% KCL brine inhibited with Biocide. Circulated 40 BBL deep clean pill at 2.5 BPM at 450 psi. Let soak for 15 minutes. Then Circulated bottoms up at 2.5 BPM at 300 psi with 8.6 PPG NaCl/ 3% KCL brine inhibited with Biocide. 04:00 09:00 5.00 9.00 W.O. M 4 P PJSM. Pull out of hole with 2-7/8” HT PAC pipe from 2590’ to surface laying down to pipe shed using manual HT-14 tongs. Continue to add 10 BPH plus metal displacement to A Annulus, with 8.6 PPG NaCl / 3% KCL brine inhibited with biocide. 09:00 11:00 2.00 11.00 W.O. M 20 P PJSM. Rig down HT14 tongs, change out handling equipment to 4.5”. Make up landing joint and attempt to pump through ESP without success, 1.5 BBL, 1500 PSI. Clean and clear rig floor with Baker Centerlift and GBR rigging up equipment. 11:00 12:30 1.50 12.50 W.O. L 20 P Pull tubing hanger to rig floor 140K to free tubing free, with a free travelling UW of 106K. Lay down the tubing hanger, swivel and the landing joint. Baker Centerlift attach ESP cable and cap lines to lines in the derrick going over sheaves to spooling unit. 12:30 18:00 5.50 18.00 W.O. L 4 P PJSM with all hands, pulling out of hole wet with ESP completion, laying down tubing, focusing on correct PPE, line of fire, and housekeeping. Pull out of hole wet with ESP completion, laying down tubing to the pipe shed from 2562’ to 79’, adding 10 BPH plus metal displacement to A annulus, with 8.6 PPG NaCl / 3% KCL brine inhibited with biocide. 18:00 21:30 3.50 21.50 W.O. L 5 P Lay down ESP assembly from 79’ to surface. Found discharge cap tube was plugged with fine sand. Disconnecting discharge from first pump had fine powder sand compacted on top of pump. Slightly pressured with clean brine at the connection. Top of pump unable to turn shaft, bottom of pump spun easily. Second pump top was able to turn shaft on both ends. Fine sand build up on top of first seal at bottom of intake. Checked oil in seals, top of first seal out of hole had brine on top and oil on bottom. Second seal assembly out of hole had clean oil in top and bottom. Clamps recovered=152 total, Cross clamps=141, Bird cage pump clamps=4, 5.38 pump clamps=2, Protectrolizer clamps=2, 4.5” cross collar clamp=1, 4.5” mid joint cpamp=1. Adding 10 BPH with 8.6 PPG NaCl / 3% KCL brine inhibited with biocide. 21:30 00:00 2.50 24.00 W.O. L 1 P Clear floor of clamps and non-essential tools. Spool up ESP cable and cap tubing to spooling unit. Clear floor of ESP components. Remove and lay down elephant trunk from sheave in derrick. Adding 10 BPH with 8.6 PPG NaCl / 3% KCL brine inhibited with biocide. Note: 24 Hour Loss of 8.6 ppg Brine = 489.89 BBLs Total Loss of 8.6 ppg Brine = 1013.15 BBLs Daily Contacts Position Contact Name Company Title Email Office Mobile Company Representative Steve Lawrence ASRC Energy Services Drilling Supv. siddrilling@eni.com 907-685-0715 Company Representative Mike Grubb ASRC Energy Services Drilling Supv. siddrilling@eni.com 907-685-0715 Company Representative Yelyzaveta Saprykina ASRC Energy Services Rig Clerk AKRigClerksDoyon15@eni.com 907-685-0722 Safety Representative Levi Karns ASRC Energy Services HSE Levi.Karns@external.eni.com 907-685-0721 Safety Representative John Lettow Doyon Drilling HSE rig15@doyondrilling.com 907-685-0796 Tool Push Ted Kruger Doyon Drilling Tour Pusher rig15@doyondrilling.com 907-685-0716 Tool Push Tom Shones Doyon Drilling Tool Pusher rig15@doyondrilling.com 907-685-0727 Last Casing Seat Cas. Type OD (in) ID (in) Grade Top (ftKB) Bottom (ftKB) TVD Bot. (ftKB) Landing Date LINER 5 1/2 4.95 L80 -13,937.1 13,996.9 3,786.6 1/31/2012 Well Name: SP23-N3 OR Wellbore Name: SP23-N3 Well Code: 26152 Job: WORKOVER WCEI Level: LEVEL 3 Daily Report Date: 4/22/2024 Report #: 7 Page: 1 of 1 Well Header Permit/Concession N° ADL-388583 Operator ENI PETROLEUM Subsidiary ENI Petroleum Co. Inc. Initial Lahee Code DEVELOPMENT WELL Rotary Table Elevation (ft) 40.89 Ground Level (ft) First Flange (ft) 4.09 RKB - Base Flange (ft) 36.80 RKB - Tubing Spool (ft) 31.91 Rig Information Rig Name RIG 15 Contractor DOYON Rig Type LAND RIG Rig Num 0723 Daily Information Weather Overcast Temperature (°F) 8.1 Wind NE @ 18 MPH Days LTI (days) 1,570.00 Days RI (days) POB 49.0 Daily Summary Operations 24h Forecast Continue to single in hole to above liner top. Wash with VACS tool snorkel string from liner top to ~7035’, tag with VACs tool cross over sub with 5K. Pull out of hole standing back 5” drill pipe in derrick. Lay down and inspect VACS tool, magnets and 2-7/8” snorkel tubing. 24h Summary Pipe management, loading and processing 5” drill pipe, 2-7/8” PH6 tubing and Baker VAC’s tool. Install wear ring. Pick up VACs tool and 1035’ of 2-7/8” PH6 and run in hole with 11 stands of 5” drill pipe. Pull out of hole and rack back stands for wash down liner top with Vacs tool. Single back in hole with 5” drill pipe to 2500’. Operation at 07.00 Wash with VAC's tool. Time Log Start Time End Time Dur (hr) Cum Dur (hr)Phase Opr. Act. Plan Oper. Descr. 00:00 02:30 2.50 2.50 W.O. M 1 P Pipe management: Move pump boxes, test joints, mouse hole and tubing from short side of pipe shed to load TT525 drill pipe and 2-7/8” PH6 in short side of pipe shed. SIMOPS: continue to clean on rig floor. Adding 10 BPH with 8.6 PPG NaCl / 3% KCL brine inhibited with biocide. 02:30 09:30 7.00 9.50 W.O. M 20 P PJSM. Load 194 joints of TT525 drill pipe in the pipe shed and process same. SIMOPS: Continue housekeeping on rig floor. Perform MP2 maintenance on air compressor and air dryer. 09:30 11:00 1.50 11.00 W.O. M 20 P PJSM. Load 35 joints of 2.875” PH6 work string tubing in pipe shed and process same. SIMOPS: Stage Baker jars, bumper sub, and handling tools on rig floor. 11:00 11:30 0.50 11.50 W.O. M 5 P PJSM. Install 9” ID wear bushing, per Vault. 11:30 12:00 0.50 12.00 W.O. M 20 P Stage magnets on the rig floor and change out handling equipment to 2-7/8”. 12:00 16:00 4.00 16.00 W.O. M 4 P PJSM. Rig up GBR tools, pick up bent 2-3/8” pup with 2.9375” OD shoe on bottom, along with 2 flapper subs. Pick up and make up 2.875” PH6 work string , bent joint and mule shoe, run in hole to 1035’. 16:00 19:00 3.00 19.00 W.O. M 5 P Make up VACs tool assembly. Make up triple connect, wash pipe, VACs assembly, 2 magnets, oil Jars and cross over. Run in hole from 1035’ to 1166’. 19:00 21:00 2.00 21.00 W.O. M 4 P Single in hole with VACs tool, 2-7/8” PH6 snorkel pipe on TT525 drill pipe from 1166’ to 2347’ MD, 33 joints. 21:00 22:00 1.00 22.00 W.O. M 4 P Pull out of hole from 2347’ to 1321’, racking back 11 stands in derrick of TT525 drill pipe to circulate down with stands when vacuuming with VACs tool from liner top down L-1 for clean out run. 22:00 00:00 2.00 24.00 W.O. M 4 P Single in hole with VACs tool, 2-7/8” PH6 snorkel pipe on TT525 drill pipe from 1321’ to 2500’ MD, 33 joints. Note: 24 Hour Loss of 8.6 ppg Brine = 240.5 BBLs Total Loss of 8.6 ppg Brine = 1253.65 BBLs Daily Contacts Position Contact Name Company Title Email Office Mobile Company Representative Steve Lawrence ASRC Energy Services Drilling Supv. siddrilling@eni.com 907-685-0715 Company Representative Mike Grubb ASRC Energy Services Drilling Supv. siddrilling@eni.com 907-685-0715 Company Representative Yelyzaveta Saprykina ASRC Energy Services Rig Clerk AKRigClerksDoyon15@eni.com 907-685-0722 Safety Representative Levi Karns ASRC Energy Services HSE Levi.Karns@external.eni.com 907-685-0721 Safety Representative John Lettow Doyon Drilling HSE rig15@doyondrilling.com 907-685-0796 Tool Push Ted Kruger Doyon Drilling Tour Pusher rig15@doyondrilling.com 907-685-0716 Tool Push Tom Shones Doyon Drilling Tool Pusher rig15@doyondrilling.com 907-685-0727 Last Casing Seat Cas. Type OD (in) ID (in) Grade Top (ftKB) Bottom (ftKB) TVD Bot. (ftKB) Landing Date LINER 5 1/2 4.95 L80 -13,937.1 13,996.9 3,786.6 1/31/2012 Well Name: SP23-N3 OR Wellbore Name: SP23-N3 Well Code: 26152 Job: WORKOVER WCEI Level: LEVEL 3 Daily Report Date: 4/23/2024 Report #: 8 Page: 1 of 1 Well Header Permit/Concession N° ADL-388583 Operator ENI PETROLEUM Subsidiary ENI Petroleum Co. Inc. Initial Lahee Code DEVELOPMENT WELL Rotary Table Elevation (ft) 40.89 Ground Level (ft) First Flange (ft) 4.09 RKB - Base Flange (ft) 36.80 RKB - Tubing Spool (ft) 31.91 Rig Information Rig Name RIG 15 Contractor DOYON Rig Type LAND RIG Rig Num 0723 Daily Information Weather Overcast Temperature (°F) 11.3 Wind NE @ 21 MPH Days LTI (days) 1,571.00 Days RI (days) POB 50.0 Daily Summary Operations 24h Forecast Run in hole with Mill cleanout run, work through tight spot at 4624’. Pump down to 6000’ just above liner top. Pull out of hole lay down BHA. Pick up VACs tool and snorkel. Wash with VACS tool snorkel string from 4600’ through liner top to ~7035’, tag with VACs tool cross over sub with 5K. Pull out of hole. 24h Summary Continue to single in hole with 5” drill pipe from 2500’ to 5667’. Tight at VACs tool depth of 4628’. Attempt to continue in, no success. Pull out of hole with VAC’s clean out assembly from 5667’ to 4492’. Wash down with VAC’s tool from 4492’ to 5667’, set down 20K. Pull out of hole and lay down VACs tool and 2-7/8” snorkel tubing. Pick up and make up Clean out BHA: 8.5” bit and watermelon mill and run in hole. Operation at 07.00 Pumping down to 6000' above liner top. Time Log Start Time End Time Dur (hr) Cum Dur (hr)Phase Opr. Act. Plan Oper. Descr. 00:00 05:30 5.50 5.50 W.O. M 4 P Single in hole with VACs tool: 2-7/8” PH6 snorkel pipe on TT525 drill pipe from’ 2500’ to 5667’ and set down 30K. Adding 10 BPH with 8.6 PPG NaCl / 3% KCL brine inhibited with biocide. Note: with bottom of 2-7/8”snorkel at 5667’ the bottom of the VACS (8.125” OD) 4628’. There were 2 tight spots encountered during previous work over, at 4626’ and 4665’. Adding 10 BPH with 8.6 PPG NaCl / 3% KCL brine inhibited with biocide 05:30 07:30 2.00 7.50 W.O. M 19 P Work pipe pulling 55K over string weight multiple times with pump on and off without success, set down and cocked the jars picked up 60K over and fired jars pipe came free. Attempt to work pipe down with pumps on and off, pumped brine down back side in an attempt to wash any debris down hole, picked up an attempted to rotate down with torque limiter at 10K, without success. Adding 10 BPH with 8.6 PPG NaCl / 3% KCL brine inhibited with biocide 07:30 08:30 1.00 8.50 W.O. M 4 P PJSM. Pull out of hole with VAC’s clean out assembly from 5667’ to 4492’, placing snorkel above previous magnet depth at 4525’, with UW 135K, DW 129K. Continue to add 10 BPH + pipe displacement of 8.6 PPG, NaCl/3% KCL brine inhibited with biocide. 08:30 10:30 2.00 10.50 W.O. M 7 P Wash down with VAC’s tool from 4492’ to 5667’, set down 20K. Pumped 4 BPM, 0 PSI, at 40 FPM. Adding 10 BPH with 8.6 PPG NaCl / 3% KCL brine inhibited with biocide 10:30 13:30 3.00 13.50 W.O. M 4 P PJSM. Pull out of hole with VAC’s BHA from 5667’ to top of BHA at 1166’. Adding 10 BPH with 8.6 PPG NaCl / 3% KCL brine inhibited with biocide. 13:30 15:30 2.00 15.50 W.O. M 20 P PJSM. Clean and clear rig floor, lay down jars, bumper sub, magnets, and VAC, s tool assembly. Magnets clean, tiny amount of metal fines. No sand in VACs tool. Adding 10 BPH with 8.6 PPG NaCl / 3% KCL brine inhibited with biocide 15:30 20:00 4.50 20.00 W.O. M 20 P PJSM. Make up floor valves with cross overs for 2-7/8” PH6. Pull out of hole laying down PH-6 from 1035’ to surface. Last 2 joints had sand above flappers, totaling 16 gallons, fine sand. Adding 10 BPH with 8.6 PPG NaCl / 3% KCL brine inhibited with biocide 20:00 21:30 1.50 21.50 W.O. M 1 P Clean tools and floor. Clear tools. Adding 10 BPH with 8.6 PPG NaCl / 3% KCL brine inhibited with biocide 21:30 23:30 2.00 23.50 W.O. M 5 P PJSM. Pick up and make up Clean out run: 8.5” Bit, bit sub, 2 joints of 5” drill pipe, 8.5” watermelon mill, 2-string magnets, LBS and oil jars. Run in hole to 120’. Adding 10 BPH with 8.6 PPG NaCl / 3% KCL brine inhibited with biocide 23:30 00:00 0.50 24.00 W.O. M 4 P Single back in hole with 5” drill pipe from 120’ to 370’. Note: 24 Hour Loss of 8.6 ppg Brine = 555 BBLs Total Loss of 8.6 ppg Brine = 1808.65 BBLs Daily Contacts Position Contact Name Company Title Email Office Mobile Company Representative Steve Lawrence ASRC Energy Services Drilling Supv. siddrilling@eni.com 907-685-0715 Company Representative Mike Grubb ASRC Energy Services Drilling Supv. siddrilling@eni.com 907-685-0715 Company Representative Yelyzaveta Saprykina ASRC Energy Services Rig Clerk AKRigClerksDoyon15@eni.com 907-685-0722 Safety Representative Levi Karns ASRC Energy Services HSE Levi.Karns@external.eni.com 907-685-0721 Safety Representative John Lettow Doyon Drilling HSE rig15@doyondrilling.com 907-685-0796 Tool Push Ted Kruger Doyon Drilling Tour Pusher rig15@doyondrilling.com 907-685-0716 Tool Push Tom Shones Doyon Drilling Tool Pusher rig15@doyondrilling.com 907-685-0727 Last Casing Seat Cas. Type OD (in) ID (in) Grade Top (ftKB) Bottom (ftKB) TVD Bot. (ftKB) Landing Date LINER 5 1/2 4.95 L80 -13,937.1 13,996.9 3,786.6 1/31/2012 Well Name: SP23-N3 OR Wellbore Name: SP23-N3 Well Code: 26152 Job: WORKOVER WCEI Level: LEVEL 3 Daily Report Date: 4/24/2024 Report #: 9 Page: 1 of 1 Well Header Permit/Concession N° ADL-388583 Operator ENI PETROLEUM Subsidiary ENI Petroleum Co. Inc. Initial Lahee Code DEVELOPMENT WELL Rotary Table Elevation (ft) 40.89 Ground Level (ft) First Flange (ft) 4.09 RKB - Base Flange (ft) 36.80 RKB - Tubing Spool (ft) 31.91 Rig Information Rig Name RIG 15 Contractor DOYON Rig Type LAND RIG Rig Num 0723 Daily Information Weather Overcast Temperature (°F) 16.9 Wind NE @ 23 MPH Days LTI (days) 1,572.00 Days RI (days) POB 47.0 Daily Summary Operations 24h Forecast Continue in hole with VACs tool and snorkel on 5” drill pipe from 2558’ to 7041’ Washing and vacuuming from above liner top into L-1. Pull out of hole and lay down VACs tool BHA. Prepare and test BOPE. 24h Summary Run in hole with Mill cleanout BHA from 370’ to 4624’. Work through tight spot at 4624’. Pump down to 6000’ just above liner top. Perform wiper trip, pull out of hole with casing cleanout assembly from 6005’ to 124’ MD’. Lay down casing cleanout assembly from 124’ to surface. Make up VACs tool with snorkel and run in hole from surface to 2558’. Operation at 07.00 Washing down from above liner top. Time Log Start Time End Time Dur (hr) Cum Dur (hr)Phase Opr. Act. Plan Oper. Descr. 00:00 00:30 0.50 0.50 W.O. M 4 P Trip back in hole with bit and mill cleanout run on 5” drill pipe from 370’ to 589’. Adding 10 BPH with 8.6 PPG NaCl / 3% KCL brine inhibited with biocide 00:30 01:00 0.50 1.00 W.O. M 25 P Rig service TDS 11, ST100, and draw works. 01:00 05:30 4.50 5.50 W.O. M 4 P Continue to trip in hole from 589’ to 4600’, wash down from 4600’ to 4692’ and tagged set down 15K. Made up top drive, washed and reamed from 4692’ to 4695’ MD, 3 times, at 30 RPM, TRQ 4-13K, 1-2K WOB, .75 BPM, 0 PSI, RWT 145K. 05:30 07:30 2.00 7.50 W.O. M 6 P Wash down from 4695’ to 5131’’ tag 20K. Attempt to pick up had 40K over pull. Worked tight spot back ream from 5131’ to 5066’, 30-50 RPM, TQ 4-20K, 2-5 BPM, 0 PSI. Pump out from 5066’ to 4969’, at 3 BPM O PSI. Pull out of hole on elevators from 4969’ to 4597’, and blow down top drive. 07:30 10:00 2.50 10.00 W.O. M 4 P Trip in hole from 4597’ to TOL at 6005’, tagged top of liner 2 time, setting down 5K. 10:00 12:30 2.50 12.50 W.O. M 4 P Perform wiper trip, pull out of hole with casing cleanout assembly from 6005’ to 4597’, trip back to bottom and tagged TOL at 6005’, no issue going back to TOL or pulling up to 4597’. 12:30 16:00 3.50 16.00 W.O. M 4 P Trip out of hole with casing clean out assembly from 6005’ to BHA at 124’. Continue to add 10 BPH plus metal displacement of 8.6 PPG NaCl/ 3% KCL brine inhibited with biocide. 16:00 18:30 2.50 18.50 W.O. M 5 P Lay down Casing cleanout assembly from 124’ to surface. Clean magnets and recovered 3 LBS of metal. Clean up floor. 18:30 23:00 4.50 23.00 W.O. M 4 P PJSM. Make up and run in hole with mule shoe, bent joint, with flapper and PH-6 jonts and VACs tool assembly from surface to 1166’. 23:00 00:00 1.00 24.00 W.O. M 4 P Run in hole with VACs tool BHA and snorkel on 5” drill pipe from 1166’ to 2558’ MD. Note: 24 Hour Loss of 8.6 ppg Brine = 512 BBLs Total Loss of 8.6 ppg Brine = 2320.65 BBLs Daily Contacts Position Contact Name Company Title Email Office Mobile Company Representative Steve Lawrence ASRC Energy Services Drilling Supv. siddrilling@eni.com 907-685-0715 Company Representative Mike Grubb ASRC Energy Services Drilling Supv. siddrilling@eni.com 907-685-0715 Company Representative Yelyzaveta Saprykina ASRC Energy Services Rig Clerk AKRigClerksDoyon15@eni.com 907-685-0722 Safety Representative Levi Karns ASRC Energy Services HSE Levi.Karns@external.eni.com 907-685-0721 Safety Representative Harold Richardson Doyon Drilling HSE hrichardson@doyondrilling.com 907-685-0796 Tool Push Ted Kruger Doyon Drilling Tour Pusher rig15@doyondrilling.com 907-685-0716 Tool Push Tom Shones Doyon Drilling Tool Pusher rig15@doyondrilling.com 907-685-0727 Last Casing Seat Cas. Type OD (in) ID (in) Grade Top (ftKB) Bottom (ftKB) TVD Bot. (ftKB) Landing Date LINER 5 1/2 4.95 L80 -13,937.1 13,996.9 3,786.6 1/31/2012 Well Name: SP23-N3 OR Wellbore Name: SP23-N3 Well Code: 26152 Job: WORKOVER WCEI Level: LEVEL 3 Daily Report Date: 4/25/2024 Report #: 10 Page: 1 of 1 Well Header Permit/Concession N° ADL-388583 Operator ENI PETROLEUM Subsidiary ENI Petroleum Co. Inc. Initial Lahee Code DEVELOPMENT WELL Rotary Table Elevation (ft) 40.89 Ground Level (ft) First Flange (ft) 4.09 RKB - Base Flange (ft) 36.80 RKB - Tubing Spool (ft) 31.91 Rig Information Rig Name RIG 15 Contractor DOYON Rig Type LAND RIG Rig Num 0723 Daily Information Weather Clear Temperature (°F) 13.6 Wind NE @ 37 MPH Days LTI (days) 1,573.00 Days RI (days) POB 50.0 Daily Summary Operations 24h Forecast Continue testing BOPE. Rig down test equipment. Rig up and run ~1800’ of 2-7/8” snorkel tubing in hole. Pick up and make up VACs tool BHA and run in hole on 5” drill pipe cleaning and vacuuming out into L-1. 24h Summary Continue in hole with VACs tool and snorkel on 5” drill pipe from 2558’ to 6898’. Washing and vacuuming from above liner top into L-1. Pull out of hole and lay down VACs tool BHA and snorkel, recover 3 BBLs of sand from tubing. Pull wear ring. Start testing BOPE. Operation at 07.00 Rigging up to run VAC's tool. Time Log Start Time End Time Dur (hr) Cum Dur (hr)Phase Opr. Act. Plan Oper. Descr. 00:00 03:00 3.00 3.00 W.O. M 4 P Run in hole with VACs tool BHA and snorkel on 5” drill pipe from 2558’ to 6000’. UW=152 K, DW=124 K, RPM=20, TQ=6 K. Adding 10 BPH with 8.6 PPG NaCl / 3% KCL brine inhibited with biocide. 03:00 07:00 4.00 7.00 W.O. M 19 P Made dry run into L-1 to 6087’. Pull up to 6000’ and start pumping at 3 BPM slacking off and tagged at 6066’. Pull up to 6000’ rotate 180°. Slack off while pumping 3 BPM and successfully dropped into L-1 continue wash and Vacuum to 6823’ at 3-4.5 BPM, set down 10K. Picked up and slacked off gaining about 2’ each time, worked down to 6850' appeared to break through. Work pipe to 6898’ with a much slower ROP acting like the tool was packed off. 07:00 07:30 0.50 7.50 W.O. M 1 P Blow down top drive and monitor well note fluid level falling. 07:30 11:00 3.50 11.00 W.O. M 4 P Pull out of hole on elevators from 6898’ to 1166’, standing back drill pipe. Continue to add 10 BPH + metal displacement of 8.6 PPG NaCl/ KCL brine inhibited with biocide. 11:00 14:00 3.00 14.00 W.O. M 20 P PJSM. Clean magnets and capture shavings 35 metal recovered, disassemble clean and drain VAC’s tool barrel. Cleaned screen in VACs tool, and stood back in derrick. 14:00 18:30 4.50 18.50 W.O. M 20 P PJSM. Rig up GBR and begin laying down 2-7/8” PH6 snorkel pipe wet. Laid 9 joints down with the 10th joint having sand. Discussed plan to recover sand on the rig floor, using buckets and a piece of herculite. Laid down remaining 23 joints of 2- 7/8” PH6 snorkel, recovered 3.75 BBL of sand. 18:30 19:30 1.00 19.50 W.O. C 5 P Pull wear bushing. Actuate and rinse stack. Install test plug. 19:30 22:00 2.50 22.00 W.O. C 5 P Install 2-7/8” test joint. Flood stack with water. Circulate out air though choke. Perform shell test to 2500 psi, good test. 22:00 00:00 2.00 24.00 W.O. C 12 P BOPE with 2-7/8” and 5” test joint to 250/2500 psi for 5 minutes each. Test annular, upper and lower variable rams 2-7/8” X 5” with 2-7/8” test joint. Test choke manifold valves 1, , 12, 13, 14, and 15. Test upper and lower IBOP. Test primary and secondary Demco kill valves. One Fail/Pass on lower pipe rams with 2-7/8” test joint. BOPE test witness waived by Austin McCloud of AOGCC. Note: 24 Hour Loss of 8.6 ppg Brine = 628 BBLs Total Loss of 8.6 ppg Brine = 2948.65 BBLs Daily Contacts Position Contact Name Company Title Email Office Mobile Company Representative Steve Lawrence ASRC Energy Services Drilling Supv. siddrilling@eni.com 907-685-0715 Company Representative Mike Grubb ASRC Energy Services Drilling Supv. siddrilling@eni.com 907-685-0715 Company Representative Yelyzaveta Saprykina ASRC Energy Services Rig Clerk AKRigClerksDoyon15@eni.com 907-685-0722 Safety Representative Levi Karns ASRC Energy Services HSE Levi.Karns@external.eni.com 907-685-0721 Safety Representative Harold Richardson Doyon Drilling HSE hrichardson@doyondrilling.com 907-685-0796 Tool Push Andrew Carlo Doyon Drilling Driller/Tool Pusher rig15@doyondrilling.com 907-685-0716 Tool Push Tom Shones Doyon Drilling Tool Pusher rig15@doyondrilling.com 907-685-0727 Last Casing Seat Cas. Type OD (in) ID (in) Grade Top (ftKB) Bottom (ftKB) TVD Bot. (ftKB) Landing Date LINER 5 1/2 4.95 L80 -13,937.1 13,996.9 3,786.6 1/31/2012 Well Name: SP23-N3 OR Wellbore Name: SP23-N3 Well Code: 26152 Job: WORKOVER WCEI Level: LEVEL 3 Daily Report Date: 4/26/2024 Report #: 11 Page: 1 of 1 Well Header Permit/Concession N° ADL-388583 Operator ENI PETROLEUM Subsidiary ENI Petroleum Co. Inc. Initial Lahee Code DEVELOPMENT WELL Rotary Table Elevation (ft) 40.89 Ground Level (ft) First Flange (ft) 4.09 RKB - Base Flange (ft) 36.80 RKB - Tubing Spool (ft) 31.91 Rig Information Rig Name RIG 15 Contractor DOYON Rig Type LAND RIG Rig Num 0723 Daily Information Weather Overcast Temperature (°F) 10.0 Wind NE @ 32 MPH Days LTI (days) 1,574.00 Days RI (days) POB 48.0 Daily Summary Operations 24h Forecast Continue to pull out of hole from 1940’. Empty and clean Vacs tool. Empty 2-7/8” snorkel string. Clean floor. Pick up clean out assembly #5 and run in hole to flush and stuff. Pull out of hole laying down drill pipe and 2-7/8”. 24h Summary Finish testing BOPE. Make up bent pup flappers and mule shoe assembly and VACs tool and run in hole to above TOL at 5980’ MD. Wash and Vacuum from 5980’ to 7285’ MD. Pull out of hole from 7285’ to 1940’. Lay down jars and bumper sub, cleaning magnets. Operation at 07.00 Laying down 2-7/8” PH6. Time Log Start Time End Time Dur (hr) Cum Dur (hr)Phase Opr. Act. Plan Oper. Descr. 00:00 04:30 4.50 4.50 W.O. C 12 P Continue testing BOPE. Test BOPE with 2-7/8” and 5” test joint to 250/2500 psi for 5 minutes each. Test annular, upper and lower variable rams 2-7/8” X 5” with 5” test joint. Test choke manifold valves 2, 3, 4, 5, 6, 7, 8, 9, 10 and 11. Test primary and secondary kill valves, TT525 FOSV, 1 and 2 HCR choke and Blind shear rams. Function test manual operated and remotely operated choke valves, open valves and allow 2000 psi bleed off. Perform accumulator draw down test: Starting pressure=2975 psi, after function=2175 psi, 200 psi increase= 9 seconds, full pressure recovery=43 seconds, Nitrogen back up 10 bottles with 4300 psi average pressure. Test Gas alarms. Test flow alarms and PVT system. All tests good. Witness waived by AOGCC rep Austin McCloud. 04:30 05:30 1.00 5.50 W.O. C 1 P Rig down test equipment. Blow down surface equipment. Pull test plug. Install wear ring. 05:30 06:30 1.00 6.50 W.O. M 1 P Rig up GBR and change handling equipment to 2-7/8”. 06:30 11:00 4.50 11.00 W.O. M 5 P PJSM. Make up bent pup flappers and mule shoe assembly on joint #1. Pick up 2-7/8” PH6 snorkel pipe and single in hole to 1840’, make up VAC’s tool and magnets to 1970’ MD. 11:00 14:00 3.00 14.00 W.O. M 4 P Trip in hole with VACs tool from 1970’ to TOL at 5980’ MD. PW=116 k, SO=112 K. 14:00 18:00 4.00 18.00 W.O. M 19 P Wash and Vacuum from 5980’ to 7285’ MD, pumping at 4-5 bbls/min, 150-630 psi, stopped to pull out of hole with VACS tool assembly acting full ( weight not falling off when slacking off ). PUW=165 K, SO=107 K. Partial returns to surface, directed through auger out to cuttings box. Made it through lem on second attempt after rotating string. Intermittent returns totaling approximately 312 bbls of crude and brine to the cuttings box. 18:00 19:00 1.00 19.00 W.O. M 20 P Clear and clean floor. Install stripping rubber and air slips. Troubleshoot flow line indicator. Fluid level at well head. 19:00 23:00 4.00 23.00 W.O. M 4 P Pull out of hole with VACs tool assembly and 1830’ of 2-7/8” PH-6 snorkel string from 7285’ to 1970’ MD. No overpull, 50-80 ft/min. 23:00 00:00 1.00 24.00 W.O. M 20 P PJSM. Lay down jars and bumper subfrom 1970’ to 1940’. Cleaning magnet. Note: 24 Hour Loss of 8.6 ppg Brine = 334 BBLs Total Loss of 8.6 ppg Brine = 3282.65 BBLs Daily Contacts Position Contact Name Company Title Email Office Mobile Company Representative Steve Lawrence ASRC Energy Services Drilling Supv. siddrilling@eni.com 907-685-0715 Company Representative Mike Grubb ASRC Energy Services Drilling Supv. siddrilling@eni.com 907-685-0715 Company Representative Yelyzaveta Saprykina ASRC Energy Services Rig Clerk AKRigClerksDoyon15@eni.com 907-685-0722 Safety Representative Levi Karns ASRC Energy Services HSE Levi.Karns@external.eni.com 907-685-0721 Safety Representative Harold Richardson Doyon Drilling HSE hrichardson@doyondrilling.com 907-685-0796 Tool Push Andrew Carlo Doyon Drilling Driller/Tool Pusher rig15@doyondrilling.com 907-685-0716 Tool Push Tom Shones Doyon Drilling Tool Pusher rig15@doyondrilling.com 907-685-0727 Last Casing Seat Cas. Type OD (in) ID (in) Grade Top (ftKB) Bottom (ftKB) TVD Bot. (ftKB) Landing Date LINER 5 1/2 4.95 L80 -13,937.1 13,996.9 3,786.6 1/31/2012 Well Name: SP23-N3 OR Wellbore Name: SP23-N3 Well Code: 26152 Job: WORKOVER WCEI Level: LEVEL 3 Daily Report Date: 4/27/2024 Report #: 12 Page: 1 of 1 Well Header Permit/Concession N° ADL-388583 Operator ENI PETROLEUM Subsidiary ENI Petroleum Co. Inc. Initial Lahee Code DEVELOPMENT WELL Rotary Table Elevation (ft) 40.89 Ground Level (ft) First Flange (ft) 4.09 RKB - Base Flange (ft) 36.80 RKB - Tubing Spool (ft) 31.91 Rig Information Rig Name RIG 15 Contractor DOYON Rig Type LAND RIG Rig Num 0723 Daily Information Weather Overcast Temperature (°F) 5.4 Wind NE @ 21 MPH Days LTI (days) 1,575.00 Days RI (days) POB 48.0 Daily Summary Operations 24h Forecast Stand back remainder of 5” drill pipe. Lay down magnets and jars. Pick up 1000’ of PH-6 and add to the PH6 in hole. Run in hole 2-7/8” BHA with 5” drill pipe to 8842’. Pull out of hole stand back 5” drill pipe and lay down 2-7/8” PH-6. 24h Summary Continue to pull out of hole from 1940’ and lay down VACS tool BHA (recover 1.25 BBLs sand). Lay down 2-7/8” PH-6 and recover 2.6 bbls sand. Run in hole with BHA #5 magnets and 2-7/8” PH-6 to 7842’ MD. Pull out of hole from 7842’ to 6083’ MD. Operation at 07.00 Run in hole with BHA #6. Time Log Start Time End Time Dur (hr) Cum Dur (hr)Phase Opr. Act. Plan Oper. Descr. 00:00 03:00 3.00 3.00 W.O. M 20 P PJSM. Continue laying down VACs tool BHA from 1940’ to 1840’. Cleaning magnet #2 and recover 5 lbs from both magnets of metal. Drain VACs tool. Upper VACs full of brine with 1.9 BBLs. Lower VACs recovered 1.25 BBLs of semi coarse sand and 0.25 BBLs of dirty brine. Soft break connections and lay down VACs tool and cross overs. 03:00 03:30 0.50 3.50 W.O. M 1 P Change out handling equipment to 2-7/8”. Make up floor valve and clear and clean floor. 03:30 09:00 5.50 9.00 W.O. M 4 P Pull out of hole laying down 2-7/8” PH6 snorkel pipe from 1970’ to surface. Encountered sand in joints 11 to bottom, with joints 5 to 1 being packed with exceptionally hard sand. Sand recovered from snorkel pipe 2.6 BBL. Total 3.85 BBL of sand recovered. 09:00 11:30 2.50 11.50 W.O. M 20 P Clean and clear rig floor, inspect 2-7/8” work string and dispose of sand from tubing. 11:30 14:30 3.00 14.50 W.O. M 4 P PJSM. Make up mule shoe on bent sub, and trip in hole on 2-7/8” PH6 work string to 1830’. 14:30 15:00 0.50 15.00 W.O. M 20 P Grease blocks, draw works and top drive. Check oils in draw works and top drive. 15:00 18:00 3.00 18.00 W.O. M 5 P Make up magnets, subs and jars. Install air slips, air slips not biting. Change out dies on slips. Pull wear bushings and wash off sand. 18:00 20:00 2.00 20.00 W.O. M 4 P PJSM. Trip in hole from 1830’ to 5990’ MD with 45 stands. 20:00 23:00 3.00 23.00 W.O. M 7 P Enter liner top and tag at 6072’ pick up and rotate string 180° and slack off to 6083’ MD. Wash down from 6083’ to 7222’ MD with 3-3.5 BPM, 125-144 psi. Fluid level at well head prior to pumping, at 3.5 BPM fluid level reaching stack before shutting down pump, slack off speeds increased to 60 ft/min. Wash from 7222’ to 7842’ MD, magnet cross over tag at liner top with 5K. (7286’ was previous depth we reached with 2-7/8”). Increased flow to 5 BPM, 70% to well, 30% returns, 380- 438 psi, taking returns to auger and out to cuttings box. Returns of dirty brine. 15 K down at 7750’ and 7831’ MD, weight would wash off.23:00 00:00 1.00 24.00 W.O. M 4 P PJSM. Install wiper rubber, pull out of hole from 7842’ to 6083’ MD. Adding 10 BPH with 8.6 PPG NaCl / 3% KCL brine inhibited with biocide. Note: 24 Hour Loss of 8.6 ppg Brine = 770 BBLs Total Loss of 8.6 ppg Brine = 4052.65 BBLs Daily Contacts Position Contact Name Company Title Email Office Mobile Company Representative Steve Lawrence ASRC Energy Services Drilling Supv. siddrilling@eni.com 907-685-0715 Company Representative Mike Grubb ASRC Energy Services Drilling Supv. siddrilling@eni.com 907-685-0715 Company Representative Yelyzaveta Saprykina ASRC Energy Services Rig Clerk AKRigClerksDoyon15@eni.com 907-685-0722 Safety Representative Levi Karns ASRC Energy Services HSE Levi.Karns@external.eni.com 907-685-0721 Safety Representative Harold Richardson Doyon Drilling HSE hrichardson@doyondrilling.com 907-685-0796 Tool Push Andrew Carlo Doyon Drilling Driller/Tool Pusher rig15@doyondrilling.com 907-685-0716 Tool Push Tom Shones Doyon Drilling Tool Pusher rig15@doyondrilling.com 907-685-0727 Last Casing Seat Cas. Type OD (in) ID (in) Grade Top (ftKB) Bottom (ftKB) TVD Bot. (ftKB) Landing Date LINER 5 1/2 4.95 L80 -13,937.1 13,996.9 3,786.6 1/31/2012 Well Name: SP23-N3 OR Wellbore Name: SP23-N3 Well Code: 26152 Job: WORKOVER WCEI Level: LEVEL 3 Daily Report Date: 4/28/2024 Report #: 13 Page: 1 of 1 Well Header Permit/Concession N° ADL-388583 Operator ENI PETROLEUM Subsidiary ENI Petroleum Co. Inc. Initial Lahee Code DEVELOPMENT WELL Rotary Table Elevation (ft) 40.89 Ground Level (ft) First Flange (ft) 4.09 RKB - Base Flange (ft) 36.80 RKB - Tubing Spool (ft) 31.91 Rig Information Rig Name RIG 15 Contractor DOYON Rig Type LAND RIG Rig Num 0723 Daily Information Weather Clear Temperature (°F) 6.8 Wind NE @ 26 MPH Days LTI (days) 1,576.00 Days RI (days) POB 50.0 Daily Summary Operations 24h Forecast Pull out of hole stand back 5” drill pipe and lay down 2-7/8” PH-6. Install flapper valves and VACs tool assembly and 2022’ of 2-7/8” PH-6. Run in hole with 5” drill pipe to ~8167’. Pull out of hole. 24h Summary Pull out of hole from 6083’ to 1885’. Lay down magnets and jars. Single in hole from 1834’ to 2856’ MD with 2-7/8”. Wash and Vacuum from 6005’ to 8791’. Pump out of hole from 8791’ to 8030’ MD Operation at 07.00 Pulling out of hole. Time Log Start Time End Time Dur (hr) Cum Dur (hr)Phase Opr. Act. Plan Oper. Descr. 00:00 02:00 2.00 2.00 W.O. M 4 P PJSM. Pull out of hole from 6083’ to 1885’ MD rack back 5” drill pipe in derrick. UW=70 k, DW=75 k. Adding 10 BPH with 8.6 PPG NaCl / 3% KCL brine inhibited with biocide. 02:00 03:00 1.00 3.00 W.O. M 20 P Lay down magnets and jars, recover 5 lbs fine metal shavings from magnets. Change out handling equipment to 2-7/8”. Rig up GBR tongs. Break out PH-6 cross over. 03:00 04:00 1.00 4.00 W.O. M 1 P Load 33 joints 2-7/8” PH-6 and process same. SIMOPS: clean and clear rig floor. 04:00 06:00 2.00 6.00 W.O. M 4 P PJSM. Single in hole from 1834’ to 2856’ MD with 2-7/8” PH-6. UW=72, DW=80. GBR use power tongs to make up connections to 3900 ft/lbs. 06:00 07:00 1.00 7.00 W.O. M 5 P Change out handling equipment to 5”. Make up XO magnets, jar, bumper sub, and change out heads on ST100. 07:00 08:30 1.50 8.50 W.O. M 4 P Trip in hole with BHA #6 to TOL at 6005’. Wash through liner top had to pick up and orientate pipe 180° to be able to pass through 08:30 11:00 2.50 11.00 W.O. M 4 P Continue to wash down from 6072’ to 7840’ at 4 BPM, 380 PSI, 50 FPM. 11:00 12:30 1.50 12.50 W.O. M 4 P Continue to wash in hole from 7840’ to 8244’ at 5 BPM 350 PSI. 12:30 13:00 0.50 13.00 W.O. M 6 P Wash and ream down from 8244’ to 8255’ at 15 RPM, 10K TQ, 5 BPM, 540 PSI, and WOB 5-10K. 13:00 15:00 2.00 15.00 W.O. M 4 P Wash down from 8255’ to 8541’’ at 4-5 BPM, PSI 500-180, WOB 5-10K. 15:00 18:30 3.50 18.50 W.O. M 6 P Wash and ream down from 8541’ to 8791’ at 3 BPM, 175 psi, PU=175, SO=140K. 18:30 20:30 2.00 20.50 W.O. M 4 P PJSM. Pump out of hole from 8791’ to 8400’, max pull to 100 k over, pumping at 2 BPM, 100 psi, attempt to rotate out of hole 20 RPM, 10-12 k. Work pipe. 20:30 21:30 1.00 21.50 W.O. M 25 P Tighten up union on gooseneck and Kelly hose. 21:30 00:00 2.50 24.00 W.O. M 4 P Continue to pump out of hole from 8400-8030’ MD. 3-4.5 BPM, with 100 k over pull, breaking free with slight releases with higher pump rates. At 8127’ returns stopped coming to surface, fluid level at well head. Sucking air when break joint connection. Note: 24 Hour Loss of 8.6 ppg Brine = 1182 BBLs Total Loss of 8.6 ppg Brine = 5224.65 BBLs Daily Contacts Position Contact Name Company Title Email Office Mobile Company Representative Steve Lawrence ASRC Energy Services Drilling Supv. siddrilling@eni.com 907-685-0715 Company Representative Mike Grubb ASRC Energy Services Drilling Supv. siddrilling@eni.com 907-685-0715 Company Representative Yelyzaveta Saprykina ASRC Energy Services Rig Clerk AKRigClerksDoyon15@eni.com 907-685-0722 Safety Representative Levi Karns ASRC Energy Services HSE Levi.Karns@external.eni.com 907-685-0721 Safety Representative Harold Richardson Doyon Drilling HSE hrichardson@doyondrilling.com 907-685-0796 Tool Push Andrew Carlo Doyon Drilling Driller/Tool Pusher rig15@doyondrilling.com 907-685-0716 Tool Push Tom Shones Doyon Drilling Tool Pusher rig15@doyondrilling.com 907-685-0727 Last Casing Seat Cas. Type OD (in) ID (in) Grade Top (ftKB) Bottom (ftKB) TVD Bot. (ftKB) Landing Date LINER 5 1/2 4.95 L80 -13,937.1 13,996.9 3,786.6 1/31/2012 Well Name: SP23-N3 OR Wellbore Name: SP23-N3 Well Code: 26152 Job: WORKOVER WCEI Level: LEVEL 3 Daily Report Date: 4/29/2024 Report #: 14 Page: 1 of 1 Well Header Permit/Concession N° ADL-388583 Operator ENI PETROLEUM Subsidiary ENI Petroleum Co. Inc. Initial Lahee Code DEVELOPMENT WELL Rotary Table Elevation (ft) 40.89 Ground Level (ft) First Flange (ft) 4.09 RKB - Base Flange (ft) 36.80 RKB - Tubing Spool (ft) 31.91 Rig Information Rig Name RIG 15 Contractor DOYON Rig Type LAND RIG Rig Num 0723 Daily Information Weather Overcast Temperature (°F) 7.0 Wind NE @ 6 MPH Days LTI (days) 1,577.00 Days RI (days) POB 52.0 Daily Summary Operations 24h Forecast Finish cut and slip. Continue in hole to 5975’, obtain parameters. Establish circulation, if we can circulate bottoms up. Washing down at 4 BPM entering into L-1. If circulation not established slowly wash to 7005’. Pull out of hole from 7005’ standing back stands of 5” drill pipe in derrick. Lay down PH-6 to pipe shed. Proceed with 2-7/8” completion. 24h Summary Pump out of hole from 8030’ to 7530’ MD. Pull on elevators from 7530’ to 2903’ MD. Lay down sub, Jars, and both magnets. Pull out of hole with 2-7/8” PH-6 to surface. Run in hole with bull nose BHA, cleanout run BHA #7. Run in hole to 5746’ MD. Start slipping and cutting drilling line. Operation at 07.00 Washing in hole. Time Log Start Time End Time Dur (hr) Cum Dur (hr)Phase Opr. Act. Plan Oper. Descr. 00:00 02:30 2.50 2.50 W.O. M 4 P Continue to pump out of hole from 8030’ to 7530’ MD, 4.5 BPM, breaking free with slight releases with higher pump rates. UW=155 K, DW=120 K. 02:30 05:00 2.50 5.00 W.O. M 4 P Pull on elevators from 7530’ to 2903’ MD, racking back 5” drill pipe. UW=75 K, DW=82 K. Adding 10 BPH plus metal displacement with 8.6 PPG NaCl / 3% KCL brine inhibited with biocide. 05:00 06:00 1.00 6.00 W.O. M 20 P PJSM. Lay down sub, Jars, and both magnets to pipe shed. Change out handling equipment to 2-7/8”, and rig up GBR. 06:00 10:00 4.00 10.00 W.O. M 4 P PJSM. Pull out of hole laying down 2-7/8” pipe from 2856’ to 1435’, GBR having issues breaking PH6 connections with their tongs. Rig down GBR tongs and pick up HT14 rig tongs. Continue to add 10 BPH + metal displacement of 8.6 PPG NaCL/3% KCL brine, inhibited with biocide to well. 10:00 12:00 2.00 12.00 W.O. M 4 P PJSM. Pull out of hole laying down 2-7/8” pipe from 1435’ to surface, using HT14 rig tongs. Continue to add 10 BPH + metal displacement of 8.6 PPG NaCL/3% KCL brine, inhibited with biocide to well. 12:00 14:30 2.50 14.50 W.O. M 1 P PJSM, Clean and clear rig floor, change out saver sub. 14:30 17:30 3.00 17.50 W.O. M 1 P Organize floor. Determine next BHA. General housekeeping. Change out GBR tong dies. 17:30 20:30 3.00 20.50 W.O. M 5 P Make up BHA #7, and run in hole from surface to 1082’ MD. Make up bent joint, cross overs and bull nose. Pick up 2-7/8” PH- 6, 33 joints. Change out elevators. Make up magnets, oil jar and bumper sub. 20:30 21:00 0.50 21.00 W.O. M 1 P Change out blocks for ST-100 21:00 23:00 2.00 23.00 W.O. M 4 P Run BHA #7 in hole with 5” drill pipe from 1082 to 5746’ MD. 23:00 00:00 1.00 24.00 W.O. M 20 P PJSM. Start slipping and cutting drilling line, 102’, 12 wraps. Note: 24 Hour Loss of 8.6 ppg Brine = 982 BBLs Total Loss of 8.6 ppg Brine = 6206.65 BBLs Daily Contacts Position Contact Name Company Title Email Office Mobile Company Representative Steve Lawrence ASRC Energy Services Drilling Supv. siddrilling@eni.com 907-685-0715 Company Representative Mike Grubb ASRC Energy Services Drilling Supv. siddrilling@eni.com 907-685-0715 Company Representative Yelyzaveta Saprykina ASRC Energy Services Rig Clerk AKRigClerksDoyon15@eni.com 907-685-0722 Safety Representative Levi Karns ASRC Energy Services HSE Levi.Karns@external.eni.com 907-685-0721 Safety Representative Harold Richardson Doyon Drilling HSE hrichardson@doyondrilling.com 907-685-0796 Tool Push Andrew Carlo Doyon Drilling Driller/Tool Pusher rig15@doyondrilling.com 907-685-0716 Tool Push Tom Shones Doyon Drilling Tool Pusher rig15@doyondrilling.com 907-685-0727 Last Casing Seat Cas. Type OD (in) ID (in) Grade Top (ftKB) Bottom (ftKB) TVD Bot. (ftKB) Landing Date LINER 5 1/2 4.95 L80 -13,937.1 13,996.9 3,786.6 1/31/2012 Well Name: SP23-N3 OR Wellbore Name: SP23-N3 Well Code: 26152 Job: WORKOVER WCEI Level: LEVEL 3 Daily Report Date: 4/30/2024 Report #: 15 Page: 1 of 1 Well Header Permit/Concession N° ADL-388583 Operator ENI PETROLEUM Subsidiary ENI Petroleum Co. Inc. Initial Lahee Code DEVELOPMENT WELL Rotary Table Elevation (ft) 40.89 Ground Level (ft) First Flange (ft) 4.09 RKB - Base Flange (ft) 36.80 RKB - Tubing Spool (ft) 31.91 Rig Information Rig Name RIG 15 Contractor DOYON Rig Type LAND RIG Rig Num 0723 Daily Information Weather Clear Temperature (°F) 11.1 Wind N @ 6 MPH Days LTI (days) 1,578.00 Days RI (days) POB 52.0 Daily Summary Operations 24h Forecast Lay down PH-6 to pipe shed. Remove wear bushing. Flush inside BOP. Clear and clean rig floor. Pick up make up ESP pump assembly. Trip in the hole with 2-7/8” ESP completion. 24h Summary Finish slipping and cutting drilling line. Continue in hole to liner top at 6005’. Pass through LEM and wash down to 7044’. Pull out of hole. Clean magnets break and lay down BHA assembly. Operation at 07.00 Prepare to pick up ESP. Time Log Start Time End Time Dur (hr) Cum Dur (hr)Phase Opr. Act. Plan Oper. Descr. 00:00 02:30 2.50 2.50 W.O. M 20 P PJSM. Finish slipping and cutting drilling line, 102’, 12 wraps. Adjust brakes, Service draw works and calibrate block height. Clean and clear floor. 02:30 03:00 0.50 3.00 W.O. M 4 P PJSM. Run in hole from 5746’ to 5934’ MD with 5” drill pipe from derrick. UW=155 K, DW=120 K, RW=140 K, 20 rpm, 5-6 K TQ. 03:00 04:30 1.50 4.50 W.O. M 4 P Wash down to liner top at 6005’ attempt to pass through LEM had to pick up and orientate bull nose wash nozzle and was able to pass through. Continue to wash down to 6396’ set down 15K. 4 BPM 350-400 PSI. 04:30 08:00 3.50 8.00 W.O. M 6 P Wash and ream in hole from 6396’ to bit depth of 7044’, at 4 BPM 350-400 PSI, 20 RPM, TRQ 6-8K, WOB 0-5K. Tagged top of liner without rotation with XO set down 5K (TOL 6005’) 08:00 15:00 7.00 15.00 W.O. M 7 P Circulate bottom up while rotating and reciprocating pipe from 7025’ to 6955’ at 4 BPM, ICP 400 PSI, FCP 260 PSI, RPM 20, TQ 6-8K, with varied loss rated from 50% to 30%, pumped 5.4 bottoms up per stroke count. Initial bottoms up had a large amount of sand coming back diminishing to minimal amounts. 15:00 17:00 2.00 17.00 W.O. M 20 P Monitor well bore fluid levels (No flow). Static losses 84 bbl/hr. 17:00 21:30 4.50 21.50 W.O. M 4 P Blow down Top drive. Pull out of the hole from 6,977’ to 1,082’. Pump 10 BPH plus pipe displacement. 21:30 00:00 2.50 24.00 W.O. M 20 P Break lay down BHA assembly, clean and wash magnets, bumper sub and Jars. Remove BHA off rig floor through beaver slide. Change out dies in the ST-80 from 5” to 2-7/8’. Change out elevators to 2-7/8”. Note: 24 Hour Loss of 8.6 ppg Brine = 567 BBLs Total Loss of 8.6 ppg Brine = 6773.65 BBLs Daily Contacts Position Contact Name Company Title Email Office Mobile Company Representative Steve Lawrence ASRC Energy Services Drilling Supv. siddrilling@eni.com 907-685-0715 Company Representative Craig Smith ASRC Energy Services Drilling Supv. siddrilling@eni.com 208 816-6803 Company Representative Yelyzaveta Saprykina ASRC Energy Services Rig Clerk AKRigClerksDoyon15@eni.com 907-685-0722 Safety Representative Levi Karns ASRC Energy Services HSE Levi.Karns@external.eni.com 907-685-0721 Safety Representative Harold Richardson Doyon Drilling HSE hrichardson@doyondrilling.com 907-685-0796 Tool Push Andrew Carlo Doyon Drilling Driller/Tool Pusher rig15@doyondrilling.com 907-685-0716 Tool Push Tom Shones Doyon Drilling Tool Pusher rig15@doyondrilling.com 907-685-0727 Last Casing Seat Cas. Type OD (in) ID (in) Grade Top (ftKB) Bottom (ftKB) TVD Bot. (ftKB) Landing Date LINER 5 1/2 4.95 L80 -13,937.1 13,996.9 3,786.6 1/31/2012 Well Name: SP23-N3 OR Wellbore Name: SP23-N3 Well Code: 26152 Job: WORKOVER WCEI Level: LEVEL 3 Daily Report Date: 5/1/2024 Report #: 16 Page: 1 of 1 Well Header Permit/Concession N° ADL-388583 Operator ENI PETROLEUM Subsidiary ENI Petroleum Co. Inc. Initial Lahee Code DEVELOPMENT WELL Rotary Table Elevation (ft) 40.89 Ground Level (ft) First Flange (ft) 4.09 RKB - Base Flange (ft) 36.80 RKB - Tubing Spool (ft) 31.91 Rig Information Rig Name RIG 15 Contractor DOYON Rig Type LAND RIG Rig Num 0723 Daily Information Weather Clear Temperature (°F) 1.4 Wind W @ 8 MPH Days LTI (days) 1,579.00 Days RI (days) POB 51.0 Daily Summary Operations 24h Forecast Trip in the hole with 2-7/8” ESP completion assembly. 24h Summary Lay down PH-6 DP in pipe shed. Remove wear bushing. Flush inside BOPE stack. Clear and clean rig floor. Pick up make up ESP assembly. Trip in the hole with 2-7/8” ESP completion from 85’ to 126’. Operation at 07.00 Continue running in hole with 2-7/8" ESP completion assembly at 1730'. Time Log Start Time End Time Dur (hr) Cum Dur (hr)Phase Opr. Act. Plan Oper. Descr. 00:00 02:00 2.00 2.00 W.O. M 4 P PJSM. Trip out of the hole with 2-7/8” PH6 DP from 1,082 to surface. Recovered 5 lbs. metal shavings from magnets. Add 10 BPH plus metal displacement to hole with 8.6 ppg NaCl/ 3% KCL brine inhibited with biocide. 02:00 02:30 0.50 2.50 W.O. M 1 P PJSM. Rig down GBR power tongs, change out handling equipment from 5’’ to 2-7/8’’. 02:30 05:00 2.50 5.00 W.O. M 20 P PJSM. Remove wear bushing and make up stack washer and X-over to 5’ joint of drill pipe wash inside of bop stack function rams, and wash tubing hanger profile, at 20 RPM, 8 BPM, total 85 BBL pumped. Rig down washing equipment blow down top drive. 05:00 09:00 4.00 9.00 W.O. K 1 P Clean and clear rig floor of all non-essential tools and equipment, simops load ESP pump equipment into the pipe shed. Add 10 BPH to hole with 8.6 ppg NaCl/ 3% KCL brine inhibited with biocide. 09:00 11:00 2.00 11.00 W.O. K 1 P PJSM. Stage Baker Centerlift completion equipment, and Vault tubing hanger and swivel joint on the rig floor. Load ESP shroud in the pipe shed, and string rope over ESP sheaves. Pull ESP cable and capillary line over sheaves coming from the spooler to the rig floor. Add 10 BPH to hole with 8.6 ppg NaCl/ 3% KCL brine inhibited with biocide. 11:00 19:30 8.50 19.50 W.O. K 12 P PJSM. Pick up and service ESP motor and seals, fill with oil and verify rotation. Install check valve and attach capillary tube, test line all good, (A) check valve opened at 3700 PSI, (B) check valve opened at 3400 PSI. Witness by ENI Company Rep. Load ESP shroud in the pipe shed, and string rope over ESP sheaves. 19:30 23:00 3.50 23.00 W.O. K 20 P Baker rep splice MLE to ESP cable Witness by ENI Electrician. Test ESP cable. Good test. 23:00 00:00 1.00 24.00 W.O. K 4 P Trip in the hole with 2-7/8” HYD-563 # 6.5 L-80 completion tubing from 85’ to 126’. GBR torque turn each connection to 1900 ft/lbs. Superior thread rep inspect all thread and witness each connection. Note: 24 Hour Loss of 8.6 ppg Brine = 325 BBLs Total Loss of 8.6 ppg Brine = 7098.65 BBLs Daily Contacts Position Contact Name Company Title Email Office Mobile Company Representative Steve Lawrence ASRC Energy Services Drilling Supv. siddrilling@eni.com 907-685-0715 Company Representative Craig Smith ASRC Energy Services Drilling Supv. siddrilling@eni.com 208 816-6803 Company Representative Yelyzaveta Saprykina ASRC Energy Services Rig Clerk AKRigClerksDoyon15@eni.com 907-685-0722 Safety Representative Levi Karns ASRC Energy Services HSE Levi.Karns@external.eni.com 907-685-0721 Safety Representative Harold Richardson Doyon Drilling HSE hrichardson@doyondrilling.com 907-685-0796 Tool Push Andrew Carlo Doyon Drilling Driller/Tool Pusher rig15@doyondrilling.com 907-685-0716 Tool Push Tom Shones Doyon Drilling Tool Pusher rig15@doyondrilling.com 907-685-0727 Last Casing Seat Cas. Type OD (in) ID (in) Grade Top (ftKB) Bottom (ftKB) TVD Bot. (ftKB) Landing Date LINER 5 1/2 4.95 L80 -13,937.1 13,996.9 3,786.6 1/31/2012 Well Name: SP23-N3 OR Wellbore Name: SP23-N3 Well Code: 26152 Job: WORKOVER WCEI Level: LEVEL 3 Daily Report Date: 5/2/2024 Report #: 17 Page: 1 of 1 Well Header Permit/Concession N° ADL-388583 Operator ENI PETROLEUM Subsidiary ENI Petroleum Co. Inc. Initial Lahee Code DEVELOPMENT WELL Rotary Table Elevation (ft) 40.89 Ground Level (ft) First Flange (ft) 4.09 RKB - Base Flange (ft) 36.80 RKB - Tubing Spool (ft) 31.91 Rig Information Rig Name RIG 15 Contractor DOYON Rig Type LAND RIG Rig Num 0723 Daily Information Weather Overcast Temperature (°F) 17.2 Wind SW @ 12 MPH Days LTI (days) 1,580.00 Days RI (days) POB 52.0 Daily Summary Operations 24h Forecast Make up 4.5” pup joints and swivel joints to tubing hanger. Install penetrator, ESP cable splice, land hanger break lay down landing joint. Nipple down BOPs and Nipple up tree. Vault rep test hanger void to 5,000 psi 15 min. Centrilift conduct cable and cap line test. Vault conduct passport testing with rig pumps. 24h Summary Trip in the hole with ESP assembly from 126’ to 5920’. Performing electrical checks every 1000’. Ran total of 193 joints. Operation at 07.00 Prepare to land hanger. Time Log Start Time End Time Dur (hr) Cum Dur (hr)Phase Opr. Act. Plan Oper. Descr. 00:00 11:00 11.00 11.00 W.O. K 4 P Trip in the hole with ESP assembly from 126’ to 3250’, with 2-7/8” HYD-563 6.5# L-80 completion tubing with ESP and cap line. GBR torque turn each connection, Baker install cannon clamps on each connection. Superior thread rep inspect all threads and witness each connection. Perform electrical checks every 1,000’, and add 10 BPH to the hole with 8.6 ppg NaCl/ 3% KCL brine inhibited with biocide. 11:00 12:00 1.00 12.00 W.O. K 9 P Pump tubing volume 20 BBL of 8.6 PPG NaCl/ 3% KCL brine inhibited with biocide, at 2 BPM. 12:00 23:00 11.00 23.00 W.O. K 4 P PJSM. Reviewed Doyon, GBR, and Baker JSA, discussed well control with new hands. Continue to trip in the hole with ESP assembly from 3250’’ to 5920’. Total joints ran 193 of 2-7/8” HYD-563 6.5# L-80 completion tubing with ESP and cap line. GBR torque turn each connection. Baker install cannon clamps on each connection. Superior thread rep inspect all threads and witness each connection. Perform electrical checks every 1,000’. Add 10 BPH to the hole with 8.6 ppg NaCl/ 3% KCL brine inhibited with biocide. 23:00 00:00 1.00 24.00 W.O. K 20 P GBR change out power tong dies to 4.5”, made up 2-7/8” x 4.5” X-over. Note: 24 Hour Loss of 8.6 ppg Brine = 326 BBLs Total Loss of 8.6 ppg Brine = 7424.65 BBLs Daily Contacts Position Contact Name Company Title Email Office Mobile Company Representative Steve Lawrence ASRC Energy Services Drilling Supv. siddrilling@eni.com 907-685-0715 Company Representative Craig Smith ASRC Energy Services Drilling Supv. siddrilling@eni.com 208 816-6803 Company Representative Yelyzaveta Saprykina ASRC Energy Services Rig Clerk AKRigClerksDoyon15@eni.com 907-685-0722 Safety Representative Levi Karns ASRC Energy Services HSE Levi.Karns@external.eni.com 907-685-0721 Safety Representative Harold Richardson Doyon Drilling HSE hrichardson@doyondrilling.com 907-685-0796 Tool Push Andrew Carlo Doyon Drilling Driller/Tool Pusher rig15@doyondrilling.com 907-685-0716 Tool Push Tom Shones Doyon Drilling Tool Pusher rig15@doyondrilling.com 907-685-0727 Last Casing Seat Cas. Type OD (in) ID (in) Grade Top (ftKB) Bottom (ftKB) TVD Bot. (ftKB) Landing Date LINER 5 1/2 4.95 L80 -13,937.1 13,996.9 3,786.6 1/31/2012 Well Name: SP23-N3 OR Wellbore Name: SP23-N3 Well Code: 26152 Job: WORKOVER WCEI Level: LEVEL 3 Daily Report Date: 5/3/2024 Report #: 18 Page: 1 of 1 Well Header Permit/Concession N° ADL-388583 Operator ENI PETROLEUM Subsidiary ENI Petroleum Co. Inc. Initial Lahee Code DEVELOPMENT WELL Rotary Table Elevation (ft) 40.89 Ground Level (ft) First Flange (ft) 4.09 RKB - Base Flange (ft) 36.80 RKB - Tubing Spool (ft) 31.91 Rig Information Rig Name RIG 15 Contractor DOYON Rig Type LAND RIG Rig Num 0723 Daily Information Weather Overcast Temperature (°F) 10.0 Wind NE @ 14 MPH Days LTI (days) 1,581.00 Days RI (days) POB 51.0 Daily Summary Operations 24h Forecast Trouble shoot Iron Roughneck. Organize and clean pipe shed. Nipple down BOPE and Nipple up tree. Perform passport testing. 24h Summary Make up 4.5” pup joints and swivel joints to tubing hanger. Install penetrator. ESP cable splice. Land hanger, break, lay down landing joint. Vault rep test hanger void to 5,000 psi 15 min. Centerlift conduct cable and cap line test at surface. Worley vac truck Fluid transfer. Remove all extra tubing from pipe shed. Operation at 07.00 Cleaning pits. Troubleshoot Iron Roughneck. Time Log Start Time End Time Dur (hr) Cum Dur (hr)Phase Opr. Act. Plan Oper. Descr. 00:00 03:30 3.50 3.50 W.O. K 5 P PJSM. Change elevators, make up two 4.5” space out pup joints, make up upper and lower swivel joint connections, along with tubing hanger. Install two way check valve. Orientate hanger key slot. Add 10 BPH to the hole with 8.6 ppg NaCl/ 3% KCL brine inhibited with biocide. 03:30 08:30 5.00 8.50 W.O. K 12 P PJSM. Install penetrator connector splice, with splice being witnessed be ENI electrician. Perform electrical ESP cable checks, terminate capillary line through tubing hanger, and test capillary line void through tubing hanger to 5000 PSI all good. Pump through capillary lines (A) Line open at 4200, and closed at 1790 PSI. (B) Line opened at 3900 PSI and closed at 2400 PSI. Add 10 BPH to the hole with 8.6 ppg NaCl/ 3% KCL brine inhibited with biocide. 08:30 10:00 1.50 10.00 W.O. K 20 P PJSM. Attempt to land hanger, and set in the wellhead profile. Hanger would not land completely, pulled back to surface inspect seals and equipment found area were the hanger had set down next to alignment slot, rotated hanger slightly and was able to land the tubing hanger. UW 110K, DW 80K. Vault representative confirmed proper alignment and ran in LDS 10:00 12:00 2.00 12.00 W.O. K 20 P Baker perform electrical checks via umbilical cord, with test failing. Pulled hanger back to surface removed the umbilical and found that the adapter between the penetrator and the umbilical was bad. Installed umbilical and re-landed the tubing hanger with no issues, performed electrical checks all good. Vault tested upper and lower tubing hanger body seals to 5000 PSI for 10 minutes all good. 12:00 00:00 12.00 24.00 W.O. K 1 P PJSM. Lay down landing joint, clean and clear rig floor, remove all baker and GBR equipment from the rig floor. Remove and lay down ESP sheave in derrick, move 2-7/8” protectors from rig floor, and stage 5” protectors for laying down 5” DP. Clean pits, remove extra tubing from pipe shed. Note: 24 Hour Loss of 8.6 ppg Brine = 64 BBLs Total Loss of 8.6 ppg Brine = 7488.65 BBLs Daily Contacts Position Contact Name Company Title Email Office Mobile Company Representative Steve Lawrence ASRC Energy Services Drilling Supv. siddrilling@eni.com 907-685-0715 Company Representative Craig Smith ASRC Energy Services Drilling Supv. siddrilling@eni.com 208 816-6803 Company Representative Yelyzaveta Saprykina ASRC Energy Services Rig Clerk AKRigClerksDoyon15@eni.com 907-685-0722 Safety Representative Levi Karns ASRC Energy Services HSE Levi.Karns@external.eni.com 907-685-0721 Safety Representative Derek Ambrose Doyon Drilling HSE rig15@doyondrilling.com 907-685-0796 Tool Push Andrew Carlo Doyon Drilling Driller/Tool Pusher rig15@doyondrilling.com 907-685-0716 Tool Push Tom Shones Doyon Drilling Tool Pusher rig15@doyondrilling.com 907-685-0727 Last Casing Seat Cas. Type OD (in) ID (in) Grade Top (ftKB) Bottom (ftKB) TVD Bot. (ftKB) Landing Date LINER 5 1/2 4.95 L80 -13,937.1 13,996.9 3,786.6 1/31/2012 Well Name: SP23-N3 OR Wellbore Name: SP23-N3 Well Code: 26152 Job: WORKOVER WCEI Level: LEVEL 3 Daily Report Date: 5/4/2024 Report #: 19 Page: 1 of 1 Well Header Permit/Concession N° ADL-388583 Operator ENI PETROLEUM Subsidiary ENI Petroleum Co. Inc. Initial Lahee Code DEVELOPMENT WELL Rotary Table Elevation (ft) 40.89 Ground Level (ft) First Flange (ft) 4.09 RKB - Base Flange (ft) 36.80 RKB - Tubing Spool (ft) 31.91 Rig Information Rig Name RIG 15 Contractor DOYON Rig Type LAND RIG Rig Num 0723 Daily Information Weather Overcast Temperature (°F) 6.4 Wind NE @ 31 MPH Days LTI (days) 1,582.00 Days RI (days) POB 47.0 Daily Summary Operations 24h Forecast Continue trouble shooting Iron Roughneck. Run 5’ Drill pipe out of the derrick. Break and lay down each stand into the pipe shed. Nipple down BOPE and Nipple up tree. Perform passport testing. 24h Summary Doyon Electrician and Mechanic Continue Trouble shoot Iron Roughneck. Clean and organize pipe shed. Empty and clean pits. Operation at 07.00 Clean and organize pipe shed and rig floor. Time Log Start Time End Time Dur (hr) Cum Dur (hr)Phase Opr. Act. Plan Oper. Descr. 00:00 12:00 12.00 12.00 W.O. K 1 U PJSM. Trouble shoot ST-100 Roughneck jaws not clamping, SIMOPS Clear pipe shed of 4.5” tubing. Clean and organize and clear pipe shed of 2-7/8” PH-6 drill pipe. Remove all tools not needed for operations empty and clean pits for rig move, clean pressure wash and organize rig floor. Pressure wash ST-100 Roughneck and draw works. 12:00 00:00 12.00 24.00 W.O. K 1 U Trouble shoot ST-100 Roughneck jaws not clamping. SIMOPS Clear pipe shed of 4.5” tubing. Clean and organize and clear pipe shed of 2-7/8” PH-6 drill pipe. Remove all tools not needed for operations empty and clean pits for rig move, clean pressure wash and organize rig floor. Pressure wash ST-100 Roughneck and draw works. Logistics hauled off used tubing to AFP. Note: 24 Hour Loss of 8.6 ppg Brine = 0 BBLs Total Loss of 8.6 ppg Brine = 7488.65 BBLs Daily Contacts Position Contact Name Company Title Email Office Mobile Company Representative Steve Lawrence ASRC Energy Services Drilling Supv. siddrilling@eni.com 907-685-0715 Company Representative Craig Smith ASRC Energy Services Drilling Supv. siddrilling@eni.com 208 816-6803 Company Representative Yelyzaveta Saprykina ASRC Energy Services Rig Clerk AKRigClerksDoyon15@eni.com 907-685-0722 Safety Representative Levi Karns ASRC Energy Services HSE Levi.Karns@external.eni.com 907-685-0721 Safety Representative Derek Ambrose Doyon Drilling HSE rig15@doyondrilling.com 907-685-0796 Tool Push Andrew Carlo Doyon Drilling Driller/Tool Pusher rig15@doyondrilling.com 907-685-0716 Tool Push Tom Shones Doyon Drilling Tool Pusher rig15@doyondrilling.com 907-685-0727 Last Casing Seat Cas. Type OD (in) ID (in) Grade Top (ftKB) Bottom (ftKB) TVD Bot. (ftKB) Landing Date LINER 5 1/2 4.95 L80 -13,937.1 13,996.9 3,786.6 1/31/2012 Well Name: SP23-N3 OR Wellbore Name: SP23-N3 Well Code: 26152 Job: WORKOVER WCEI Level: LEVEL 3 Daily Report Date: 5/5/2024 Report #: 20 Page: 1 of 1 Well Header Permit/Concession N° ADL-388583 Operator ENI PETROLEUM Subsidiary ENI Petroleum Co. Inc. Initial Lahee Code DEVELOPMENT WELL Rotary Table Elevation (ft) 40.89 Ground Level (ft) First Flange (ft) 4.09 RKB - Base Flange (ft) 36.80 RKB - Tubing Spool (ft) 31.91 Rig Information Rig Name RIG 15 Contractor DOYON Rig Type LAND RIG Rig Num 0723 Daily Information Weather Overcast Temperature (°F) 6.8 Wind N @ 14 MPH Days LTI (days) 1,583.00 Days RI (days) POB 46.0 Daily Summary Operations 24h Forecast Nipple down BOPE and Nipple up tree. Perform passport testing. 24h Summary Doyon electrician and mechanic continue trouble shoot and fix Iron Roughneck. Run 5’ Drill pipe out of the derrick. Break and lay down each stand into the pipe shed. Start nipple down BOPE. Operation at 07.00 Nippling down BOPE. Time Log Start Time End Time Dur (hr) Cum Dur (hr)Phase Opr. Act. Plan Oper. Descr. 00:00 12:00 12.00 12.00 W.O. K 25 U PJSM. Trouble shoot ST-100 Roughneck jaws not clamping, clean and organize and inventory tools on rig floor in preparation for cold stack. Clean pump room chip and paint, clean and prep pits for paint, clean pipe shed and skate. Remove paint chips in bops’ and mezzanine deck. Begin organizing, relocation and segregating miscellaneous equipment around yard in preparation for rig move. Doyon’s Electrical Administrator along with Doyon Superintendent arrived and assisted rig electrician and mechanic. Through their combined efforts they were able to determine that a poppet in a hydraulic solenoid was stuck, the solenoid was disassembled and repaired, this allowed enough functions to laydown drill pipe from the derrick. 12:00 13:00 1.00 13.00 W.O. K 1 P Clean and clear rig floor, grease ST100, install mouse hole, and prep rig floor to laydown drill pipe from derrick. Perform derrick inspection. 13:00 22:00 9.00 22.00 W.O. K 1 P Lay down 5” Drill pipe from derrick using mouse hole. 22:00 22:30 0.50 22.50 W.O. K 1 P Remove mouse hole, remove tote of thread protectors and tools and equipment down beaver slide. Clear rig floor. 22:30 00:00 1.50 24.00 W.O. C 5 P Nipple down BOPE. Remove VBR’S from ram body. Disassemble break down BOPE for cold stack. Daily Contacts Position Contact Name Company Title Email Office Mobile Company Representative Steve Lawrence ASRC Energy Services Drilling Supv. siddrilling@eni.com 907-685-0715 Company Representative Craig Smith ASRC Energy Services Drilling Supv. siddrilling@eni.com 208 816-6803 Company Representative Yelyzaveta Saprykina ASRC Energy Services Rig Clerk AKRigClerksDoyon15@eni.com 907-685-0722 Safety Representative Levi Karns ASRC Energy Services HSE Levi.Karns@external.eni.com 907-685-0721 Safety Representative Derek Ambrose Doyon Drilling HSE rig15@doyondrilling.com 907-685-0796 Tool Push Andrew Carlo Doyon Drilling Driller/Tool Pusher rig15@doyondrilling.com 907-685-0716 Tool Push Tom Shones Doyon Drilling Tool Pusher rig15@doyondrilling.com 907-685-0727 Last Casing Seat Cas. Type OD (in) ID (in) Grade Top (ftKB) Bottom (ftKB) TVD Bot. (ftKB) Landing Date LINER 5 1/2 4.95 L80 -13,937.1 13,996.9 3,786.6 1/31/2012 Well Name: SP23-N3 OR Wellbore Name: SP23-N3 Well Code: 26152 Job: WORKOVER WCEI Level: LEVEL 3 Daily Report Date: 5/6/2024 Report #: 21 Page: 1 of 1 Well Header Permit/Concession N° ADL-388583 Operator ENI PETROLEUM Subsidiary ENI Petroleum Co. Inc. Initial Lahee Code DEVELOPMENT WELL Rotary Table Elevation (ft) 40.89 Ground Level (ft) First Flange (ft) 4.09 RKB - Base Flange (ft) 36.80 RKB - Tubing Spool (ft) 31.91 Rig Information Rig Name RIG 15 Contractor DOYON Rig Type LAND RIG Rig Num 0723 Daily Information Weather Overcast Temperature (°F) 16.7 Wind NE @ 22 MPH Days LTI (days) 1,584.00 Days RI (days) POB 47.0 Daily Summary Operations 24h Forecast Reporting moved to Doyon 15 Cool Down Operation. 24h Summary Nipple down BOPE, nipple up tree and test void to 5000 PSI. Vault representative conduct passport testing. Centrilift Conduct final well head check on ESP and cap lines. Final Report for SP23-N3. Operation at 07.00 Doyon 15 Cool Down Operation. Time Log Start Time End Time Dur (hr) Cum Dur (hr)Phase Opr. Act. Plan Oper. Descr. 00:00 08:00 8.00 8.00 W.O. C 5 P PJSM. Nipple down BOP’s bleed down accumulator and remove all control lines. Remove rams from ram body, and stage in shop. Clean and lube ram cavities for storage. Remove choke and kill lines along with valves, staging valves in shop. Remove flow line, pitcher nipple and the drip pan. Remove BOP from riser and install on BOP stump. 08:00 14:00 6.00 14.00 W.O. C 20 P PJSM. Obtain work permits for work in wellhead room. Removed riser, inspected and cleaned top of tubing hanger. Vault terminate capillary lines through the wellhead. Install tree and test void to 5000 PSI for 20 minutes all good. Clean and clear wellhead room of tree installation tools and prep for passport testing. 14:00 19:30 5.50 19.50 W.O. C 12 P PJSM. Rig up testing equipment and perform passport test. Test hanger void on tree to 5k 20 min (Good test) Test #1 shell test 3,400 psi 10 min (Good test) Test #2 swab valve 3,400 psi 30 min (Good test) test #3 wing valve 3,400 psi 30 min, (Good test) Renew well bay permit, Pulled tree cap off, Removed TWV, installed tree cap, Fill lines, Test #4 tree cap 3,400 psi 10 min (Good test). 19:30 21:30 2.00 21.50 W.O. A 1 P Rig down vault test equipment in well bay, clean well bay. Flush lines and mud pumps with fresh water, blow down top drive back to pumps 21:30 00:00 2.50 24.00 W.O. A 1 P Organize parts house, wash all bops valves and place in parts house, Send all flow line sections to mezzanine, work on cold stack checklist. Note: Final Report for SP23-NE3 Workover. Daily Contacts Position Contact Name Company Title Email Office Mobile Company Representative Steve Lawrence ASRC Energy Services Drilling Supv. siddrilling@eni.com 907-685-0715 Company Representative Craig Smith ASRC Energy Services Drilling Supv. siddrilling@eni.com 208 816-6803 Company Representative Adam Groendyke ASRC Energy Services Rig Clerk AKRigClerksDoyon15@eni.com 907-685-0722 Safety Representative Levi Karns ASRC Energy Services HSE Levi.Karns@external.eni.com 907-685-0721 Safety Representative Derek Ambrose Doyon Drilling HSE rig15@doyondrilling.com 907-685-0796 Tool Push Andrew Carlo Doyon Drilling Driller/Tool Pusher rig15@doyondrilling.com 907-685-0716 Tool Push Tom Shones Doyon Drilling Tool Pusher rig15@doyondrilling.com 907-685-0727 Last Casing Seat Cas. Type OD (in) ID (in) Grade Top (ftKB) Bottom (ftKB) TVD Bot. (ftKB) Landing Date LINER 5 1/2 4.95 L80 -13,937.1 13,996.9 3,786.6 1/31/2012 Well Name: SP23-N3 OR Wellbore Name: SP23-N3 Well Code: 26152 Job: WORKOVER WCEI Level: LEVEL 3 Daily Report Date: 5/7/2024 Report #: 22 Page: 1 of 1 Well Header Permit/Concession N° ADL-388583 Operator ENI PETROLEUM Subsidiary ENI Petroleum Co. Inc. Initial Lahee Code DEVELOPMENT WELL Rotary Table Elevation (ft) 40.89 Ground Level (ft) First Flange (ft) 4.09 RKB - Base Flange (ft) 36.80 RKB - Tubing Spool (ft) 31.91 Rig Information Rig Name RIG 15 Contractor DOYON Rig Type LAND RIG Rig Num 0723 Daily Information Weather Overcast Temperature (°F) 23.0 Wind SW @ 6 MPH Days LTI (days) 1,585.00 Days RI (days) POB 54.0 Daily Summary Operations 24h Forecast Prep New Location for rig move to SP03. 24h Summary Clean and organize rig. Work on stack out checklist. Operation at 07.00 Prep New Location for rig move to SP03. Time Log Start Time End Time Dur (hr) Cum Dur (hr)Phase Opr. Act. Plan Oper. Descr. 00:00 06:00 6.00 6.00 W.O. M 1 P PJSM, Work on stack out checklist, Remove subs from rig floor. Lock out accumulator disconnect power, and utilities. Roll up cables from generator to spooler and move the generator along with spooler out of area. Disassemble pump 3 removed caps, seats and valves, and disconnect interconnects. 06:00 12:00 6.00 12.00 W.O. M 1 P PJSM, Trouble shoot ST100 raise and lower function control from remote panel, lower and pin support braces in pipe shed. Remove high pressure mud line disconnects under stairs. Rig down flow line dresser sleeve and pull back to pits. Disconnect and secure all lines on pits roof top, and dispose of rinse water in pits. 12:00 18:00 6.00 18.00 W.O. M 1 P PJSM, Continue to trouble shoot ST-100 on raising and lowering feature. Rig down pump #3, Electrical, communication cables from pump#3module, move pump #3 module to proper lcation.Rig down suit cases , fold up beaver slide, Rig down all scaffolding, set cover on valve house, move koomey module to proper location. 18:00 00:00 6.00 24.00 W.O. M 1 P PJSM, Blow down water lines in pits, put glycol, in pressure washer, tape up all inter connects double check mud pits are ready for rig move, install transport pup joint on top drive. Scrape and clean location with loader. Continue working on stack out checklist Daily Contacts Position Contact Name Company Title Email Office Mobile Company Representative Steve Lawrence ASRC Energy Services Drilling Supv. siddrilling@eni.com 907-685-0715 Company Representative Craig Smith ASRC Energy Services Drilling Supv. siddrilling@eni.com 208 816-6803 Company Representative Adam Groendyke ASRC Energy Services Rig Clerk AKRigClerksDoyon15@eni.com 907-685-0722 Safety Representative Mark Hubler ASRC Energy Services HSE mark.hubler@external.eni.com 907-685-0721 Safety Representative Derek Ambrose Doyon Drilling HSE rig15@doyondrilling.com 907-685-0796 Tool Push Tom Shones Doyon Drilling Tool Pusher rig15@doyondrilling.com 907-685-0727 Tool Push Andrew Yochum Doyon Drilling Tour Pusher rig15@doyondrilling.com 907-685-0716 Last Casing Seat Cas. Type OD (in) ID (in) Grade Top (ftKB) Bottom (ftKB) TVD Bot. (ftKB) Landing Date LINER 5 1/2 4.95 L80 -13,937.1 13,996.9 3,786.6 1/31/2012 Well Name: SP23-N3 OR Wellbore Name: SP23-N3 Well Code: 26152 Job: WORKOVER WCEI Level: LEVEL 3 Daily Report Date: 5/8/2024 Report #: 23 Page: 1 of 1 Well Header Permit/Concession N° ADL-388583 Operator ENI PETROLEUM Subsidiary ENI Petroleum Co. Inc. Initial Lahee Code DEVELOPMENT WELL Rotary Table Elevation (ft) 40.89 Ground Level (ft) First Flange (ft) 4.09 RKB - Base Flange (ft) 36.80 RKB - Tubing Spool (ft) 31.91 Rig Information Rig Name RIG 15 Contractor DOYON Rig Type LAND RIG Rig Num 0723 Daily Information Weather Overcast Temperature (°F) 24.4 Wind W @ 7 MPH Days LTI (days) 1,586.00 Days RI (days) POB 38.0 Daily Summary Operations 24h Forecast Prep for rig move to SP03. Set herculite and matting boards on SP03 24h Summary Work on cold stack checklist. Prep for rig move to SP03. Operation at 07.00 Prepping rig move. Time Log Start Time End Time Dur (hr) Cum Dur (hr)Phase Opr. Act. Plan Oper. Descr. 00:00 12:00 12.00 12.00 W.O. B 2 P PJSM, Remove and secure remote controls and camera from pipe skate. Disconnect and lower the 6” and 1” vent stacks on the pits roof. Rig down choke line under off driller side rig floor. Lay herculite and lay rig mats for rig footprint in front of SP03. Reposition accumulator hoses in preparation of spinning accumulator house on trailer. Blow down steam and water lines, fill up hot well and drain water tank. Move cuttings tank away from the rig, LOTO top drive and disconnect power cables in preparation of moving rig. 12:00 00:00 12.00 24.00 W.O. B 2 P PJSM, Continue to perform general housekeeping, remove herculite, scaffolding and chip ice around rig, and pick up miscellaneous tools and equipment around location. Check tire pressures on rig prior to move. PJSM, Remove stomper cylinder in mezzanine. Secure top drive to lower rail to driller side torque pad eye. Unplug cattle shoot light and hydraulic unit landing at pipe shed and secure cables and upper skidding section drip pan, unplug cooling hydraulic cooling fan lower to landing in pipe shed, remove fall arresters and drain hoses in bop’s deck, open wind wall flaps and exhaust clearance, flip up hand rail connector and remove hand rail section to allow choke hard line travel. PJSM for skidding rig floor. Went through check list on skidding rig. Daily Contacts Position Contact Name Company Title Email Office Mobile Company Representative Steve Lawrence ASRC Energy Services Drilling Supv. siddrilling@eni.com 907-685-0715 Company Representative Craig Smith ASRC Energy Services Drilling Supv. siddrilling@eni.com 208 816-6803 Company Representative Adam Groendyke ASRC Energy Services Rig Clerk AKRigClerksDoyon15@eni.com 907-685-0722 Safety Representative Mark Hubler ASRC Energy Services HSE mark.hubler@external.eni.com 907-685-0721 Safety Representative Derek Ambrose Doyon Drilling HSE rig15@doyondrilling.com 907-685-0796 Tool Push Tom Shones Doyon Drilling Tool Pusher rig15@doyondrilling.com 907-685-0727 Tool Push Andrew Yochum Doyon Drilling Tour Pusher rig15@doyondrilling.com 907-685-0716 Last Casing Seat Cas. Type OD (in) ID (in) Grade Top (ftKB) Bottom (ftKB) TVD Bot. (ftKB) Landing Date LINER 5 1/2 4.95 L80 -13,937.1 13,996.9 3,786.6 1/31/2012 Well Name: SP23-N3 OR Wellbore Name: SP23-N3 Well Code: 26152 Job: WORKOVER WCEI Level: LEVEL 3 Daily Report Date: 5/9/2024 Report #: 24 Page: 1 of 1 Well Header Permit/Concession N° ADL-388583 Operator ENI PETROLEUM Subsidiary ENI Petroleum Co. Inc. Initial Lahee Code DEVELOPMENT WELL Rotary Table Elevation (ft) 40.89 Ground Level (ft) First Flange (ft) 4.09 RKB - Base Flange (ft) 36.80 RKB - Tubing Spool (ft) 31.91 Rig Information Rig Name RIG 15 Contractor DOYON Rig Type LAND RIG Rig Num 0723 Daily Information Weather Overcast Temperature (°F) 20.7 Wind S @ 5 MPH Days LTI (days) 1,587.00 Days RI (days) POB 45.0 Daily Summary Operations 24h Forecast Move rig from SP23 to SP03 spot sub and pits over well. Continue rigging up. 24h Summary Prep for rig move to SP03. Operation at 07.00 Moving pits to mate up with sub. Time Log Start Time End Time Dur (hr) Cum Dur (hr)Phase Opr. Act. Plan Oper. Descr. 00:00 06:00 6.00 6.00 MOB B 2 P PJSM, Perform General housekeeping. Final checks for rig move. Remove all stair landings, install stomper cylinder in mezzanine deck. Vacuum all the water from duck ponds and water lines. Place plywood in between well bay and rig mats for spill containment. 06:00 12:00 6.00 12.00 MOB B 2 P PJSM, Removed and secured remote control and camera cables from pipe skate, disconnect and lower 6” and 1” vent stack on pits roof top. Rig down choke line on off drill side under rig floor. Blow steam lines and water lines. Fill up hot well and drain water tank. Move cutting tank. Lock out breaker panel and disconnect top drive power cables. 12:00 18:00 6.00 18.00 MOB B 2 P PJSM, General housekeeping, Get stomper cylinder in shop ready for shipping, Help set up Worley crane to pick and move koomey unit 180 degrees and repositioned back on trailer deck. 18:00 00:00 6.00 24.00 MOB B 2 P PJSM, Conduct final checks on inner connects between pits and rig. Pull sub off well bay crab sub over to matting board on SP03, Set sub down turn tires. Daily Contacts Position Contact Name Company Title Email Office Mobile Company Representative Bruce Simonson ASRC Energy Services Drilling Supv. siddrilling@eni.com 907-685-0715 Company Representative Craig Smith ASRC Energy Services Drilling Supv. siddrilling@eni.com 208 816-6803 Company Representative Adam Groendyke ASRC Energy Services Rig Clerk AKRigClerksDoyon15@eni.com 907-685-0722 Safety Representative Mark Hubler ASRC Energy Services HSE mark.hubler@external.eni.com 907-685-0721 Safety Representative Derek Ambrose Doyon Drilling HSE rig15@doyondrilling.com 907-685-0796 Tool Push Tom Shones Doyon Drilling Tool Pusher rig15@doyondrilling.com 907-685-0727 Tool Push Andrew Yochum Doyon Drilling Tour Pusher rig15@doyondrilling.com 907-685-0716 Last Casing Seat Cas. Type OD (in) ID (in) Grade Top (ftKB) Bottom (ftKB) TVD Bot. (ftKB) Landing Date LINER 5 1/2 4.95 L80 -13,937.1 13,996.9 3,786.6 1/31/2012 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 Changeout__ 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): 14,021 712 N/A N/A Casing Collapse Structural Conductor Surface 2,270 Intermediate 4,760 Production Liner slotted 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: Giorgio Iannucci 3/14/2024 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 N/A 20-Mar-24 139677598 4 1/2 3807 N/A Perforation Depth MD (ft): 6369 6369-13967 5.5 3895-3807 20" 13.375 160 9.6256369 2748 MD 6,870 5,020 160 2480 3895 160 2748 Length Size Proposed Pools: L80 TVD Burst 5,955 Perforation Depth TVD (ft): STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL 391283, 3885833, 388574 211-127 3700 Centerpoint Dr, Ste, 500, Anchorage, AK, 99503 50-629-23456-00-00 Eni US Operating CO. Inc. PRESENT WELL CONDITION SUMMARY AOGCC USE ONLY slotted Tubing Grade: Tubing MD (ft): N/A 3,807 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: SP23-N3 Amjad Chaudhry amjad.chaudhry@eni.com 907-865-3300 Well Operations Project Manager Nikaitchuq Schrader bluff Schrader Bluff 3806 13,967 m n P s 2 66 t ouuuttttttttttttt_____ N Form 10-403 Revised 06/2023 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov nucci p By Grace Christianson at 2:24 pm, Mar 14, 2024 A.Dewhurst 14MAR24 DSR-3/15/24 10-404 X X BOP test to 2500 psig Annular preventer test to 2500 psig VTL 3/27/2024JLC 3/27/2024 3700 Centerpoint Drive Suite 500 Anchorage, Alaska 99503 Phone: 907-865-3300 March 14, 2024 Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Application for Sundry Approval for SP23-N3 Rig Workover Dear Commissioners, ENI US Operating Co. Inc. hereby applies for a Workover Sundry for well SP23-N3. SP23-N3 was completed on Spy Island on February 3rd, 2012, with an electric submersible pump set at a depth of 5,929 MD. This ESP producer was completed without a packer. The well was started up for production on February 7 th,2012. In 2021 a second lateral was drilled, and the well was completed with a conventional ESP. Well continued producing until March 13 th, 2023, when an ESP failure occurred. Plan is to swap ESP completion with a new tubing and ESP system. The estimated date for beginning this work is March 20 th, 2024. Please find attached for the review of the Commission forms 10-403 and supporting documentation. If you have any questions or require further information, please contact Amjad Chaudhry at 907- 865-3300. Sincerely, Giorgio Iannucci Well Operations Project Manager Sincerely, SP23-N3 Workover Summary Page PTD#:211-127 Current Status SP23-N3 is currently shutdown. Scope of Work The scope of this workover is to pull out existing tubing and run new tubing and new ESP. General Well info Reservoir Pressure/TVD: This well is expected to have a static max bottom hole pressure of approximately 1100 psi (3,878 TVD) during the time of workover. SP23-N3 MASP Shut-in BHP (Max) 1,100 psi, 5.5 ppge Depth 3,878 ft. (TVD) Gradient 0.1 psi/ft MASP 712 psi Wellhead type/pressure rating: Vetco Gray, MB-247/5000 psi BOP configuration: Annular/pipe/blind rams/Mudcross/pipe TIFL/MIT-IA/MIT-OA: Intermediate csg 9 5/8 was tested to 800 psi on February 8th, 2021. Well type: Producer Estimated start date: March 20th, 2024. Drilling rig: Doyon 15 Sr. Drilling Engineer: Amjad Chaudhry: Amjad.chaudhry@eni.com Work: 907-865-3300 Well Operations Project Manager: Giorgio Iannucci: Giorgio.Iannucci@eni.com Work: 907-865-3300 Procedure: 1. MIRU Doyon 2. Bullhead 8.6 ppg brine down tubing through conventional ESP. 3. Bullhead brine down the Annulus A 4. ND tree, NU BOPE and test 5. POOH with 4-1/2 tubing. 6. Contingency: RIH with 9-5/8 Casing Scraper and clean / scrape to LHP 7. 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I 1 N o co o 0o co co co 0o co co co 1• W O N 1N N N N N N N N N N N IC > m 1 V V V V V V V V V V V �_ W E o I N N N N N N N N N N N N 0 0 0 W O 0 N i s 0) c c i• CI) a, �0 c y ; O 2-) Yr` Im U Uta fD A Z 11 F- m I o 0 0 0 0 0 0 0 0 0 U l o y m 1i U n 3 o E E I O E o o E II m` 0 0 0 0 0 0 0 0 0 0 0 0 o a M W W W W W W W W W LU W 3 L _, i 0 a C) 0 0 0 0 O co N M Z N o) U D 0 N O Z aA.----- a O CN Z . 07 io a Ce 0 O 4E ,42 O F- a UJ w Ce o LU J W Z Q O R N J Q. ca 7 0. o c r M0 `7 0 O G a .c-4- E U °' 0 J Q I-- enO Z M _N N O cn d N 1 CO a = N 1 n 1- Ca Q a NII Q Z • - O it .0 to Z All m M n >> m N F- 9 T- d 3 NN N Q' O• CD ) coo E 0 c a 2 0 Davies, Stephen F (DOA) From: Davies, Stephen F (DOA) Sent: Tuesday, July 09, 2013 6:07 PM To: 'michele.cesari@enipetroleum.com' Cc: Bettis, Patricia K(DOA); Okland, Howard D (DOA) Subject: Nikatichuq SP23-N3 (PTD#211-127): Missing Directional Survey Data Michele, During a reporting compliance check for the Nikatichuq SP23-N3 (PTD#211-127) development oil well, I noticed that ENI submitted printed reports for the final directional survey but we did not receive the corresponding digital data files. (See 20 AAC 25.071.) Could you please submit the final directional data for Nikatichuq SP23-N3 and Nikatichuq SP23-N3 PB1 in tab-delimited, ASCII text-file or Excel spreadsheet format via email or on a CD-ROM? I appreciate your help with this request. Regards, Steve Davies Sr. Petroleum Geologist Alaska Oil and Gas Conservation Commission (AOGCC) Phone: 907-793-1224 Fax: 907-276-7542 1 Bettis, Patricia K (DOA) From: Cesari Michele [Michele.Cesari@enipetroleum.com] Sent: Friday, July 19, 2013 11:41 AM To: Davies, Stephen F (DOA) Cc: Bettis, Patricia K(DOA); Okland, Howard D (DOA) Subject: RE: Nikatichuq SP23-N3 (PTD#211-127): Missing Directional Survey Data Attachments: SP23-N3PB1 ASP Final Survey.xlsx; SP23-N3 ASP Final Survey.xlsx Stephen, Attached are the Excel spreadsheets about SP23-N3 and SP23-N3 PB1 as per your request. If you need anything else, let me know. Thanks. Regards, Michele Cesari Jr Completion Engineer Anchorage, AK Office (Anchorage): (907) 865-3338 Cell: (907) 230-9701 Email: Michele.cesari@enipetroleum.com From: Davies, Stephen F (DOA) [mailto:steve.davies@alaska.gov] Sent: Tuesday, July 09, 2013 6:07 PM To: Cesari Michele Cc: Bettis, Patricia K (DOA); Okland, Howard D (DOA) Subject: Nikatichuq SP23-N3 (PTD# 211-127): Missing Directional Survey Data Michele, During a reporting compliance check for the Nikatichuq SP23-N3 (PTD#211-127) development oil well, I noticed that ENI submitted printed reports for the final directional survey but we did not receive the corresponding digital data files. (See 20 AAC 25.071.) Could you please submit the final directional data for Nikatichuq SP23-N3 and Nikatichuq SP23-N3 PB1 in tab-delimited,ASCII text-file or Excel spreadsheet format via email or on a CD-ROM? I appreciate your help with this request. Regards, Steve Davies Sr. Petroleum Geologist Alaska Oil and Gas Conservation Commission (AOGCC) Phone: 907-793-1224 Fax: 907-276-7542 1 This message may contain information that is confidential, and is being sent exclusively to the Recipient. If you are not the designated Recipient, you are prohibited from utilizing, copying or divulging the information contained in this message,or taking any action whatsoever on the basis of the information herein. If you have received this message by mistake, we ask you to kindly inform the Sender and to delete the message. It is understood that, with regard to messages sent by its network, the Company is not responsible for any statements made or opinions expressed, that are not strictly related to the Company's operations. 2 %% 4& STATE Alaska Oil and Gas °fALASKAConservation Commission =='- GOVERNOR SEAN PARNELL 333 West Seventh Avenue ALAS* Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 Marc Kuck Production Optimization Coordinator Eni US Operating Co. Inc. I I f 3800 Centerpoint Drive, Suite 300 Anchorage, AK 99503 Re: Nikaitchuq Field, Schrader Bluff Oil Pool, SP23-N3 Sundry Number: 313-147 Dear Mr. Kuck: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, • Cathy P. Foerster eAC'lay Chair DATED this of April, 2013. Encl. 4/ 1/;" STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS AO( C0 20 AAC 25.280 1.Type of Request: Abandon❑ Plug for Redrill❑ Perforate New Pool❑ Repair Well❑ Change Approved Program ❑ Suspend❑ Plug Perforations❑ Perforate❑ Pull Tubing •ElCInI► / ye�Time Extension 0/ Operations Shutdown Re-enter Susp.Well❑ Stimulate Alter Casing❑ Other: 1. en-nes? 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: ,( Eni US Operating Co.Inc. Exploratory ❑ Development Q ' 211-127 141. 3 3.Address: 6.API Number: Stratigraphic ❑ Service CI6. -.Z3 VA,-00-oma 3800 Centerpoint Drive,Ste.300,Anchorage,AK 99503 ?I43 n t3 7.If perforating: 8.Well Name and Number: 3/ What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require a spacing exception? Yes ❑ No ❑ SP23-N3 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL 391283,388583,388574 Nikaitchuq Schrader Bluff Oil Pool 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD(ft): Effective Depth TVD(ft): Plugs(measured): Junk(measured): 13,967 3807 13967 N/A N/A Casing Length Size MD TVD Burst Collapse Structural Conductor 160 20" 160 160 Surface 2748 13.375 2748 2480 5,020 2,270 Intermediate 6369 9.625 6369 3895 5,750 3,090 Production 7598 5.5 13967 3807 slotted slotted Liner Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 6369-13967- 3895-3807 4 1/2 L80 5,955 Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft): N/A N/A 12.Attachments: Description Summary of Proposal Q. 13.Well Class after proposed work: Detailed Operations Program Q • BOP Sketch O. Exploratory ❑ Stratigraphic❑ Development FM Service ❑ 14.Estimated Date for 1-Apr-13 15.Well Status after proposed work: Commencing Operations: Oil Q• Gas ❑ WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: WINJ ❑ GINJ ❑ WAG ❑ Abandoned ❑ Commission Representative: GSTOR ❑ SPLUG ❑ 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Michele Cesari Email michele.cesari(c�enipetroleum.com Printed Name Marc Kuck Title Production Optimization Coordinator Signature Phone Contac 907-865-3338 Date 3/26/2013 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 31 _ 1-1-7 Plug Integrity ❑ BOP Test m Mechanical Integrity Test ❑ Location Clearance ❑ Other: X- Ej Soo A S.- eD f ;:c r ...s APR 10 2013 Spacing Exception Required? Yes ❑ No Z Subsequent Form Required: /O,4--/611 APPROVED BY // Approved byIF: -f")�� COMMISSIONER THE COMMISSION Date: C�, -�-/3ry ryk / r . O i) tel•J�%3 Submit Form and \• nt, y� r ( i Approved application is valid for 12 months from the date of approval. , ( chments in Duplicate .1,\� C V los AOG CC tr Ileum em 3800 Centerpoint Drive Suite 300 Anchorage,Alaska 99503 Marc Kuck Phone(907)865-3322 Email: Marc.kuck@enipetroleum.com March 26th, 2013 Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage,Alaska 99501 RE: Application for Sundry Approval for SP23-N3 Rig Workover Dear Commissioners, ENI US Operating Co. Inc. hereby applies for a Workover Sundry for well SP23-N3. SP23-N3 was originally completed on February 3rd, 2012. The well was put on production on February 7th, 2012. The well was operated until November 12th 2012 when it would not surface fluid and was shut in. The ESP electrical system checked out positively. A pump change out was performed with E-line tractor on December 28th and a failure in the insert coupling pump-eye was found.The well was restarted on December 31st and it was operated until March 24th when a drop on amps was seen and it would not surface fluid anymore. The downhole electrical components of the ESP were tested and still maintain integrity, so a mechanical failure in the receiving coupling shaft is suspected. The estimated date for beginning this work is April 1St, 2013. Please find attached for the review of the Commission forms 10-403 and supporting documentation. If you have any questions or require further information, please contact Michele Cesari at 907- 865-3338. Sincerely, 610,4t___________ Marc Kuck Production Optimization Coordinator SP23-N3 Workover— Summary Page SP23-N3 Capital Rig Workover PTD#:211-127 Current Status Well SP23-N3 is currently shut in waiting for rig workover. Scope of Work Scope of this workover is to pull the current TTC-ESP tubing completion and run in with a new TTC-ESP system. General Well info Reservoir Pressure/TVD: The ESP downhole gauge are still functioning and reading 955 psi at 5955'MD/3,870'TVD on March 26 6. Reservoir depth is 6370'MD/3895'TVD. This well is expected to have a static max bottom hole pressure of approximately 1100 pduring the time of workover, which places the fluid level well below surface. Wellhead type/pressure rating: Vetco Gray, MB-247/5000 psi BOP configuration: Annular/pipe/blind rams/Mudcross/pipe TIFL/MIT-IA/MIT-OA: Due to the completion design these tests were not performed. Intermediate csg 9 5/8" was tested prior to drill out on January 2012. Well type: Producer Estimated start date: April 1St 2013 Drilling rig: Doyon 15 RWO Engineer: Marc Kuck: Marc.Kuck@enipetroleum.com Work: 907-865-3322 Procedure: 1. MIRU Doyon 15. 2. Shear lower GLM valve and circulate 8.6 ppg hot water with 3 % KCl kill fluid - through tree. 3. Set BPV. ND tree and NU BOP and test to 3500 psi. fi s- 4. Pull tubing to lower GLM. Rig up wireline and pull tubing stop check valve. 5. Circulate out remaining production fluid. Li7 3�d 6. Continue POOH and lay down ESP assembly. 7. MU new ESP assembly and RIH to setting depth. 8. Land hanger, and test it. 9. Install BPV and nipple down BOP. 10. NU tubing adapter and tree. 11. Pull BPV, install test plug and test tree.- w°°r T 12. Circulate Freeze protect through tree down IA. 13. Shut in well. 14. RDMO. Below the current schematic of the well: 4-W 12.6 ppf H563 Production eni Tubing petroleum SP23-N3 2,243'MD,2117,38°Inc-GLM,KBMG, 4-W x 1",with 2,000 psi STS-1 SOV Installed Oil Producer with 4-W x-cplg cable damps,for ESP ESP Lift Power Cable,(1)3/8'Chem Inj Line As Completed 111. 5750'MD,3855'TVD,86°Inc -GLM,KBMG, 4-W x 1", 02/03/2012 with 3,100 psi STS-1 SOV installed 5851'MD,3863'ND -Discharge Gauge Sub Surf.Casing +/""� 5955'MD,3870'ND,86°Inc —Bottom of Motor Centralizer 13-3/8',68#BTC � Centriitt,TTC-ESP,116-stage 380PI8SXD pump.513 GSB3 2,748'MD,2,481'NDseals,150 HP MSPI motor 49°Inc. •Wr 6176'MD,3,888 ND-Baker SLXP Liner Hanger/Packer Zonal Isolation Swell 5-W Silver Buffet Ecc. Packers Nose Guide Shoe Swell Packer MD's 18) = #1)7.486 ::.'> __w+"aiocker MD'sala01Slotted Liner, Interni Casing 5-W 15.5 ppf 9-5/8",40# 13,967'MD, 6369'MD,3895'ND 3807'TVD 89°Inc 91.5°Inc. Pkkaitchuq Field- Spy Island ups VetcoGray MB-247 SURFACE COMPLETION SYSTEM ,139 /CL e339 --15. 37.19 iàM. u 11<"glttroli 41..TAPly,' ',: �1 / v T.O.S. EL 25'5-3/4- I052 OFFSET OAB.O.S. EL 25'7-1/4- OP OF WELLHEAD 5.00- EL 25.2-1/4" TOP O 10 Al ci bFIT FEITOIHRu 21.6I 1�, [1" 13,..;50-375°.°17 3-5VO 51/.•37 30.°11P 00 PS, J _ 411 u4-1/19- �L 3000 P9 elltinc Rill _ • -- --- H . 1111 3.437 OFFSET 101.0 47 5a.- 111 1II p, . 5000 P3 1111 2-1 IPSI 11 •''�j I= ib.71 OUT OF POSRION i 'in. 13. 00 091 5295- C b 11:0807 3031 400. _:Ir \4t }`I:_ 34.00• OUT OF P051100 1.2 1II V. 15�3- I 1 18 a Fi TOP OF GRADING 1 ` EL 18T0l---1/4- L1.03 /11020121.4Y MI= at 20'OD 133f K-551--3 - 13-3/B-OD 581 L-80 4.4YM00 ENI ALASKA 9-5/8`OD 53.5#L-80 MULTI-BOWL SYSTEM 4-1/2.00 WITH 5-5/8 VR E 20 X 13-3/8 X 9-5/8 X 9dw1 X 4-1/2 WITH 8-5/8 VET AND ESP FLAT CABLE 31118 a -*ELI 'dim , ®6 H173370-1 uta; . 9 1.e PRP 10161. NC 10 OF 10 23 JANUARY 2009 0 GO Imagination m work L. •a B N J 4 in CD 1 'H: L., 0 5 0 P'' O N O.p C7U 4 ¢ Z N O D N w m a g o J BiS Erc �' a J o G z D. z O O? to: :0.. _p� a~ mm X U m m l- Q a N M IA CD 1- G ~O Q En O .o dp x El o02. ° 1,o i o L p❑ 0 J Z W V00 NIL ^ - C.) - C bijz - < JoZ -Og m O - - Z O S C �� Oma¢ §J X.7Z K ~N — g o U J M 'J` U W a ! a 6 J za m i. l-- g t. LI x m � m mg. i � �y, 6m 0 •b 1 "1! " 1 1 Itil IV II i iVT, i p Z a _ iI1�, - --- millittilliillaillir____, IIII . 1 V a a s lir I V ! W 1 ti l , i , -g ! `'- ! j -- /e�lul'=11 -Vs s xi I ce 1 I STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG la.Well Status: Oil Q Gas ❑ SPLUG ❑ Other ❑ Abandoned ❑ Suspended❑ 1b.Well Class: 20AAC 25.105 20AAC 25.110 Development [ Exploratory ❑ GINJ ❑ WINJ❑ WAG ❑ WDSPL❑ No.of Completions: Service ❑ Stratigraphic Test ❑ 2.Operator Name: 5.Date Comp.,Susp.,or 12.Permit to Drill Number: ENI US Operating Co. Inc. Aband.: 2/4/2012 211-127 3.Address: 6.Date Spudded: 13.API Number: 3800 Centerpoint Drive,Ste.300,Anchorage,AK 99503 1/4/2012 50-029-23456-00-00 4a.Location of Well(Governmental Section): 7.Date TD Reached: 14.Well Name and Number: Surface: 4449.8 FSL 1374.2 FEL S19 T14N R9E UM 1/28/2012 SP23-N3 Top of Productive Horizon: 8.KB(ft above MSL): 53.99 15.Field/Pool(s): 3518 FSL 3598 FEL 19 T14N R9EUM GL(ft above MSL): 13.1 Nikaitchuq/Schrader Bluff Oil Pool Total Depth: 9.Plug Back Depth(MD+TVD): 3699 FSL 3807 FEL 13 T14N R8EUM N/A 4b.Location of Well(State Base Plane Coordinates,NAD 27): 10.Total Depth(MD+TVD): 16.Property Designation: Surface: x- 511535.62 y-6053631.53 Zone- 4 14021'MD/3804'TVD ADL 391283,388583,388574 TPI: x- 509316.93 y-6052696.34 Zone- 4 11.SSSV Depth(MD+TVD): 17.Land Use Permit: Total Depth: x- 504017.11 y-6058152.50 Zone- 4 N/A ADL 417493 18.Directional Survey: Yes Q No LI 19.Water Depth,if Offshore: 20.Thickness of Permafrost MD/TVD: (Submit electronic and printed information per 20 AAC 25.050) 13.1 (ft MSL) 1828'MD/1766'TVD 21.Logs Obtained(List all logs here and submit electronic and printed information per 20AAC25.071): 22.Re-drill/Lateral Top Window MD/TVD: GR/RE_S/NEU/Den N/A 23. CASING,LINER AND CEMENTING RECORD WT.PER SETTING DEPTH MD SETTING DEPTH TVD AMOUNT CASING GRADE TOP BOTTOM TOP BOTTOM HOLE SIZE CEMENTING RECORD FT. PULLED 20 178.89 X-65 37.04 160 37.04 160 Driven N/A N/A 10.7 ppg ASL: 455 bbls 13.375 68 L-80 36.8 2748 36.8 2480 16 12.5 ppg DeepCRETE:82 bbls N/A 9.625 40 L-80 35.5 6369 35.5 3895 12.25 12.4 ppg DeepCRETE:202 bbls N/A 5.5 15.5 L-80 6175 13967 3888 3807 8.75 Slotted Liner N/A , ta,15 24.Open to production or injection? Yes No[ j If Yes,list eac TUBING RECORD interval open(MD+TVD of Top&Botto n umber): SIZE DEPTH SET(MD) PACKER SET(MD/TVD) l-o'rrED L./NAL RECEIVED 4.5 5955' N/A 6,1607 - 34G7 r M 26. ACID,FRACTURE,CEMENT SQUEEZE,ETC. 3k/C - 3:07 ` T D MAR 12 2012 DEP H INTERVAL(MD) AMOUNT AND KIND OF MATERIAL USED Alaska Oil&Gas Con g.Comm sion A 27. PRODUCTION TEST Date First Production: Method of Operation(Flowing,gas lift,etc.): 2/6/2012 E_SP Date of Test: Hours Tested: Production for Oil-Bbl: Gas-MCF: Water-Bbl: Choke Size: Gas-Oil Ratio: 2/9/2012 24 Test Period -950 146 0.1 128/64 N/A Flow Tubing Casing Press: Calculated Oil-Bbl: Gas-MCF: Water-Bbl: Oil Gravity-API(corr): Press. 259 1 24-Hour Rate - 950 146 0.1 18.5 28. CORE DATA Conventional Core(s)Acquired? Yes❑ No 0 Sidewall Cores Acquired? Yes ❑ No❑✓ If Yes to either question,list formations and intervals cored(MD+TVD of top and bottom of each),and summarize lithology and presence of oil,gas or water (submit separate sheets with this form,if needed).Submit detailed descriptions,core chips,photographs and laboratory analytical results per 20 AAC 25.071. i4 ! a 1F `nil RBDMS MAR 12011 . 4^ A. Form 10-407 Revised 12/2009 CONTINUED ON REVERSE lit_ 7•/O.13 Submit original only • 29. GEOLOGIC MARKERS (List all formations and markers encountered): 30. FORMATION TESTS NAME MD TVD Well tested? UYes L4lo If yes,list intervals and formations tested, briefly summarizing test results.Attach separate sheets to this form,if Permafrost-Top surf surf needed,and submit detailed test information per 20 AAC 25.071. Permafrost-Base 1828 1766 OA sand top 6154 3886 Formation at total depth: OA sand 14021 3806 31. List of Attachments: Directional Survey,As Run Wellbore Schematic,Well Operations Summary 32. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Michele Cesari(907)865-3338 Printed Name: Maurizio Grandi Title: Well Operations Project Manager Signature: pV K.4/(/1 Phone: (907)865-3320 Date: 3/5/2012 INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. Item 1b: Classification of Service wells: Gas Injection,Water Injection,Water-Altemating-Gas Injection,Salt Water Disposal,Water Supply for Injection,Observation,or Other.Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 4b: TPI(Top of Producing Interval). Item 8: The Kelly Bushing and Ground Level elevations in feet above mean sea level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 13: The API number reported to AOGCC must be 14 digits(ex:50-029-20123-00-00). Item 20: Report true vertical thickness of permafrost in Box 20. Provide MD and TVD for the top and base of permafrost in Box 28. Item 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 24: If this well is completed for separate production from more than one interval(multiple completion),so state in item 1,and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced,showing the data pertinent to such interval). Item 27: Method of Operation: Flowing,Gas Lift,Rod Pump,Hydraulic Pump,Submersible,Water Injection,Gas Injection,Shut-in,or Other (explain). Item 28: Provide a listing of intervals cored and the corresponding formations,and a brief description in this box. Submit detailed description and analytical laboratory information required by 20 AAC 25.071. Item 30: Provide a listing of intervals tested and the corresponding formation,and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Form 10-407 Revised 12/2009 • g U U 0) W o Nij) N QQQ 4) 4-+ L M 3 > 0 p , Otitn +- - 0 0 aW M L y 4 N U) O \ MMOL O w t~ a) .N p (n to T- o Z \ Z i C� J C. oN to N n- Eo EL ocn o a LM o w m a) x V)JE•. a W V 0 (...) co _ Q m a) f O U �, Q c ccn 0 x ,� Q c Na :: Cp X ^L _c \ C LL Cl) c 3 X 0 o d N 0 mCO x m = M Y Y O rn m I ,� _I -0 � � p Q I I 0d J (� - E > 2 U 0 .- N m W E U N a 00 C O C 'C Q (a/) (4 CO0 2 4- a) o > Ow .e 11 _ J m Q� 00 � Q ootid d c .c U co CO 0co 0 � -T) -7- l�C) � M CO asa01 Lo U Z co U N co Q 0 C0 00 CO O p p U - - co -c to U cn 0 O o_ N 1- U 2 0 to °° co - _x 4) O Mco O) co MO- D 4 d 0 co 4I- N O N N \\ \\ \i .0111111tIkiiiixilk\- 1* ,-.4 CO 1‘ 7U0 � aOo � � N P p � � tnv_ F Yl� oorn :- =( _ __ - usm , 00 N M (0 co � C W *k k *k UoN - a) o a) E . Q O) s a CI) Cr) CO c al CO 1 0 - N z cn Eni E&P Division I Well Name:SP23-N3 1/11* ENI Petroleum Co.Inc. Daily Report Well Code:26152 Field Name:Nikaitchuq • API/UW:50-629-23456-00-00 2^n Date:1/2/2012 - Report#: 1 II II II page 1 of 1 Wellbore name: SP23-N3 Well Header Permit/Concession N° Operator ENI Share(%) Well Configuration type • 211127 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(m) Ground Level(m) Water Depth(m) RKB-Base Flange(m) RKB-Tubing Spool(m) 12.46 16.46 3.99 11.22 9.73 Rig Information Contractor Rig Name Rig Type Job Information Wellbore Job Phase Spud Date Target Depth(mKB) Target Depth(TVD...Depth Dr.(MD)(m) Drilling Hours(hr) Avg ROP(mlhr) DFS(days) SP23-N3 DRILLING 1/6/2012 4,250.74 1.163.32 5.315.68 200.06 26.6 -3.69 Daily Information End Depth(mKB) End Depth(TVD)(... Depth Progress(m) Drilling Hours(hr) Avg ROP(m/hr) POB Temperature(°C) Weather Wind 0.00 101.0 -25.7 Clear,WC-21' 357'N @ 5.8 mph Daily summary operation 24h Summary RD and move rig to Well SP23-N3 Operation at 07.00 N/U diverter system. 24h Forecast Spot modules over well,secure location,hookup diverter line and system and prep.for spud. Lithology Shows MAASP(kgflcm°) Mud Weight(gIL) Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00.00 15:30 15.50 15.50 MOB A 2 P Prep.rig for move.Clean pad and remove utility suit cases,lay herculite and matt boards and secure location. 15.30 18:00 2.50 18.00 MOB A 2 P B/D all water,mud and steam lines and break connections.Skid ng floor. 18.00 22:00 4.00 22.00 MOB A 2 •P PJSM.Move sub over well SP23-N3 and skid floor back to dolling position.R/U rig floor service lines. 22.00 00:00 2.00 24.00 MOB A 2 P PJSM.Crane section of diverter line from well bay,weld saddle and install proper diverter line section. Daily Contacts Position Contact Name Company Title E-mail Office Mobile - Eni representative Mike Ross ENI Senior Drilling Supv 'SIDDrilling@enipetroleum.com 907-685-0715 Eni representative Russ Wimmer ENI Drilling Supv. SIDDnlling@enipetroleum.com 907-685-0715 907-320-0058 Eni representative Geoff Ackerman ENI HSE geoff.ackerman@enipetroleum.co 907-685-0721 Tool Push Dave Evans Doyon Drilling Tool Pusher ng15@doyondrilling.com 907-685-0716 Eni representative Tom Norvig ENI Drilling Rig Clerk AKRigClerksDoyon15@enipetroleum.com 907-685-0722 229-6100 Tool Push Pete Maninusen Doyon Dulling Tour Pusher ng15@doyondrilling.com 907-685-0716 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(mKB) Bottom(mKB) Run Date Last Leakoff Test Depth(mKB) TVD(mKB) Fluid Type Fluid Density(gIL) P Surf Applied(kgflcm°) Eq.Mud Weight(gIL) P LeakOff(kgflcm°) I r ( I • 1 D Eni E&P Division [Well Name:SP23-N3 ENI Petroleum Co.Inc. Daily Report Well Code:26152 Field Name:Nikaitchuq 2^fl Date:1/3/2012 - Report#: 2 API/MI:50-629-23456-00-00 II I)IIpage 1 of 1 wellbore name: SP23-N3 Well Header Permit/Concession N° Operator ENI Share(%) Well Configuration type • 211127 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(m) Ground Level(m) Water Depth(m) RKB-Base Flange(m) RKB-Tubing Spool(m) 12.46 16.46 3.99 11.22 9.73 Rig Information Contractor Rig Name Rig Type DOYON DRILLING DOYON 15 LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(mKB) Target Depth(TVD...Depth Dr.(MD)(m) Drilling Hours(hr) Avg ROP(m/hr) DFS(days) SP23-N3 DRILLING 1/6/2012 4,250.74 1.163.32 5,315.68 200.06 26.6 -2.69 Daily Information End Depth(mKB) End Depth(TVD)(... Depth Progress(m) Drilling Hours(hr) Avg ROP(m/hr) POB Temperature(°C) Weather Wind 0.00 100.0 -33.4 Partly Cloudy.WC- 196'SSW @ 9.2 52.8` mph Daily summary operation 24h Summary Spot modules over well,secure location,hookup diverter line and system and prep.for spud. Operation at 07.00 Picking up 5"drill pipe. 24h Forecast Complete rig up,berming and diverter installation.Pick up 5"drill pipe and stand back. Note;Continue monitoring flow back from Well SP27-N1. Lithology Shows MAASP(kgf/cm') Mud Weight(gIL) Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 0000 01:30 1.50 1.50 MOB A 2 P PJSM.Complete installing outside diverter line extensions. 01:30 05:30 4.00 5.50 MOB A 2 P Move and spot pd complex. 05:30 12:00 6.50. 12.00 MOB A 2 P Moving#3 pump to spot.R/U all service lines,swap to rig generator and finish RIU on manifold bldg.suitcase and transfer lines. 12:00 18:00 6.00 18.00 MOB A 2 P Spot#3 pump skid and install lines.Spot and hookup service buildings.N/U diverter system. 18:00 00:00 6.00 24.00 MOB A 2 P Complete N/U of Vetco well head equipment and diverter bag.Vetco tested starter head and riser to 500 psi f/10 min. PJSM.spot rock washer unit and berm area.Prep diverter line for installation in cellar. Note;As of 2400 hrs.Fow back test from SP27-N1 400 bbls.16%oil,.9%sediment.83.1%mud.WH-216 psi @ 54.6 degree.OA-205 psi. Daily Contacts Position Contact Name Company _ Title E-mail Office Mobile Eni representative Jack Keener ENI Senior Dulling Supv SIDDdlling@enipetroleum.com 907-685-0715 715-6434 Eni representative Russ Wimmer ENI Dulling Supv. SIDDnlling@enipetroleum.com 907-685-0715 907-320-0058 Eni representative Jack Potter ENI HSE jack.potter@enipetroleum.com 907-685-0721 Eni representative Tom Norvig ENI Drilling Rig Clerk AKRigClerksDoyon 15@enipetroleum.corn 907-685-0722 229-6100 Tool Push Dave Evans Doyon Drilling Tool Pusher rig15@doyondrilling.com 907-685-0716 Tool Push Pete Martinusen Doyon Dulling Tour Pusher rig15@doyondrilling.com 907-685-0716 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(mKB) Bottom(mKB) Run Date Last Leakoff Test Depth(mKB) TVD(mKB) Fluid Type Fluid Density(gIL) P Surf Applied(kgflcm°) Eq.Mud Weight(gIL) P LeakOff(kgflcm') Eni E&P Divisionwen Name:SP23-N3 Petroleum Co.Inc. Daily Report Well Code:26152 • Field Name:Nikaitchuq $1191* � API/IIWI:50-629-23456-00-00 2^ Date:1/4/2012 - Report#: 3 tri II page 1 of 1 Wellbore name: SP23-N3 Well Header Permit/Concession N° Operator ENI Share(%) Well Configuration type 211127 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(m) Ground Level(m) Water Depth(m) RKB-Base Flange(m) RKB-Tubing Spool(m) 12.46 16.46 3.99 11.22 9.73 Rig Information Contractor Rig Name Rig Type DOYON DRILLING DOYON 15 LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(mKB) Target Depth(TVD...Depth Dr.(MD)(m) Drilling Hours(hr) Avg ROP(m/hr) DFS(days) SP23-N3 DRILLING 1/6/2012 4,250.74 1,163.32 5,315.68 200.06 26.6 -1.69 Daily Information End Depth(mKB) End Depth(TVD)(... Depth Progress(m) Drilling Hours(hr) Avg ROP(m/hr) POB Temperature(°C) Weather Wind 0.00 103.0 -21.0 Mostly Cloudy.WC- 55'ENE @ 30 mph 56.5 Daily summary operation 24h Summary Complete rig up,berming and diverter installation.Pick up 5"drill pipe and stand back. Note;Continue monitoring flow back from Well SP27-N1. Operation at 07.00 Picking up 5"drill pipe. 24h Forecast P/U 5"drill pipe and rack back in derrick.Make spud mud and fill pits.P/U HWDP and rack back.M/U Bit and dolling easy.#1. Lithology Shows MAASP(kgflcm') Mud Weight(gIL) Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00:00 12:00 12.00 12.00 MOB A 20 P Set and bolt up suit cases going to WIF.Cont,rig up lines.Fab diverter line tie-up.Prep pipe shed to load drill pipe. 12:00 14:00 2.00 14.00 MOB C 20 P Weld up diverter line and N/U diverter system.Start loading 5"DP to pipe shed and strap. -!° 41111 14:00 15:00 1.00 15.00 MOB C 20 P PJSM.Function test diverter and inspect as per AOGCC specs.Witness waived by Man Harerra on 1-3-12 @ 11:45 hrs. 1)t V / 15:00 00:00 9.00 24.00 MOB A 20 P PJSM.Loading 5"DP in pipe shed.C/O saver sub to 4.5"IF. // Note:Flow Back of Well SP27-N1;Total of 1331 bbls.@ 39 HZ WH-200 psi,57 degrees,94%oil,6%mud w/TR sed.Lil Red injected total of 504 bbls @ 1.5 bpm.2860 psi. Daily Contacts Position Contact Name Company Title E-mail ' Office Mobile Eni representative Jack Keener ENI Senior Drilling Supv SIDDrilling@enipetroleum.com °907-685-0715 715-6434 Eni representative Russ Wimmer ENI Drilling Supv. SIDDrilling@enipetroleum.com 907-685-0715 907-320-0058 Eni representative Jack Potter ENI HSE jack.potter@enipetroleum.com 907-685-0721 Eni representative Tom Norvig ENI Drilling Rig Clerk AKRigClerksDoyonl5@enipetroleum.com 907-685-0722 229-6100 Tool Push Dave Evans Doyon Drilling Tool Pusher rig15@doyondnlling.com 907-685-0716 Tool Push Pete Martinusen Doyon Drilling Tour Pusher rig15@doyondnlling.com 907-685-0716 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(mKB) Bottom(mKB) Run Date Last Leakoff Test Depth(mKB) TVD(mKB) Fluid Type Fluid Density(g/L) P Surf Applied(kgflcm') Eq.Mud Weight(gIL) P LeakOff(kgflcm') 1111* Eni E&P Division I Well Name:SP23-N3 ENI Petroleum Co.Inc. Daily Report Well Code:26152 Field Name: Nikaitchuq • API/t/W1:50-629-23456-00-00 2^ Date:1/5/2012 - Report#: 4 II I' page 1 of 1 Wellbore name: SP23-N3 Well Header Permit/Concession N° Operator ENI Share(%) Well Configuration type 211127 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(m) Ground Level(m) Water Depth(m) RKB-Base Flange(m) RKB-Tubing Spool(m) 12.46 16.46 3.99 11.22 9.73 Rig Information Contractor Rig Name Rig Type DOYON DRILLING DOYON 15 LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(mKB) Target Depth(ND...Depth Dr.(MD)(m) Drilling Hours(hr) Avg ROP(mlhr) DFS(days) SP23-N3 DRILLING 1/6/2012 4,250.74 1,163.32 5,315.68 200.06 26.6 -0.69 Daily Information End Depth(mKB) End Depth(TVD)(... Depth Progress(m) Drilling Hours(hr) Avg ROP(m/hr) POB •Temperature(°C) Weather Wind 0.00 105.0 -27.4 Partly Cloudy.WC- 264'W @ 9.21 mph 39.8` Daily summary operation 24h Summary P/U 5"drill pipe and rack back in derrick.Make spud mud and fill pits.P/U HWDP and rack back.M/U Bit and drilling aasy.#1. Operation at 07.80 RIH with BHA#1 and tag bottom. 24h Forecast R/U wire line and Gyro tools.Perform dummy run with 13 5/8"hanger and landing jt.M/U BHA#1.Hold pre-spud meeting.Fill stack and check for leaks.Spud well. Lithology Shows MAASP(kgflcm') Mud Weight(g/L) Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00:00 00.30 0.50 0.50 MOB A 20 P Complete installation of saver sub. 00:30 07'00 6.50 7.00 MOB A 20 P PJSM.Load and process 5"drill pipe in pipe shed. 07:00 18.00 11.00 18.00 MOB A 20 P PJSM.M/U 5"DP in mouse hole and rack back in derrick for a total of 148 Stds. 18:00 20.00 2.00 20.00 MOB A 20 P M/U 5"HWDP in mouse hole and rack back,total of 6 stds. Note;Flow back from SP27-N1;2300 bbls total,98%oil,2%BSW,Tr-sediment @ 42 HZ,WH-200 psi,Flare.060 mmfcm. Injection last 24 hrs-952 bbls @ 1.5 bpm,2871 psi. Daily Contacts Position Contact Name Company Title E-mail _ Office Mobile Eni representative 'Jack Keener ENI Senior Drilling Supv SIDDnlling@enipetroleum.com 907-685-0715 715-6434 Eni representative Russ Wimmer ENI Drilling Supv. SIDDnlling@enipetroleum.com 907-685-0715 907-320-0058 Eni representative Jack Potter ENI HSE jack.potter@enipetroleum.com 907-685-0721 Eni representative Tom Norvig ENI Drilling Rig Clerk AKRigClerksDoyon15@enipetroleum.com 907-685-0722 229-6100 Tool Push Dave Evans Doyon Dulling Tool Pusher ng15@doyondrilling.com 907-685-0716 Tool Push ,Chad Johnson Doyon Dnlling Tour Pusher ng15@doyondrilling.com 907-685-0716 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(mKB) Bottom(mKB) Run Date Last Leakoff Test Depth(mKB) TVD(mKB) Fluid Type Fluid Density(gIL) P Surf Applied(kgflcm') Eq.Mud Weight(g/L) P LeakOff(kgf/cm') 111* En!E&P Division `Well Name:SP23-N3 ENI Petroleum Co.Inc. Daily Report Well Code:26152 Field Name:Nikaitchuq • 2^n Date:1/6/2012 - Report#: 5 API/t1W1:50-629-23456-00-00 II �'I) page 1 of 1 Wellbore name: SP23-N3 Well Header Permit/Concession N° Operator ENI Share(%) Well Configuration type 211127 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(m) Ground Level(m) Water Depth(m) RKB-Base Flange(m) RKB-Tubing Spool(m) 12.46 16.46 3.99 11.22 9.73 Rig Information Contractor Rig Name Rig Type DOYON DRILLING DOYON 15 LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(mKB) Target Depth(TVD..,Depth Dr.(MD)(m) Drilling Hours(hr) Avg ROP(mlhr) DFS(days) SP23-N3 DRILLING 1/6/2012 4,250.74 1,163.32 5,315.68 200.06 26.6 0.31 Daily Information End Depth(mKB) End Depth(TVD)(... Depth Progress(m) Drilling Hours(hr) Avg ROP(m/hr) POB Temperature(°C) Weather Wind 114.00 113.87 65.23 3.54 18.4 111.0 -26.0 Cloudy,WC-62.1" 223°WSW @ 21.87 mph Daily summary operation 24h Summary R/U wire line and Gyro tools.Perform dummy run with 13 5/8"hanger and landing jt.M/U BHA#1.Hold pre-spud meeting.Fill stack and check for leaks.Spud well. Operation at 07.00 Drilling ahead. 24h Forecast Drill ahead as per well plan. Lithology Shows MAASP(kgflcm') Mud Weight(g/L) 1054.5 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00'00 01:00 1.00 1.00 MOB A 20 P Bring BHA tools to rig floor. 01:00 01:30 0.50 1.50 MOB A 20 P M/U jar stand and rack back. 01:30 04:00 2.50 4.00 MOB A 20 P M/U surface casing hanger to landing jt.and perform dummy run. 04:00 06:00 2.00 6.00 MOB A 20 P UD hanger/landing jt.M/U stand of flex collars and rack back. 06:00 07:30 1.50 7.50 MOB A 20 P PJSM.R/U Halliburton Nine and Gyro equipment. 07:30 09:00 1.50 9.00 MOB E 19 P PJSM.FiII hole with mud,flow check diverter sys.and check for leaks. 09:00 10:00 1.00 10.00 MOB E '20 P PJSM.M/U BHA#1 as per Schlumberger. - 10:00 11:00 1.00 11.00 MOB E 20 P PJSM.Perform function test on all 3-mud pumps.Pressure test mud line to 3500 psi. 11:00 13:00 2.00 13.00 DRILL E 3 P PJSM.TIH with BHA#1.twice @ 67.Pump and rotate.Tag btm @ 132'.Clean conductor to 160'MD.550 qpm,131 spm,375 psi,20 rpm. 13'00 13.30 0.50 13.50 DRILL E 7 P Circulate.Hold pre-spud meeting. 13.30 16:30 3.00 16.50 DRILL E 4 P PJSM.POOH and P/U BHA#2. 16:30 18:00 1.50 18.00 DRILL E 3 P Slide f/160'-195'MD,500gpm,119spm,550psi,15-20k WOB,105 PUW,92 SOW,95 ROTW,11.10 ECD.Max gas-1 unit. 18:00 20:00 2.00 20.00 DRILL E 3 P Slide 1/195'-273'MD.470gpm,109spm,500psi,15-20k WOB,100k PUW,95k SOW,95k ROTW.10.96 ECD,Max gas-2 units. 20:00 20:30 0.50 20.50 DRILL E 11 P Blowdwn TD and Gyro @ 273'. 20:30 21:30 1.00 21.50 DRILL E 4 P Observe well.Pump OOH to 95'.P/U std of collars and RIH. 21:30 23:30 2.00 23.50 DRILL E 3 P Ddg 1/273'-374'MD 373'ND.550 gpm,650 psi On,500 psi Off,8-22k WOB,4 RPM,2k TO On,98k PUW,95k SOW,976 ROTW,10.4 ECD,Max Gas-4 units.AST-3.02,ART-.52,Bit-3.54,Jars-3.54. Note;Flow back of SP27-N1 Completed with 3301 bbls total,99%oil,1%BSW,TR sed.W/38 HZ. Lil Red Inject 1216 bbls @ 1.5bpm @ 2915 psi •SP27-N1 hooked up tp production @ 2100 hrs flowing 1000BPD @ 44 HZ. 23.30 00.00 0.50 24.00 DRILL E 11 P Blow dwn TD and Gyro @ 374'MD. Daily Contacts Position Contact Name Company Title E-mail Office Mobile Eni representative Jack Keener ENI Senior Dulling Supv SIDDrilling@enipetroleum.com 907-685-0715 715-6434 Eni representative Russ Wimmer ENI Drilling Supv. SIDDrilling@enipetroleum.com 907-685-0715 907-320-0058 Eni representative Jack Potter ENI HOE jack.potter@enipetroleum.com 907-685-0721 Eni representative Tom Norvig ENI Drilling Rig Clerk AKRigClerksDoyon15@enipetroleum.com 907-685-0722 229-6100 Tool Push Dave Evans Doyon Dnlling Tool Pusher ng15@doyondrilling.com 907-685-0716 Tool Push Chad Johnson Doyon Dolling Tour Pusher rig15@doyondrilling.com 907-685-0716 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(mKB) Bottom(mKB) Run Date Last Leakoff Test Depth(mKB) ND(mKB) Fluid Type Fluid Density(g/L) P Surf Applied(kgflcm') Eq.Mud Weight(gIL) P LeakOff(kgflcm') Eni E&P Division I Well Name: SP23-N3 WI* ENI Petroleum Co.Inc. Daily Report Well Code:26152 Field Name:Nikaitchuq • APIIUWI:50-629-23456-00-00 2^ii Date:1/7/2012 - Report#: 6 I' II page 1 of 1 Wellbore name: SP23-N3 Well Header Permit/Concession N` Operator ENI Share(%) Well Configuration type 211127 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(m) Ground Level(m) Water Depth(m) RKB-Base Flange)m) RKB-Tubing Spool(m) 12.46 16.46 3.99 11.22 9.73 Rig Information Contractor Rig Name Rig Type DOYON DRILLING DOYON 15 LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(mKB) Target Depth(ND...Depth Dr.(MD)(m) Drilling Hours(hr) Avg ROP(m/hr) DFS(days) SP23-N3 DRILLING 1/6/2012 4,250.74 1,163.32 5,315.68 200.06 26.6 1.31 Daily Information End Depth(mKB) End Depth(TVD)(... Depth Progress(m) Drilling Hours(hr) Avg ROP(mlhr) POB Temperature('C) Weather Wind 424.89 415.91 310.90 12.64 24.6 109.0 -31.6 Cloudy,WC-78.2` 208°SSW @ 23 mph Daily summary operation 24h Summary Drill ahead as per well plan. Operation at 07.00 Drilling ahead. 24h Forecast Drill ahead as per well plan to proposed surface total depth of 2.731'MD. Lithology Shows MAASP(kgf/cm') Mud Weight(gIL) 1090.4 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00.00 06:00 6.00 6.00 DRILL E 3 P Ddg and Gyro survey f/374'-646'MD(642'TVD)550 gpm,910 psi on,820 psi off,5-22k WOB,40 RPM,4-6k TO on,3k TO off,98k PUW,98k SOW.98 ROTW,10.01 ECD,Max gas-3 units. 2.33 ADT,1.65 AST,.68 ART,5.87 Bit,5.87 Jars 06:00 12.00 6.00 12.00 DRILL E 3 P Ddg.and Gyro survey 1/646-829'MD(822'ND)650 gpm,1080 psi on,840 psi off,40 RPM,4-6k TO on,3-4k TO off.8- 24k WOB.119k PUW,118K SOW,119k ROTW.9.83 ECD,Max gas-4 units. 2.19-ADT,1.48-AST,.71-ART,8.06-Bit,8.06-Jars. 12:00 16.00 4.00 16.00 DRILL E 20 P PJSM.C/O saver sub to TT 525. 16:00 18.00 2.00 18.00 DRILL E 3 P Dig and Gyro f/829'-983'MD(976'TVD)630 gpm,1050 psi.25-30 WOB,60 RPM,120k PUW,115k SOW,120k ROT/. 10.09 ECD,Max gas 13 units.Flow check-static. 18.00 00.00 6.00 24.00 DRILL E 3 P DrIg and Gyro f/983'-1394'MD(1365'TVD)800 qpm,1815 psi,35k WOB,60 RPM,8-10k TO,130k PUW,130k SOW. 130k ROTW,10.02 ECD,Max gas 16 units.3.04 ADT,1.92 AST,1.12 ART,11.10 Bit,11.01 Jars. R/D Halliburton and Gyro @ 2230 hrs. Daily Contacts Position Contact Name Company Title E-mail Office Mobile Eni representative Jack Keener ENI Senior Drilling Supv SIDDnlling@enipetroleum.com 907-685-0715 715-6434 Eni representative Russ Wimmer ENI Drilling Supv. SIDDnlling@enipetroleum.com 907-685-0715 907-320-0058 Eni representative Jack Potter ENI HSE jack.potter@enipetroleum.com 907-685-0721 Eni representative Tom Norvig ENI Dulling Rig Clerk AKRigClerksDoyonl5@enipetroleum.com 907-685-0722 229-6100 Tool Push Dave Evans Doyon Drilling Tool Pusher rig15@doyondrilling.com 907-685-0716 Tool Push Chad Johnson Doyon Drilling Tour Pusher rig15@doyondrilling.com 907-685-0716 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(mKB) Bottom(mKB) Run Date Last Leakoff Test Depth(mKB( TVD(mKB) Fluid Type Fluid Density(g/L) P Surf Applied(kgf/cm') Eq.Mud Weight(g/L) P LeakOff(kgflcm') • !If* Eni E&P Division I Well Name:SP23-N3 ENI Petroleum Co.Inc. Daily Report Well Code:26152 Field Name:Nikaitchuq • APIIUWI:50-629-23456-00-00 2^r,II Date:1/8/2012 - Report#: 7 'I II page 1 of 1 Wellbore name: SP23-N3 Well Header + Permit/Concession N° Operator ENI Share)%) Well Configuration type 211127 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(m) Ground Level(m) Water Depth(m) RKB-Base Flange(m) RKB-Tubing Spool(m) 12.46 16.46 3.99 11.22 9.73 Rig Information Contractor Rig Name Rig Type DOYON DRILLING DOYON 15 LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(mKB) Target Depth(TVD...Depth Dr.(MD)(m) Drilling Hours(hr) Avg ROP(mlhr) DFS(days) SP23-N3 DRILLING 1/6/2012 4,250.74 1,163.32 5,315.68 200.06 26.6 2.31 Daily Information End Depth(mKB) End Depth(TVD)(... Depth Progress(m) Drilling Hours(hr) Avg ROP(m/hr) •POB Temperature(°C) Weather Wind 641.86 758.85 416.97 7.60 54.9 106.0 -28.7 Cloudy.WC-70.6' 213°SSW @ 23 mph Daily summary operation 24h Summary Drill ahead as per well plan to proposed surface total depth of 2,762'MD.Circulate 4 bottoms up while back reaming.BROOH to 2350'. Operation at 07.00 POOH on elevators. 24h Forecast BROOH to HWDP and circ.hole clean.POOH on elevators and L/D BHA.R/U casing equipment and run 13 3/8"to btm.and circ.Cement casing inplace. Lithology Shows MAASP(kgflcm') Mud Weight(gIL) 1102.4 Time Log Start End Cum Time Time Dur(hr) Our(hr) Phase Opr. Act. Plan _ Oper.Descr. 00:00 06-.00 6.00 6.00 DRILL E 3 P Dig fl 1394'-2045'MD(1956'TVD)794 gpm,1660 psi on,1340 psi off.22-35k WOB,60 RPM,149k PUW,136k SOW. 141k ROTW,6-Sk TO on,4-6k TQ off,10.13 ECD,Max gas 402 units. 06:00 12.00 6.00 12.00 DRILL E 3 P Dig fl 2045'-2519'MD(2326'TVD)800 qpm,1760 psi on,1450 psi off,28-356 WOB,60 RPM,158k PUW,133k SOW, 143k ROTW,7-8k TQ on,4-66 TO off,10.01 ECD,Max gas 141 units.6.02 ADT,3.48 AST,2.54 ART,17.12 BIT,17.12 JARS. 12:00 17:00 5.00 17.00 DRILL E 3 P Ddg(/2519'-2762'MD(2490'TVD)TD for surf hole.780 gpm.1700 psi,35k WOB,60 RPM,164k PUW,142k SOW,150k ROTW,10-14k TQ on,8-10k TO off,9.82 ECD,Max gas 42 units.1.52 ADT,1.22 AST,.3 ART,18.64 Bit,18.64 Jars.Flow check-static. 17.00 00.00 7.00 24.00 DRILL E 7 P 'PJSM.Rotate and reciprocate while circulating 4-BU.BROOH at 800 gpm,1500 psi,80 rpm,4-6k TO,155k PUW,140k /SOW.II 2762'-2346'MD racking back 1 std.each BU.Stapping out of hole. Daily Contacts Position Contact Name _ Company Title E-mail Office Mobile Eni representative Jack Keener ENI :Senior Drilling Supv .SIDDnlling@enipetroleum.cum 907-685-0715 715-6434 Eni representative Russ Wimmer ENI Dulling Supv. SIDDnlling@enipetroleum.com 907-685-0715 907-320-0058 Eni representative Jack Potter ENI HSE jack.potter@enipetroleum.com 907-685-0721 Eni representative Tom Norvig ENI Drilling Rig Clerk AKRigClerksDoyon15@enipetroleum.com 907-685-0722 229-6100 Tool Push Dave Evans Doyon Dulling Tool Pusher ng15@doyondnlling.com 907-685-0716 Tool Push Chad Johnson Doyon Dulling Tour Pusher rig15@doyondnlling.com 907-685-0716 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(mKB) Bottom(mKB) Run Date Last Leakoff Test Depth(mKB) ND(mKB) Fluid Type Fluid Density(gIL) P Surf Applied(kgflcm') Eq.Mud Weight(gIL) P LeakOff(kgflcm') Eni E&P Division I Well Name:SP23-N3 fill* ENI Petroleum Co.Inc. Daily Report Well Code:26152 Field Name: Nikaitchuq • API/UWI:50-629-23456-00-00 eni Date:1/9/2012 - Report#: 8 - II 'I page 1 of 1 Wellbore name: SP23-N3 Well Header Permit/Concession N° Operator ENI Share(%) Well Configuration type 211127 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(m) Ground Level(m) Water Depth(m) RKB-Base Flange(m) RKB-Tubing Spool(m) 12.46 16.46 3.99 11.22 9.73 Rig Information Contractor Rig Name Rig Type DOYON DRILLING DOYON 15 LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(mKB) Target Depth(TVD...Depth Dr.(MD)(m) Drilling Hours(hr) Avg ROP(m/hr) DFS(days) SP23-N3 DRILLING 1/6/2012 4,250.74 1,163.32 5,315.68 200.06 26.6 3.31 Daily Information End Depth(mKB) End Depth(TVD)(... Depth Progress(m) Drilling Hours(hr) Avg ROP(m/hr) FOB Temperature(°C) Weather Wind 841.86 758.85 0.00 106.0 -32.0 Cloudy,WC-35.7° 192'WSW @ 5.8 mph Daily summary operation 24h Summary BROOH to HWDP and circ.hole clean.POOH on elevators and UD BHA.R/U casing equipment and run 13 3/8"casing. Operation at 07.00 • Running 13 3/8'casing. 24h Forecast Run 13 3/8'casing to 2748'.Circulate and condition mud for cement job.Cement casing as per plan and bump plug.N/D diverter system. Lithology Shows MAASP(kgf/cm') Mud Weight(g/L) 1126.4 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00:00 01:00 1.00 1.00 DRILL E 4 P PJSM.BROOH(/2346'-2234'MD 800 gpm,1650 psi,80 rpm.4-6k TQ.138k ROTW.circ.one BU per std.and rack back. 01:00 07:30 6.50 7.50 DRILL 'E 4 P Cont.BROOH f/2234'-830'MD,800 gpm,1400 psi,80 rpm,2-4k TO,102k ROTW.Encountered tight spots @ 2223'-2218', 2167'-2144',2020'-1942',1330'-1280'.SLM out of hole-checked OK. 07:30 09.00 1.50 9.00 DRILL E 7 P Circ.and reciprocate @ HWDP f/830'-735'MD 650 gpm,900 psi,45 rpm,2-3k TQ,102k ROTW.until hole was clean. 09:00 12.00 3.00 12.00'DRILL E 4 P B/D Top-drive.POOH on elevators 8830'-95'.Noted tight spots @ 303',190'work through.UD 3-jts hwdp,and rack 5-stds hvdp,1-jar std.Proper hole fill. 12:00 14.30 2.50 14.50 DRILL E 4 P PJSM POOH and L/D BHA.80k PUW,80k SOW 14:30 '15.00 0.50 15.00 DRILL E 20 P Clear and clean rig floor. 15:00 18:00 3.00 18.00 DRILL E 20 P PJSM.R/U to run 13 3/8"casing. 18:00 '00:00 6.00 24.00 DRILL G 4 P PJSM.Run 13 3/8'csg.684,L-80,BTC.as per well plan to 628'.120k PUW,90k SOW.Tested floats. Daily Contacts Position Contact Name Company Title E-mail Office Mobile Eni representative Jack Keener ENI Senior Drilling Supv SIDDrilling@enipetroleum.com 907-685-0715 715-6434 Eni representative Russ Wimmer ENI Dulling Supv. SIDDrilling@enipetroleum.com 907-685-0715 907-320-0058 Eni representative Jack Potter ENI HSE jack.potter@enipetroleum.com 907-685-0721 Eni representative Torn Norvig ENI Dulling Rig Clerk AKRigClerksDoyonl5@enipetroleum.com 907-685-0722 229-6100 Tool Push Dave Evans Doyon Drilling Tool Pusher rig15@doyondrilling.com 907-685-0716 Tool Push Chad Johnson Doyon Dulling Tour Pusher rig15@doyondrilling.cow 907-685-0716 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(mKB) Bottom(mKB) Run Date Last Leakoff Test Depth(mKB) TVD(mKB) Fluid Type Fluid Density(gIL) P Surf Applied(kgflcm') Eq.Mud Weight(gIL) P LeakOff(kgf/cm') . . • , Eni E&P Division ..} Well Name:SP23-N3 1 1 riff* ENI Petroleum Co.Inc. Daily Report Well Code:26152 Field Name: Nikaitchuq • API/UWI:50-629-23456-00-00 2^r, Date:1/10/2012 - Report#: 9 II II II page 1 of 1 Wellbore name: SP23-N3 • Well Header PermitlConcession N° Operator ENI Share(%) Well Configuration type 211127 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(m) Ground Level(m) Water Depth(m) RKB-Base Flange(m) RKB-Tubing Spool(m) 12.46 16.46 3.99 11.22 9.73 Rig Information Contractor Rig Name Rig Type DOYON DRILLING DOYON 15 LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(mKB) Target Depth(TVD...Depth Dr.(MD)(m) Drilling Hours(hr) Avg ROP(m/hr) DFS(days) SP23-N3 DRILLING 1/6/2012 4,250.74 1,163.32 5,315.68 200.06 26.6 4.31 Daily Information End Depth(mKB) End Depth(TVD)(... Depth Progress(m) Drilling Hours(hr) Avg ROP(m/hr) POE Temperature(°C) Weather Wind 841.86 758.85 0.00 101.0 -23.7 Clear,WC-15.7° 12°N @ 17.5 mph Daily summary operation 24h Summary P/U 13 3/8"csg(68#,L-80,BTC)1/2748'(Circulate(g 1800'one CBU)\Circulate and condition mud\UD Frank's tool and P/U cement head\Continue circulating-PJSM with Schlumberger for cement job\ Test lines 1/3500 psi.(leak on 1502 connections,replace one rubber and 15'cement hose on interconnect of rig.\Held PJSM-Schlumberger cemented 13 3/8"csg.in place @ 1916 hrs.with full returns- 180 bbls.10.7 ppg cement returns back to surface.\UD landing joint.\Flush stack and equipment-35 gal.spill with CH2MHill while draining diverter rise.\R/D GBR and cementing equipment-transfer fluids to WIF and clean pits. - Operation at 07.00 N/D 20"Diverter system. 24h Forecast Finish draining and flush out diverter and flow lines.\N/D Diverter stack./N/U Vetco Gray Multi-bowl./N/U 13 5/8"BOP stack and test as per AOGCC requirements.)P/U BHA#3 as per well plan.)Off line Clean active and prep for LSND mud. Lithology Shows MAASP(kgflcm') Mud Weight(gIL) 1126.4 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan I Oper.Descr. 0000 0200 2.00 2.00 DRILL G 4 P •RIH f/628'-1/1800'P/U 13 3/8"csg.(686,L-80.BTC)/Install centralizer as per well plan./Filling pipe every joint and top off every 10 its. 02:00 03:00 1.00 3.00 DRILL G 7 P Break circulation @ 1800'-stage pump rate from 21 gpm to 84 gpm with final pressure @ 200 psi.with 25%returns final- circulate one bottoms-up volume.\Dn wit=165K. 03:00 05:30 2.50 5.50 DRILL G 4 P Continue P/U 13 3/8"csg.(686,L-80,BTC)'f/1800'-P/U landing joint and set on depth @ 2748'./Up wt.=270K-Dn wt.= 165K. 05:30 07:00 1.50 7.00 DRILL G 7 P -Break circulate stage pump rate to 84 gpm @ 240 psi.)Reciprocate pipe 15'-Up wt=265K-Dn wt=197K\Monitor returns.\Load plugs in cement head.ENI reps.witness. 07:00 08:00 1.00 8.00 DRILL -G 20 P Land hanger and UD GBR Frank's fill-up-blow down top drive-P/U Schlumberger 13 3/8"cement head and install cement lines. 08:00 10:30 2.50 10.50 DRILL H 7 P Continue to circulate and condition mud while reciprocate 13 3/8"csg.through cement head pumping 210 gpm @ 175 psi.) Up wt.=250K-Dn wt.=185K\PJSM for cementing 13 3/8"csg.with Schlumberger and all parties involved. 10:30 14:00 3.50 14.00 DRILL H 20 XD99 Shut down mud pumps and switch to Schlumberger pump 10 bbls of water-test line to 3500 psi.No test-bleed off-check 1502 unions(replace rubber on cement line in suit case and replace 15'cement hose on top rock washer).\Schlumberger pump 10 bbls.water and retest line to 3500 psi.-good.\Crew change held PJSM w/Schlumberger.\Gave 24 hour .5 _,[ notification to AOGCC for BOP test @ 1300 hrs.and Lou Grimaldi returned call©1315 hrs.-will update tomorrow (,tJ"� morning. ?04 14:00 19:30 5.50 19.50 DRILL H 7 P Switched back rig pumping 98 bbls.of Mud Push II @ 10.1-rate of 5 bpm @ 130 psi.\Shut-down drop bottom plug./SLB mix&pump Lead slurry 455 bbls.@ 10.7 ppg.\ActicSet Lite 1067 sks.[2.45 Yield,mix water at 11.513 gal/sk.]-Pump rate of 5.5 bpm @ 380 psi.\SLB mix and pump Tail slurry 82 bbls.@ 12.5 ppg./DeepCRETE 300 sks.[1.56 Yield,mix H2O at 5.471 gat/sk.[-Pump rate of 3.0 bpm @ 280 psi.\Shut down&drop top plug-SLB pump 10 bbls H20.\Displace with 388 bbls.@ 9.4 ppg mud with ng pump at 8 bpm wd350 psi.-Reciprocating pipe-decreased rate to 4.2 bpm @ 490 psi.-land hanger with 170 bbls.of displacement away./With 378 bbls away slow pump to 3.1 bpm with 460 psi.FCP with full returns\ Bump plug to 540/psi,over FCP to 1000 psi.-Hold for 5 minutes and bleed off-check floats are holding-Good./Cement in place @ 1916 hrs.with a total of 180 bbls.10.7 ppg cement retums to surface. r 19:30 21 00 1.50 21.00 DRILL H 20 P UD landing joints.\Change bails and elevators./P/U 5"DP and M/U Johnny Wacker-flush diverter equipment and riser on cement contaminates with treated cement retarded fluids./Transfer fluids to WIF for injection and start cleaning active pits. 21:00 000 3 00 24.00 DRILL H 20 P ' 0Clean and clear ng floor-R/D GBR casing equipment.\Transfer fluids to WIF and clean pits.)While draining riser with CH2MHill super sucker @ 1024 hrs.-had a 35 gal spill on connection @ truck-Notified security and ACS-cleaned same Daily Contacts Position Contact Name Company Title E-mail Office Mobile Eni representative Jack Keener ENI Senior Dolling Supv SIDDrilling@enipetroleum.com .907-685-0715 715-6434 Eni representative David F Smith ENI Dulling Supv. SIDDnlling@enipetroleum.com 907-685-0715 632-3058 Eni representative Jack Potter ENI HSE jack.potter@enipetroleum.com 907-685-0721 Eni representative Tom Norvig ENI Drilling Rig Clerk AKRigClerksDoyonl5@enipetroleum.com 907-685-0722 229-6100 Tool Push Dave Evans Doyon Drilling Tool Pusher ng15@doyondrdling.com 907-685-0716 Tool Push Chad Johnson Doyon Drilling Tour Pusher rig15@doyondrilling.com 907-685-0716 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(mKB) Bottom(mKB) Run Date CASING 133/8 12.415 L80 10.99 837.59 1/10/2012 Last Leakoff Test Depth(mKB) TVD(mKB) Fluid Type Fluid Density(gIL) P Surf Applied(kgflcm') Eq.Mud Weight(gIL) P LeakOff(kgf/cm') Eni E&P Division I Well Name:SP23-N3 EN!Petroleum Co.Inc. Daily Report Well Code:26152 Field Name:Nikaitchuq Oil* • API/UWI:50-629-23456-00-00 2 II^rt Date:1/11/2012 - Report#: 10 II II page 1 of 1 Wellbore name: SP23-N3 • Well Header Permit/Concession N° Operator ENI Share(%) Well Configuration type 211127 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(m) Ground Level(m) Water Depth(m) RKB-Base Flange(m) RKB-Tubing Spool(m) 12.46 16.46 3.99 11.22 9.73 Rig Information Contractor Rig Name Rig Type DOYON DRILLING DOYON 15 LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(mKB) Target Depth(TVD...Depth Dr.(MD)(m) Drilling Hours(hr) Avg ROP(m/hr) DFS(days) SP23-N3 DRILLING 1/6/2012 4.250.74 1.163.32 5,315.68 200.06 26.6 5.31 Daily Information End Depth(mKB) End Depth(TVD)(... Depth Progress(m) Drilling Hours(hr) Avg ROP(m/hr) POB Temperature(Cl° Weather Wind 841.86 758.85 0.00 98.0 -32.1 Clear.WC-57.2` 233"WSW C 11.5 mph Daily summary operation 24h Summary R/D Schlumberger and GBR equipment.\Drain 20"diverter system and flush stack again.\N/D 20'Diverter system./N/U Vetco Gray Multi-bowl and test to 5000 psi f/10 mins./N/U 13 5/8"riser and BOP stack./Perform shell test\Test BOP test-AOGCC waived witness of BOP test.\Clean active pits and rack washer transfer to WIF for injected all fluids./Transfer LSND mud from mud plant. Operation at 07.00 P/U BHA#3 as per well plan with Schlumberger DD and MWD. 24h Forecast Finish testing BOP components with 5"and 5 1/2"tubular to AOGCC requirement(Lou Grimaldi with AOGCC waived witness of test).\P/U BHA#3 as per well plan./RIH 2500'+above float collar./ Perform 13 3/8"casing test to 2500 psi.f/30 mins.(chart record)\Drill out float/shoe and 20'-50'new hole./Displace well bore to new LSND mud.\Perform LOT/FIT\Drill ahead intermediate hole section.\ Load and prep 9 5/8"csg.in pipe shed. Lithology Shows MAASP(kgf/cm') Mud Weight(g/L) 1114.4 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00:00 0330 3.50 3.50 DRILL E 5 P Clear floor Schlumberger cement head and GBR casing equipment.\Clean drip pan under rig floor.\Drain 20"diverter and riser and wash out with H2O./Continue transferring mud to WIF for injection and clean active pits. 0330 07:00 3.50 7.00 DRILL E 5 P R/D turnbuckles,flow line and diverter line from spool-pull bell nipple./N/D 20"diverter system and set back on pedestal.\ Clean rig active pit and transfer fluids from rock wash to WIF.Called AOGCC Lou Grimaldi @ 0630 hrs.to update,plans to come out to witness BOP test @ 1900 hrs. 07 00 12.00 5.00 12.00 DRILL E 5 P Pull 20"riser and UD same./Pull well house top.\N/D starting head./N/U Vetco Gray Multi-bowl and well head valves.\ Test seals to 5000 psi for 10 minutes-good./Obtain RKB measurements:Top flange=31.35';Top lockdowns=31.94`, Lower lockdowns 34.74'.1 Set well house hatch cover on and N/U riser.\Continue cleaning active pits. 1200 17:00 5.00 17.00 DRILL E 5 P N/U 13 5/8"BOP stack-install choke&kill lines,bell nipple.flow lines,turn buckles and Koomey lines.\Finished installing wing valves on Vetco Gray multi-bowl.\Check accumulator bladders(pre-charge average 1075 psi.)and cleaned screens in suction lines of pumps. 1700 20:00 3.00 20.00 DRILL E 12 P Energize Koomey lines-function test BOP and install test plug(Netto Gray rep.)-R/U to test-fill stack with H2O and bled air off from equipment./Test all gas alarms-4 H2S and 4 LEL-Passed.\Lou Grimaldi w/AOGCC waived witness of BOP test @ 1820 hrs. 20 00 00.00 4.00 24.00 DRILL E 12 P Test BOP to AOGCC requirements on 5"tubuli;-Annular @ 250 psi./2500 psi.\Top pipe,choke manifold,kill manual stack&HCR valves,top drive and floors valves @ 250 psi./3500 psi.-Chart record all test for 5 mins.\Transfer LSND mud from mud plant to rig active pits. Daily Contacts Position Contact Name Company Title E-mail Office Mobile Eni representative Jack Keener ENI Senior Drilling Supv SIDDnlling@enipetroleum.com 907-685-0715 715-6434 Eni representative David F Smith ENI Drilling Supv. SIDDnlling@enipetroleum.com 907-685-0715 632-3058 Eni representative Jack Potter ENI HSE jack.potter@enipetroleum.com 907-685-0721 Eni representative Tom Norvig ENI Drilling Rig Clerk AKRigClerksDoyon15@enipetroleum.com 907-685-0722 229-6100 Tool Push Dave Evans Doyon Dolling Tool Pusher ng15@doyondrilling.com 907-685-0716 Tool Push Chad Johnson Doyon Dulling Tour Pusher rig15@doyondrilling.corn 907-685-0716 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(mKB) Bottom(mKB) Run Date CASING 133/8 12.415 L80 10.99 837.59 1/10/2012 Last Leakoff Test • Depth(mKB) TVD(mKB) Fluid Type Fluid Density(g/L) P Surf Applied(kgflcm') Eq.Mud Weight(g/L) P LeakOff(kgf/cm') r cti* Eni E&P Division (Well Name: SP23-N3 EN!Petroleum Co.Inc. Daily Report Well Code:26152 Field Name:Nikaitchuq • API/UWI:50-629-23456-00-00 2^ Date:1/12/2012 - Report#: 11 - II iI page 1 of 1 Wellbore name: SP23-N3 Well Header Permit/Concession N° Operator ENI Share(%) Well Configuration type 211127 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(m) Ground Level(m) Water Depth(m) RKB-Base Flange(m) RKB-Tubing Spool(m) 12.46 16.46 3.99 11.22 9.73 Rig Information Contractor Rig Name Rig Type DOYON DRILLING DOYON 15 LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(mKB) Target Depth(ND...Depth Dr.(MD)(m) Drilling Hours(hr) Avg ROP(m/hr) DFS(days) SP23-N3 DRILLING 1/6/2012 4,250.74 1,163.32 5,315.68 200.06 26.6 6.31 Daily Information End Depth(mKB) End Depth(TVD)(... Depth Progress(m) Drilling Hours(hr) Avg ROP(m/hr) POB Temperature(°C) Weather Wind 841.86 758.85 0.00 99.0 -31.7 Partly Cloudy.WC- 229 WSW @ 26.5 82.6 mph Daily summary operation 24h Summary Finish testing BOP components.\R/D test equipment and install wear bushing.\Held PJSM-P/U BHA#3-1/740'and performed shallow test tools.5 Slip 8 cut drilling line-service rig and inspect top dove -Schlumberger check block height calibration.\RIH 0740'-112607'\Circulate hole volume.\Perform 13 3/8"csg.test 2500 psi f/30 mins.\RIH circulating and ream(/2607'-1/2657'tag with 7K.5 Drill 1/2657'- 1/2696'cement and float collar(FC@ 2665').\Load pipe shed with 9 5/8'csg. Operation at 07.00 Displacing well to LSND mud and circulating 119.2 equal mud weights in/out.\Performing LOT/FR on 13 318"csg.shoe. 24h Forecast Finish drilling cement and shoe(/2696'-62748'-clean out old hole 112748'-1/2762'.6 Drill(2762'-1/2787'(25'new hole).\PJSM-Displace well to LSND mud 9.2 ppg.\Perform LOT/FIT\Doll ahead 12 1/4" intermediate hole section. Lithology Shows MAASP(kgficm') Mud Weight(g/L) 1114 4 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. - 00.00 05 00 5.00 5.00 DRILL 'E 12 P Completed testing BOP to AOGCC requirements on remaining 5"and 5 1/2"tubular.\Annular 250/2500 psi.on 5 1/2".5 Upper pipe 8 blind rams,mud cross choke manual valve and HCR's,retest floor dart valve(passed)to 250 psi./3500 psi.- Chart si-Chart record for 5 mins.\Koomey draw down test(Recovery times:f/1475-1/1675 psi.(200 psi.)in 30 seconds with final @ 3000 psi.in 196 seconds-5 Nitrogen bottles @ 2400 psi.average).\Tested A 8 B manual chokes and hydraulic choke to 1500 psi.-Flow tested gas buster-16 bbls.volume. 05:00 06:30 1.50 6.50 DRILL E 20 P •R/D test equipment and pull test plug-install wear ring(12 5/16")-Vetco Gray rep.\Blow down choke manifold and top drive. 06.30 14:30 8.00 14.50 DRILL E 4 P -PJSM-P/U BHA#3 as per well plan and Schlumberger DD/MWD 11740'\Surface test MWD with 750 gpm @ 1230 psi.\Up wt.=125K-Dn wt.=116K-Rot wt.=12010 K&M record parameters for BHA weight. • 14.30 17:00 2.50 17.00 DRILL E 25 P Slip and cut drilling line(adjust brake linkage)\Inspect top drive and service rig components.\Schlumberger check calibration of block height. 17.00 20:00 3.00 20.00 DRILL E 4 P RIH 1/740'-92607'\Up wt.=160K-Dn wt.=135K. 20.00 20:30 0.50 20.50 DRILL E 7 P Circulate with pump rate 710 gpm @ 1730 psi\Reciprocate and rotate stand 40 rpm @ 3-7K torque.\Up wt.=160K-Dn wt=135K-Rot v4=145K. 20.30 22:00 1.50 22.00 DRILL E 12 P R/U and circulated through lines to fluid pack,close upper pipe rams-perform 13 3/8"csg.test 1/2500 psi f/30 minutes (chart record).\R/D test equipment lines. 22.00 22:30 0.50 22.50 DRILL E 20 P Trouble shoot pressure gauge inconsistent after bleeding-off pressure,found stand pipe manifold beginning to freeze-up on sensor outlets-thawed out,cleared lines and sensors.\Reinstalled 8 tested gauge sensors.\Cover manifold and R/U heater duct to same. • 22 30 00:00 1.50 24.00 DRILL E 3 P RIH circulating and reaming(/2607'-112657'tag w/7K-Drill 1/2657'-1/2696'cement and float collar @ 2665'5 Pump rate 600 gpm @ 960 psi./40 rpm @ 6-10K torque\WOB=5-8K.5 Up wt.=160K-Dn wt=135K.-Rot wt.=145K. Daily Contacts Position Contact Name Company Title E-mail Office Mobile Eni representative Jack Keener 'ENI •Senior Drilling Supv SIDDnlling@enipetroleum.com 907-685-0715 715-6434 Eni representative David F Smith •ENI Drilling Supv. SIDDnlling@enipetroleum.com 907-685-0715 632-3058 Eni representative Jack Potter ENI HSE jack.poner@enipe11oleum.com 907-685-0721 Eni representative Tom Norvig ENI Drilling Rig Clerk AKRigClerksDoyon15@enipetroleum.com 907-685-0722 229-6100 Tool Push Steve Dambacher Doyon Drilling Tool Pusher rig15@doyondrilling.com 907-685-0716 Tool Push Chad Johnson •Doyon Drilling Tour Pusher rig15@doyondrilling.com 907-685-0716 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(mKB) Bottom(mKB) Run Date CASING 133/8 12.415 L80 10.99 837.59 1/10/2012 Last Leakoff Test Depth(mKB) ND(mKB) Fluid Type Fluid Density(gIL) P Surf Applied(kgflcm') Eq.Mud Weight(g/L) P LeakOff(kgflcm') 837.59 756.05 LSND mud 1096.4 26.7 1449.8 109.6 111* Eni E&P Division I Well Name:SP23-N3 ENI Petroleum Co.Inc. Daily Report Well Code:26152 Field Name:Nikaitchuq � APIIUWI:50-629-23456-00-00 2^ Date:1/13/2012 - Report#: 12 Ifl IIn page 1 of 1 Wellbore name: SP23-N3 Well Header Permit/Concession N° Operator ENI Share(%) Well Configuration type 211127 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(m) Ground Level(m) Water Depth(m) RKB-Base Flange(m) RKB-Tubing Spool(m) 12.46 16,46 3.99 11.22 9.73 Rig Information Contractor Rig Name Rig Type DOYON DRILLING DOYON 15 LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(mKB) Target Depth(TVD...Depth Dr.(MD)(m) Drilling Hours(hr) Avg ROP(m/hr) DFS(days) SP23-N3 DRILLING 1/6/2012 4,250.74 1,163.32 5,315.68 200.06 26.6 7.31 Daily Information End Depth(mKB) End Depth(TVD)(... Depth Progress(m) Drilling Hours(hr) Avg ROP(mlhr) POB Temperature(°C) Weather Wind 1,192.99 983.73 351.13 6.84 51.3 98.0 -29.6 Partly Cloudy,WC- 227'WSW @26.2 70 mph Daily summary operation 24h Summary Drill cement&shoe(/2696'-52748'.\Wash/team(/2748'-112762'(old hole)/Drill rotary 1/2762'-1/2787'(25'new hole).\Displace well bore to new LSND mud.clean surface equipment.\Circulate to equal 9.15 ppg mud weights in/out.\Perform LOT 12.1 ppg EMW Drill slide/rotary 1/2787'-1/3914'/Continue loading pipe shed with 9 5/8'csg and prep same. Operation at 07.00 Drilling ahead 12 1/4"intermediate hole section with mud motor assembly as per well plan. 24h Forecast Drill 12 1/4"intermediate hole section with mud motor assembly./Continue loading 9 5/8"csg.-strap and special drift to 8 3/4". Lithology Shows MAASP(kgflcm') Mud Weight(g/L) 1102.4 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00:00 0030 0.50 0.50 DRILL E 3 P Drill cement and shoe 1/2696'-1/2748'-Clean rat hole section f/2748'-5/2762'.\Pump rate 590 gpm @ 980 psi.\40 rpm @ 5 -10K torque./WOB=6-8K.\Up wt.=154K-Dn wt.=135K.-Rot wt.=147K, 00:30 01:00 0.50 1.00 DRILL E 3 P Drill slide/rotate f/2762'-1/2787'(25'new hole-2505'TVD)\Pump rate 610 gpm @ 1120 psi./45 rpm @ 6-9.5K torque./ WOB=8-14K.1 Up wt.=160K-Dn wt.=138K.-Rot wt.=148K.\Mud wt.=9.3 ppg./ECD=9.66 ppg.\ART=0.16 hrs./AST-- 0.0 ST=0.0 hrs.\ADT=0.16 hrs.\Jars=18.76 hrs. 01:00 03:30 2.50 3.50 DRILL E 7 P Circulate and reciprocate pipe 62787'-52707'\Held PJSM\Pumped 31 bbs.LSND viscosities spacer pill and displace well to new LSND 9.2 ppg.\Transfer fluids shipped to WIF.\420 gpm @ 710 psi.\40 rpm @ 6-8K torque.Up wt.=150K-Dn wt.=130K.-Rot wt.=148K. 03:30 04:00 0.50 4.00 DRILL E 20 P Shut down and clean surface equipment and lines on spud mud./Pull into shoe @ 2697'for LOT/FIT test. 04.00 05.00 1.00 5.00 DRILL E 7 P Circulate to balance mud weights 9.15 ppg in/out.\Pumping 426-gpm @ 630 psi.\Rotate and reciprocate pipe 40 rpm @4- ` 7K torque. \ 05.00 08:00 3.00 8.00 DRILL E 12 P R/U and perform FIT with 9.15 ppg_new LSND mu -EMW=12.1 ppg.\R/ and blow down lines./Off line.clean pit#5 from displacement and transfer fluids to WIF from roc washer. 08:00 12:00 4.00 12.00 DRILL E 3 P Dritl slide&rotate 62787'-1/3072'(2698'ND)-Pump a 900 gpm @ 17 psi./40/60 rpm @ 8-26K torque.\WOB=8- 30K/Up wt.=169K-Dn wt.=136K-Rot wt.=148K\MW= 15 ppg\EC 9.70 ppg.\ART=0.68 hrs.\AST=0.62 hrs.\ADT= 1.46 hrs.\Jars=20.06 hrs. 12:00 18:00 6.00 18.00 DRILL E 3 P Drill slide&rotate 1/3072'-1/3514'(2977'TVD)-Pump rate 900 gpm @ 1760 psi./40-60 rpm @ 8-30K torque./WOB=8- 32K\Up wt.=170K-Dn wt.=142K-Rot wt.=148K\MW=9.15 ppg\ECD 9.68 ppg.\ART=1.01 hrs.\AST=1.93 hrs.\ADT= 4.40 hrs.\Jars=23.0 hrs. 18.00 00:00 6.00 24.00 DRILL E 3 P Drill slide&rotate 1/3514'-1/3914'(3230'ND)-Pump rate 900 gpm @ 1950 psi./40-60 rpm @ 8-25K torque.\WOB=8- 30K\Up wt.=185K-Dn wt.=145K-Rot wt=160K\MW=9.15 ppg\ECD 9.70 ppg.\ART=1.08 hrs.\AST=1.36 hrs.\ADT= 6.84 hrs.\Jars=25.44 hrs. Total ADT=6.84 hrs. Total AST=3.91 hrs. Total ART=2.93 hrs. Total Jar=25.44 hrs. Daily Contacts Position Contact Name Company Title E-mail _ Office Mobile Eni representative Jack Keener ENI Senior Dolling Supv SIDDnlling@enipetroleum.com 907-685-0715 715-6434 Eni representative David F Smith ENI Dnlling Supv. SIDDrilling@enipetroleum.com 907-685-0715 632-3058 Eni representative Jack Potter ENI HSE jack.potter@enipetroleum.com 907-685-0721 Eni representative John Spaulding ENI Dulling Rig Clerk AKRigClerksDoyon15@enipetroleum.com 907-685-0722 355-2607 Tool Push Steve Dambacher Doyon Drilling Tool Pusher ng15@doyondrilling.com 907-685-0716 Tool Push Chad Johnson Doyon Dulling Tour Pusher ng15@doyondrilling.com 907-685-0716 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(mKB) Bottom(mKB) Run Date CASING 133/8 12.415 L80 10.99 837.59 1/10/2012 Last Leakoff Test Depth(mKB) TVD(mKB) Fluid Type Fluid Density(gIL) P Surf Applied(kgflcm') Eq.Mud Weight(gIL) P LeakOff(kgflcm') 837.59 756.05 LSND mud 1096.4 26.7 1449.8 109.6 ft* Eni E&P Division I Well Name:SP23-N3 ENI Petroleum Co.Inc. Daily Report Well Code:26152 Field Name: Nikaitchuq • APIIUWI:50-629-23456-00-00 2^ Date:1/14/2012 - Report#: 13 �I II page 1 of 1 Wellbore name: SP23-N3 Well Header Permit/Concession N° Operator ENI Share(%) Well Configuration type 211127 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(m) Ground Level(m) Water Depth(m) RKB-Base Flange(m) RKB-Tubing Spool(m) 12.46 16.46 3.99 11.22 9.73 Rig Information Contractor Rig Name Rig Type DOYON DRILLING DOYON 15 LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(mKB) Target Depth(TVD...Depth Dr.(MD)(m) Drilling Hours(hr) Avg ROP(mlhr) DFS(days) SP23-N3 DRILLING 1/6/2012 4,250.74 1,163.32 5,315.68 200.06 26.6 8.31 Daily Information End Depth(mKB) End Depth(TVD)(... Depth Progress(m) Drilling Hours(hr) Avg ROP(m/hr) POB Temperature(°C) Weather Wind 1,362.46 1.084.10 169.47 8.60 19.7 97.0 -33.0 Clear,WC-38 193`SSW @ 7.5 mph Daily summary operation 24h Summary Drill slide(88%)8 rotate(12%)1/3914'-1/4470'/Back ream minimum 30'before connection.\Finished prepping 9 5/8'csg. Operation at 07.00 Dolling ahead with mud motor assembly as per directional well plan. 24h Forecast Drilling 12 1/4"intermediate hole section with 1.50'mud motor assembly to 9 5/8"csg.point. Lithology Shows MAASP(kgflcm') Mud Weight(gIL) 1096.4 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00:00 06:00 6.00 6.00 DRILL E 3 P Drill slide&rotate 1/3914'-114192'(3393'TVD)-Pump rate 750 gpm @ 1630 psi.\60 rpm @ 7-18K torque.\WOB=10-28K\ Up wt.=186K-Dn wt.=138K-Rot wt.=162K\MW=9.2 ppg\ECD 9.62 ppg.\ART=0.18 hrs.\AST=2.42 hrs.\ADT=9.44 hrs.\Jars=28.04 hrs. 06:00 12.00 6.00 12.00-DRILL E 3 P 'Drill slide&rotate(/4192'-1/4312'(3471'TVD)-Pump rate 873 gpm @ 1700 psi.\60 rpm @ 8-20K torque.\WOB=10-20K\ Up wt=189K-Dn wt.=137K-Rot wt.=160K\MW=9.2 ppg\ECD 9.75 ppg.\ART=0.04 hrs.\AST=1.27 hrs.\ADT=10.75 hrs.\Jars=29.35 hrs. 12:00 18.00 6.00 18.00 DRILL E 3 P Drill slide 8 rotate 1/4312'-1/4415'(3530'TVD)-Pump rate 850 gpm @ 1740 psi.\50 rpm @ 10-20K torque.\WOB=10- 20K\Up wt.=190K-Dn w1=145K-Rot wt.=165K1 MW=9.2 ppg\ECD 9.75 ppg.\ART=0.10 hrs.\AST=1,81 hrs.\ADT= 12.66 hrs.\Jars=31.26 hrs. 18:00 00.00 6.00 24.00 DRILL E 3 P Drill slide 8 rotate 1/4415'-1/4470'(3556'TVD)-Pump rate 850 gpm @ 1740 psi.\60 rpm @ 10-26K torque\WOB=10- 20K\Up wt.=190K-Dn wt=145K-Rot wt.=165K1 MW=9.2 ppg\ECD 9.66 ppg.\ART=0.14 hrs.\AST=2.64 hrs,\ADT= 15.44 hrs.\Jars=34.04 hrs. Total ADT=15.44 hrs. Total AST=12.05 hrs. .- Total ART=3.39 hrs. Total Jar=34.04 hrs. Daily Contacts Position Contact Name Company Title E-mail Office Mobile Eni representative Jack Keener ENI -Senior Drilling Supv 'SIDDrilling@enipetroleum.com 907-685-0715 715-6434 Eni representative David F Smith ENI Dolling Supv. SIDDrilling@enipetroleum.com 907-685-0715 632-3058 Eni representative Jack Potter ENI HSE jack.potter@enipetroleum.com 907-685-0721 Eni representative John Spaulding ENI Drilling Rig Clerk AKRigClerksDoyonl5@enipetroleum.com 907-685-0722 355-2607 Tool Push Steve Dambacher Doyon Dolling Tool Pusher rig15@doyondrilling.com 907-685-0716 Tool Push Chad Johnson Doyon Dulling Tour Pusher rig15@doyondrilling.com 907-685-0716 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(mKB) Bottom(mKB) Run Date CASING 133/8 12.415 L80 10.99 837.59 1/10/2012 Last Leakoff Test Depth(mKB) TVD(mKB) Fluid Type Fluid Density(g/L) P Surf Applied(kgf/cm') Eq.Mud Weight(g/L) P LeakOff(kgflcm') 837.59 756.05 LSND mud 10964 26.7 1449.8 109.6 • • Eni E&P Division I Well Name:SP23-N3 011* ENI Petroleum Co.Inc. Daily Report Well Code:26152 Field Name: Nikaitchuq • li Date:1/15/2012 - Report#: 14 API/UWI:50-629-23456-00-00 2" " page 1 of 1 Wellbore name: SP23-N3 Well Header Permit/Concession N' Operator ENI Share)%) Well Configuration type 211127 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(m) Ground Level(m) Water Depth(m) RKB-Base Flange(m) RKB-Tubing Spool(m) 12.46 16.46 3.99 11.22 9.73 Rig Information Contractor Rig Name Rig Type DOYON DRILLING DOYON 15 LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(mKB) Target Depth(TVD...Depth Dr.(MD)(m) Drilling Hours(hr) Avg ROP(m/hr) DFS(days) SP23-N3 DRILLING 1/6/2012 4,250.74 1,163.32 5,315.66 200.06 26.6 9.31 Daily Information End Depth(mKB) End Depth(TVD)(... Depth Progress(m) Drilling Hours(hr) Avg ROP(m/hr) POB Temperature(°C) Weather Wind 1,402.38 1,105.52 39.93 6.37 6.3 97.0 -32.9 Clear,WC-51 224"WSW @ 23 • mph Daily summary operation 24h Summary Drill Slide/Rotate t/4470'-V45973 Back ream(/4597'-114194'.\Monitor well static./RIH(/4194'-114565'./Wash(/4565'-0/4597.1 Drill Slide/Rotating 1/4597'-114601'.\Circulate bottoms-up(rack back stand 15 mins.)f/4601'-114192'./POOH on elevators 1/4192'-1/3710'(20K over put and signs of swabbing)./RIH 1/38213 POOH back reaming(/3821'-1/3500'.Drilling:slide(98%)&rotate(2%). Operation at 07.00 POOH and working BHA#3 with Schlumberger DD/MWD. 24h Forecast Finished POOH w/BHA 3#(CBU @ shoe)./Work BHA#33 P/U BHA#4(surface test).\RIH 114601'./Drill ahead 12 1/4"intermediate hole section. Lithology Shows MAASP(kgf/cm') Mud Weight(g/L) 1102.4 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00:00 06:00 6.00 6.00 DRILL E 3 P Drill Slide/Rotating(/4470'-1/4563'(3607'TVD)-Pump rate 850 gpm @ 1620 psi./40-80 rpm @ 8-26K torque-back ream as required+303 WOB=10-35K\Up wt.=188K-Dn wt.=143K-Rot wt.=164K\MW=9.2 ppg\ECD 9.63 ppg./ART=0.0 • hrs.-AST=2.92 hrs.-ADT=18.36 hrs\Jars=36.96 hrs. 06:00 12:00 6.00 12.00 DRILL E 3 P Drill Slide/Rotating(/4563'-1/4573'(3606'TVD)-Pump rate 900 gpm @ 1600 psi.\40-80 rpm @ 8-26K torque./WOB=10- 35K\Up wt.=188K-Dn wt.=146K-Rot wt.=166K\MW=9.2 ppg\ECD 9.59 ppg.\ART=0,6 hrs.-AST=1.42 hrs.-ADT= 20.38 hrs./Jars=38.98 hrs. 1200 '16:00 4.00 16.00 DRILL E 3 P Drill Slide/Rotating(/4573'-1/4597'(3606'TVD)-Pump rate 900 gpm @ 1600 psi./60-80 rpm @ 8-26K torque-back stands as hole required./WOB=15-40K\Up wt.=188K-Dn e4,146K-Rot wt.=166K\MW=9.2 ppg\ECD 9.67 ppg.\ ART=0.0 hrs:AST=1.18 hrs.-ADT=21.56 hrs.\Jars=40.20 hrs. 16.00 17:00 1.00 17.00 DRILL E 7 P Back ream f/4597'-114194'-pumping 900 gpm @ 1530 psi./80 rpm @ 8-15K torque. 17.00 17:30 0.50 17.50 DRILL E 4 P Mondor well(static)/RIH 1/4194'-V4565'\Dn wt.=150K./Wash 1/4565'-114597'pumping 900 gpm @ 1550 psi.\60 rpm @ 8- 15K torque.\Rot wt.=166K. 17.30 19:30 2.00 19.50 DRILL E 3 P Drill Slide/Rotating(/4597'-V4601'(3606'TVD)-Pump rate 900 gpm @ 1600 psi./50-60 rpm @ 8-26K torque./WOB=20- 40K/Up wt.=188K-Dn wt.=146K-Rot wt.=166K/MW=9.2 ppg\ECD 9.62 ppg./ART=0.0 hrs.-AST=0.25 hrs.-ADT= 21.61 hrs./Jars=40.45 hrs. Drilling:slide(98%)&rotate(2%). Total ADT=21.81 hrs. Total AST=17.82 hrs. Total ART=3.99 hrs. Total Jar=40.45 hrs. 19:30 21:30 2.00 21.50 DRILL E 7 P Circulate bottoms-up(racking back stand every 15 mins.)(/4601'-114192'/900 gpm @ 1330 psi.180 rpm @ 8-12K torque. 21:30 22.30 1.00 22.50 DRILL E 4 P Monitor well-static./POOH on elevator(/4192'-113710'\Pulled 20K over and well began to swab-RIH V3821'. 22:30 00.00 1.50 24.00 DRILL E 4 P POOH back reaming(/3821'-t/3500'./Circulate 900 gpm @ 1100 psi./80 rpm @ 8-10K. Daily Contacts Position Contact Name Company Title E-mail Office Mobile Eni representative Jack Keener 'ENI Senior Dnlling Supv SIDDnlling@enipetroleum.com 907-685-0715 715-6434 Eni representative David F Smith ENI Dolling Supv. SIDDrilling@enipetroleum.com 907-685-0715 632-3058 Eni representative Jack Potter ENI HSE jack.potter@enipetroleum.com 907-685-0721 Eni representative John Spaulding ENI Dnlling Rig Clerk AKRigClerksDoyon15@enipetroleum.com 907-685-0722 355-2607 Tool Push Steve Dambacher Doyon Dnlling Tool Pusher rig15@doyondrilling.com 907-685-0716 Tool Push ' Chad Johnson Doyon Dulling Tour Pusher rig15@doyondrilling.com 907-685-0716 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(mKB) Bottom(mKB) Run Date CASING 133/8 12.415 L80 10.99 837.59 1/10/2012 Last Leakoff Test Depth(mKB) TVD(mKB) Fluid Type Fluid Density(gIL) P Surf Applied(kgflcm') Eq.Mud Weight(g/L) P LeakOff(kgf/cm') 837.59 756.05 LSND mud 1096.4 26.7 1449.8 109.6 Eni E&P Division 'Well Name:SP23-N3 I fa* ENI Petroleum Co.Inc. Daily Report Well Code:26152 Field Name: Nikaitchuq • Date:1/16/2012 - Report#: 15 API/INN:50-629-23456-00-00 en page 1 of 1 Wellbore name SP23-N3 Well Header Permit/Concession N° Operator ENI Share(%) Well Configuration type 211127 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(m) Ground Level(m) Water Depth(m) RKB-Base Flange(m) RKB-Tubing Spool(m) 12.46 16.46 3.99 11.22 9.73 Rig Information Contractor Rig Name Rig Type DOYON DRILLING DOYON 15 LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(mKB) Target Depth(ND...Depth Dr.(MD)(m) Drilling Hours(hr) Avg ROP(mlhr) DFS(days) SP23-N3 DRILLING 1/6/2012 4,250.74 1,163.32 5.315.68 200.06 26.6 10.31 Daily Information End Depth(mKB) End Depth(TVD)(... Depth Progress(m) Drilling Hours(hr) Avg ROP(m/hr) POB Temperature(°C) Weather Wind 1,417.93 1.113.08 15.54 0.49 31.7 97.0 -27.6 Clear,WC-49 231'WSW @ 23 mph Daily summary operation 24h Summary POOH back reaming 1/3500'-112740'circulate clean before entering shoe.\POOH on elevators 1/2740'-Vsurface and work BHA#3(VD NM Flex DC)\RIH wlSchlumberger tools and mud motor-POOH L/D same.\P/U BHA#4.\Service rig.\RIH(/731'-1/4372'shallow test MWD @ 917'.\Wash 1/4372-5/4582'.1 Ream under gauge hole 1/4582'- 114602'(Fan bottom to remove junk 8 made 1'new hole).\ Drill Slide/Rotary 1/4602'-54652'.Drilling.slide(100%)&rotate(0%). Operation at 07.00 Drilling ahead 12 1/4"hole section. 24h Forecast Drill ahead 12 1/4"intermediate hole section to 9 5/8"csg.point. Lithology Shows MAASP(kgf/cm') Mud Weight(gIL) 1120.4 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00.00 03:30 3.50 3.50 DRILL E 4 P POOH back reaming f/3500'-52740'.\Circulate 900 gpm©1350 psi./85 rpm @ 5-7K torque.\Rot wt.=138K.\Slow down pulling speed f12981'-52748'to circulate 2 1/2 CBU and clean outside shoe./Monitor well-static. 03.30 08:30 5.00 8.50 DRILL E 4 P POOH on elevators(/2740'-V2697'(check for swab).\Pump dry job.\Continue POOH f/2697'-Vsurface.\VD NM Flex DC and break bit off. 08.30 11:00 2.50 11.00 DRILL E 4 P RIH w/Power Pulse 825,ARC 825.NM stab and mud motor-POOH L/D same as per Schlumberger.\Clear and clean rig floor. 11:00 15:30 4.50 15.50 DRILL E 4 P P/U NM Flex DC and rack back in derrick./BHA#4 as per Schlumberger DD/MWD-Orient tool off set-1/741'. 15:30 16:00 0.50 16.00 DRILL E 25 P Service and lubricate ng:blocks,top drive,draw-works and crown. 16:00 19:30 3.50 19.50 DRILL E 4 P RIH f/731'-1/4372'-perform shallow test @ 917'pumping rate 640 gpm @ 1020 psi.-fill every 15 stands. 19:30 20:30 1.00 20,50 DRILL E 6 P Wash&ream 1/4372'-1/4582'.\Pump rate 230 gpm @ 340 psi./40 rpm @ 5-8k torque.\WOB=1K.\Up wt.=180K-On wf.= 145K-Rot wt.=165K. 20:30 23:00 2.50 23.00 DRILL E 6 P Ream under gauge hole(/4582'-1/4602'(made 1'new hole)./Pump rate 550 gpm @ 910 psi./40 rpm @ 5-8k torque./ WOB=1-2K./Increase pump rate to 850 gpm @ 1710 psi.1/4597'-1/4602'fan bosom to remove junk from under bit.\40 rpm @ 6-6K torque.\\WOB=1-2K.\Up wt.=180K-Dn w4.=145K-Rot wt.=165K. 23:00 00.00 1.00 24.00 DRILL E 3 P Drill Slide/Rotating 1/4602'-54652'(3663'TVD)-Pump rate 700 gpm @ 1350 psi.\40-60 rpm @ 7-10K torque./WOB=15- 1.- 20K/Up wl.=185K-Dn wt.=145K-Rot w1=165@1 MW=9.2 ppg\ECD 9.7 ppg.\ART=0.0 hrs.-AST=0.49 hrs.-ADT= 0.49 hrs.\Jars=40.94 hrs. Total ADT=0.49 hrs. Total AST=0.49 hrs. Total ART=0.00 hrs. Total Jar=40.94 hrs. Daily Contacts Position Contact Name Company Title E-mail Office Mobile Eni representative Jack Keener ENI Senior Drilling Supv SIDDnlling@enipetroleum.com 907-685-0715 715-6434 Eni representative David F Smith ENI Drilling Supv. SIDDnlling@enipetroleum.com 907-685-0715 632-3058 Eni representative Jack Potter ENI HSE jack.potter@enipetroleum.com 907-685-0721 Eni representative John Spaulding ENI Drilling Rig Clerk AKRigClerksDoyon15@enipetroleum.com 907-685-0722 355-2607 Tool Push Steve Dambacher Doyon Drilling Tool Pusher rig15@doyondrilling.com 907-685-0716 Tool Push Chad Johnson Doyon Drilling Tour Pusher ng15@doyondnlling.com 907-685-0716 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(mKB) Bottom(mKB) Run Date CASING 13 3/8 12.415 L80 10.99 837.59 1/10/2012 Last Leakoff Test Depth(mKB) ND(mKB) Fluid Type Fluid Density(gIL) P Surf Applied(kgflcm°) Eq.Mud Weight(gIL) P LeakOff(kgf/cm') 837.59 756.05 LSND mud 1096.4 26.7 1449.8 109.6 Ill* Eni E&P Division I Well Name:SP23-N3 ENI Petroleum Co.Inc. Daily Report Well Code:26152 Field Name:Nikaitchuq • APIIUWI:50-629-23456-00-00 2^ii Date:1/17/2012 - Report#: 16 'I II page 1 of 1 Wellbore name: SP23-N3 Well Header Permit/Concession N° Operator ENI Share(%) Well Configuration type 211127 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(m) Ground Level(m) Water Depth(m) RKB-Base Flange(m) RKB-Tubing Spool(m) 12.46 16.46 3.99 11.22 9.73 Rig Information Contractor Rig Name Rig Type DOYON DRILLING DOYON 15 LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(mKB) Target Depth(TVD...Depth Dr.(MD)(m) Drilling Hours(hr) Avg ROP(m/hr) DFS(days) SP23-N3 DRILLING 1/6/2012 4,250.74 1,163.32 5,315.68 200.06 26.6 11.31 Daily Information End Depth(mKB) End Depth(TVD)(... Depth Progress(m) Drilling Hours(hr) Avg ROP(m/hr) POB Temperature("C) Weather Wind 1,805.94 1,178.95 388.01 13.92 27.9 100.0 -29.0 Partly Cloudy. WC- 221'SSW @ 27 52 mph Daily summary operation 24h Summary Drill Slide/Rotary(/4652'-65925'.1 Drilling footage.slide(75%)&rotate(25%).Phase II condition 2030 hrs. Operation at 07.00 Drilling 12 1/4"hole section to 9 5/8"csg.point TD. 24h Forecast Drill 12 1/4"hole to 9 5/8"csg.TD @ proposed 6426 MD.\Circulate 5-6+bottoms-up or until clean(rack stand after each CBU).\POOH back reaming to shoe./Circulate until clean./POOH on elevators and L/D BHA#4./Change to 9 5/8"csg.rams and test./Vetco Gray install short wear bushing./R/U Tesco CDS system./PJSM-P/U 9 5/8"csg.as per tally. Lithology Shows MAASP(kgf/cm') Mud Weight(gIL) 1132.4 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00:00 06.00 6.00 6.00 DRILL E 3 P 'Drill Slide/Rotating 1/4652'-65022'(3780'ND)-Pump rate 800 gpm @ 1780 psi.\60 rpm @ 6-9K torque.\WOB=20-45K\ Up wt.=178K-Dn wt.=144K-Rot wt.=160K\MW=9.4 ppg\ECD 9.98 ppg.\ART=0.0 hrs.-AST=3.77 hrs:ADT=4.26 hrs.\Jars=44.76 hrs. 06:00 '12.00 6.00 12.00 DRILL E 3 P Doll Slide/Rotating f/5022'-(/5303'(3823'TVD)-Pump rate 900 gpm @ 2150 psi./60 rpm @ 7-9K torque.\WOB=20-451\ Up wt.=160K-Dn wt.=145K-Rot wt=159K\MW=9.4 ppg\ECD 10.01 ppg\ART=0.24 hrs.-AST=2.90 hrs.-ADT= 7.40 hrs.\Jars=47.90 hrs. 12'.00 18'00 6.00 18.00 DRILL E 3 P Drill Slide/Rotating 5/5303'-(/5608'(3843'ND)-Pump rate 900 gpm©2220 psi.\60 rpm©7-8K torque.\WOB=10-20K\ Up wt.=175K-Dn wt.=145K-Rot wt.=160K\MW=9.4 ppg\ECD 10.06 ppg.\ART=0.11 hrs.-AST=3.29 hrs:ADT= 10.80 hrs.\Jars=51.30 hrs. 18.00 00.00 6.00 24.00 DRILL E 3 P Drill Slide/Rotating f/5608'-1/5925'(3867'TVD)-Pump rate 900 gpm/1)2150 psi.\100 rpm @ 7-10K torque.\WOB=20- 30K\Up wt.=170K-Dn wt.=145K-Rot wt=150K1MW=9.4 ppg\ECD 10.4 ppg.\ART=2.32 hrs:AST=1.29 hrs:ADT= 14.41 hrs.\Jars=54.91 hrs.\Phase II©2030 hrs. Total ADT=14.41 hrs. Total AST=11.74 hrs. Total ART=2.67 hrs. Total Jar=54.91 hrs. Daily Contacts Position Contact Name Company Title E-mail _ Office Mobile Eni representative Mike Ross ENI Senior Drilling Supv SIDDrilling@enipetroleum.com 907-685-0715 Eni representative David F Smith ENI Drilling Supv. SIDDrilling@enipetroleum.com 907-685-0715 632-3058 Eni representative Geoff Ackerman ENI HSE geoR.ackerman@enipetroleum.co 907-685-0721 Eni representative John Spaulding EN I Drilling Rig Clerk AKRigClerksDoyon 15@enipetroleum.com 907-685-0722 355-2607 Tool Push Steve Dambacher Doyon Drilling Tool Pusher rig15@doyondrilling.com 907-685-0716 Tool Push Chad Johnson Doyon Drilling Tour Pusher rig15@doyondrilling.com 907-685-0716 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(mKB) Bottom(mKB) Run Date CASING 133/8 12.415 L80 10.99 837.59 1/10/2012 Last Leakoff Test Depth(mKB) TVD(mKB) Fluid Type Fluid Density(g/L) P Surf Applied(kgf/cm') Eq.Mud Weight(gIL) P LeakOff(kgllcm') 837.59 756.05 LSND mud 1096.4 26.7 1449.8 1096 flit* Eni E&P Division (Well Name:SP23-N3 ENI Petroleum Co.Inc. Daily Report Well Code:26152 Field Name:Nikaitchuq • Date:1/18/2012 - Report#: 17 APIIl1Wl:50-629-23456-00-00 2" "[I page 1 of 1 Wellbore name: SP23-N3 Well Header Permit/Concession N° Operator ENI Share(%) Well Configuration type 211127 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(m) Ground Level(m) Water Depth(m) RKB-Base Flange(m) 'RKB-Tubing Spool(m) 12.46 16.46 3.99 11.22 9.73 Rig Information Contractor Rig Name Rig Type DOYON DRILLING DOYON 15 LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(mKB) Target Depth(ND...Depth Dr.(MD)(m) Drilling Hours(hr) Avg ROP(m/hr) DFS(days) SP23-N3 DRILLING 1/6/2012 4,250.74 1,163.32 5,315.68 200.06 26.6 12.31 Daily Information End Depth(mKB) End Depth(TVD)(... Depth Progress(m) Drilling Hours(hr) Avg ROP(m/hr) POB Temperature(°C) Weather Wind 1,947.73 1.187.34 141.79 7.26 19.5 99.0 -24.0 Clear.WC-13 S94`WNW @ 06 mph Daily summary operation 24h Summary Drill Slide/Rotary 1/5925'-116390'(TD for 9 5/8"csg.)\Circulate bottoms-up 6X until clean 1/6930'-65805'(rack back stand every CBU)./POOH back ream f/5805'-t/4463'pumping 900 gpm @ 2150 psi./ 125 rpm @ 6-11K.1 Hole condition and section with high dog legs dictated pulling speed. Operation at 07.00 POOH back reaming to run 9 5/8"csg. 24h Forecast POOH/BR 1/4463'-112748'(13 3/8"csg shoe).\Continue POOH/BR circulating 2-3X or until clean(rack back stand every CBU)/Pump dry job-POOH on elevators and L/D BHA#4./Change to 9 5/8"csg rams and test 1/250/3500psi.\Vetco Gray install short wear bushing.\R/U Tesco CDS system.\PJSM-P/U 9 5/8"csg.as per tally. Lithology Shows MAASP(kgflcm°) Mud Weight(gIL) 1120.4 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00 00 0600 6.00 6.00 DRILL E 3 P Drill Slide/Rotating 65925'-V6255'(3892'TVD)-Pump rate 893 gpm @ 2215 psi.\80-100 rpm @ 10-12K torque.\WOB= 28-30K\Up wt.=182K-Dn wt.=132K-Rot wt.=157K\MW=9.4 ppg\ECD 10.25 ppg.\ART=1.7 hrs.-AST=1.3 hrs.-ADT =17.41 hrs.\Jars=57.91 hrs. 06:00 12 00 6.00 12.00 DRILL E 3 P Drill Slide/Rotating f/6255'-116366'(3896'ND)-Pump rate 896 gpm @ 2220 psi.\40-105 rpm @ 8-12K torque./WOB= 30K\Up wt.=178K-Dn wt=134K-Rot wt.=153K\MW=9.35 ppg\ECD 10.10 ppg.\ART=1.65 hrs:AST=1.19 hrs.- ADT rs:ADT=20.25 hrs.\Jars=60.75 hrs. 12 00 13 30 1.50 13.50 DRILL E 3 P .Drill Slide/Rotating(/6366'-V6390'(3896'ND)-Pump rate 900 gpm @ 2220 psi.\80-105 rpm @ 8-10K torque.\WOB= 30K\Up wt.=178K-Dn wt=134K-Rot wt=153K\MW=9.4 ppg\ECD 9.92 ppg.\ART=1.42 hrs..AST=0.0 hrs:ADT= 21.67 hrs.\Jars=62.17 hrs.TD for intermediate 9 5/8"csg. Total ADT=21.67 hrs. Total AST=14.23 hrs. Total ART=7.44 hrs. Total Jar=62.17 hrs. 13:30 1630 3.03 16.50 DRILL E 7 P Circulate bottoms-up 5X(racking back stand every bottoms-up)f/6390'-115890'\900 gpm @ 2125 psi\125 rpm @ 7-10K torque./MW=9.4 ppg.\ECD 10.16 ppg. 16:30 00.00 7.50 24.00 DRILL E 4 P POOH back reaming(/5805'-114463'./Circulate 900 gpm @ 1930 psi./125 rpm @ 6-11K torque./Rot wt.=160K.\MW= 9.45 ppg.\ECD 10.15 ppg.\Hole condition dictated pulling speed and section with high dog legs. Daily Contacts Position Contact Name Company Title E-mail Office Mobile Eni representative David F Smith -ENI Drilling Supv. SIDDnlling@enipetroleum.com 907-685-0715 632-3058 Eni representative Geoff Ackerman ENI HSE geoff.ackerman@enipetroleum.co 907-685-0721 Tool Push Steve Dambacher Doyon Dnlling Tool Pusher rig15@doyondrilling.com 907-685-0716 Tool Push Chad Johnson Doyon Drilling Tour Pusher ng15@doyondrilling.com 907-685-0716 Eni representative John Spaulding ENI Drilling Rig Clerk AKRigClerksDoyon15@enipetroleum.com 907-685-0722 355-2607 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(mKB) Bottom(mKB) Run Date CASING 133/8 12.415 L80 10.99 837.59 1/10/2012 Last Leakoff Test Depth(mKB) TVD(mKB) Fluid Type Fluid Density(gIL) P Surf Applied(kgflcm') Eq.Mud Weight(g/L) P LeakOff(kgflcm') 837.59 756.05 LSND mud 1096.4 26.7 1449.8 109.6 Eni E&P Division I Well Name:SP23-N3 ENI Petroleum Co.Inc. Daily Report Well Code:26152 Field Name: Nikaitchuq Ift* • API/UWI:50-629-23456-00-00 2 II^ Date:1/19/2012 - Report#: 18 II fI n page 1 of 1 Wellbore name: SP23-N3 Well Header Permit/Concession 14 Operator ENI Share)%) Well Configuration type 211127 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(m) Ground Level(m) Water Depth(m) RKB-Base Flange(m) RKB-Tubing Spool(m) 12.46 16.46 3.99 11.22 9.73 Rig Information Contractor Rig Name Rig Type DOYON DRILLING DOYON 15 LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth)mKB) Target Depth(TVD...Depth Dr.(MD)(m) Drilling Hours(hr) Avg ROP(mlhr) DFS(days) SP23-N3 DRILLING 1/6/2012 4,250.74 1,163.32 5,315.68 200.06 26.6 13.31 Daily Information End Depth)mKB) End Depth(TVD)(... Depth Progress(m) Drilling Hours)hr) Avg ROP)mlhr) POB Temperature(°C) Weather Wind 1,947.73 1,187.34 0.00 97.0 -19.7 Cloudy Lt Snow WC- WSW 237"@ 27 44 mph Daily summary operation 24h Summary POOH/BR 1/4463'-1/2748'(13 3/8"csg shoe).\Circulating 2 1/2X until clean(rack back stand every CBU).02748'-U2595'1 Pump dry job-POOH on elevators and L/D BHA#4.1 Change to 9 5/8"csg.rams and test U250/3500psi.\Vetco Gray install short wear bushing./R/U Tesco CDS system.\PJSM-P/U 9 5/8"csg.as per tally(check floats in shoe track)-RIH 0885'. Operation at 07.00 P/U 9 5/8"csg.(409;L-80;Hydril 563)floating in hole with Tesco CDS. 24h Forecast P/U 9 5/8"csg.(40#;L-80;Hydril 563)as per tally(/885'-1/6369'\Fill 9 5/8"csg.with 9.4 ppg LSND mud./Load wiper plugs in cement head./Break circulate @ 1/2 bpm-increase 1/8 bpm.-condition mud for cement job./PJSM with Schlumberger and cement 9 5/8"csg.\Perform infective test down 13 3/6"x 9 5/8"annulus with LSND mud./Lift BOP stack and Vetco Gray install emergency slips as per well plan. Lithology Shows MAASP(kgflcm') Mud Weight(gIL) 1132,4 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00:00 07:00 7.00 7.00 DRILL E 4 P POOH back reaming(/4463'-t/2748'./Circulate 900 gpm @ 1625 psi./125 rpm @ 5-7K torque./Rot wt.=142K.\MW=9.4+ ppg.\ECD 9.91 ppg.\K&M parameters(500-700 fpm)-hole condition dictated pulling speed and section with high dog legs. 07:00 08:00 1.00 8.00 DRILL E 7 P Circulate bottoms-up 2 1/2X(racking back stand every bottoms-up)f/2748'-1/2595'\900 gpm @ 1600 psi./125 rpm @ 3-6K torque./Rot wt.=140K.\MW=9.4 ppg.\ECD 9.90 ppg.\Monitor well-static. 08:00 10:00 2.00 10.00 DRILL E 4 P POOH on elevators(check for swab and pump dry job).\f/2595-0270'to 5"HWDP. 10:00 13:30 3.50 13.50 DRILL E 4 P UD BHA#4 as per Schlumberger DD/MWD.\Clear of components and clean floor area of tools. 13:30 14:00 0.50 14.00 DRILL G 20 P Pull wear bushing and M/U test plug-install with Vetco Gray. 14:00 16:00 2.00 16.00 DRILL G 5 P PJSM-Change upper pipe rams from variable to 9 5/B"csg. 16:00 17:00 1.00 17.00 DRILL G 12 P PJSM\P/U and M/U 9 5/8"test joint and test equipment-fill stack wlwater.\Test rams 0250 psi/3500 psi.(chart record f/5 mins.)\R/D test equipment and L/D 9 5/8"csg test joint. 17:00 17:30 0.50 17.50 DRILL G 5 P Install short wear bushing for rotating casing with Vetco Gray(length 48 3/8"-12 11/4"ID-13 7/8"OD). 17:30 18:30 1.00 18.50 DRILL G 1 P L/D short bails-M/U 2"high pressure hoses and valves from stand pipe to choke manifold for floating 9 5/8"csg. 18:30 21:30 3.00 21.50 DRILL G 20 P R/U Tesco CDS-Remove guide bowl from TDS-8./P/U CDS tool and M/U on TD. 21:30 00:00 2.50 24.00 DRILL G 4 P PJSM with Tesco-P/U shoe track(BakerLok)-fill and check float equipment-OK./Continue P/U 9 5/8"csg.(409;L-80, Hydril 563)empty with Tesco CDS tool 1/885'/Check connection torque to guidelines.\Dn wt.=80K.\Monitor displacement with active#4-no loses. Daily Contacts Position Contact Name Company Title E-mail Office Mobile Eni representative David F Smith ENI 'Dulling Supv. 'SIDDnlling@enipetroleum.com 907-685-0715 632-3058 Eni representative Geoff Ackerman ENI HSE geotf.ackerman@enipetroleum.co 907-685-0721 Tool Push Steve Dambacher Doyon Drilling Tool Pusher ng15@doyondrilling.com 907-685-0716 Tool Push Chad Johnson Doyon Dulling Tour Pusher ng15@doyondrilling.com 907-685-0716 Eni representative Mike Ross ENI Senior Drilling Supv SIDDrilling@enipetroleum.com 907-685-0715 Eni representative John Spaulding ENI Drilling Rig Clerk AKRigClerksDoyon15@enipetroleum.com 907-685-0722 355-2607 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(mKB) Bottom(mKB) Run Date CASING 9 5/8 8.835 L80 9.44 1.941,39 1/19/2012 Last Leakoff Test Depth(mKB) TVD(mKB) Fluid Type Fluid Density(gIL) P Surf Applied(kgf/cm') Eq.Mud Weight(gIL) P LeakOff(kgflcm') 837.59 756.05 LSND mud 1096.4 26.7 1449.8 109.6. lifil* Eni E&P Division I Well Name:SP23-N3 ENI Petroleum Co.Inc. Daily Report Well Code:26152 Field Name:Nikaitchuq • Date:1/20/2012 - Report#: 19 APIIUWI:50-629-23456-00-00 e i page 1 of 1 Wellbore name: SP23-N3 Well Header Permit/Concession N° Operator ENI Share(%) Well Configuration type 211127 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(m) Ground Level(m) Water Depth(m) RKB-Base Flange(m) RKB-Tubing Spool(m) 12.46 16.46 3.99 11.22 9.73 Rig Information Contractor Rig Name Rig Type DOYON DRILLING DOYON 15 LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(mKB) Target Depth(TVD...Depth Dr.(MD)(m) Drilling Hours(hr) Avg ROP(m/hr) DFS(days) SP23-N3 DRILLING 1/6/2012 4,250.74 1.163.32 5,315.68 200.06 26.6 14.31 Daily Information End Depth(mKB) End Depth(TVD)(... Depth Progress(m) Drilling Hours(hr) Avg ROP(m/hr) POB Temperature(°C) Weather Wind 1,947.73 1.187.34 0.00 99.0 -18.9 Partly cloudy WC-10 WNW 307°@11 mph Daily summary operation 24h Summary P/U 9 5/8"csg.(40#;L-80:Hydril 563)as per tally f/885-5/6369'1 Fill 9 5/8"csg.with 9.4 ppg LSND mud.\Load plugs in cement head-Break circulate @ 1/2 bpm-increase 5/8 bpm.-condition mud.:PJSM with Schlumberger and cement 9 5/8"csg.\Perform infective test down 13 3/8"x 9 5/8"annulus with LSND 9.4 ppg mud.\N/D BOP-Flow line,bleeder,fill-up,choke lines./Gave AOGCC 24 hrs. notification @ 0600 hrs.for BOP test-John Crisp returned call to witness BOP test. Operation at 07.00 Vetco Gray set emergency slips and cut 9 5/8"csg. 24h Forecast N/D BOP stack and set emergency slips and cut 9 5/8"csg.\N/U BOP.\Change top rams to 4 1/2"x 7"variable.\Test BOP-AOGCC will witness./P/U BHA#5-RIH to float equipment.\Test 9 5/8"csg to 3000 psi./Displace to OBM mud./Drill out shoe track and 20'-50'new hole. Lithology Shows MAASP(kgflcm') •Mud Weight(gIL) 1126.4 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00:00 08:00 8.00 8.00 DRILL G 4 'P Continue P/U 9 5l8"csg.(40#;L-80;Hydril 563)Tesco CDS 1/885'-1/6369'(P/U landing joint).\K&M recorded parameters @ shoe-started rotating 1/5902'-1/6369'with 30 RPM @ 7K torque./Rot wt.=87K./Monitor displacement-no loses.\Gave AOGCC 24 hrs.notification @ 0600 hrs.for BOP test-John Crisp returned call to witness BOP test tomorrow. 08:00 10:00 2.00 10.00 DRILL G 20 P R/D Tesco CDS equipment and L/D from floor./P/U long bails and install on TD./Install cement head(without plugs)-R/U 2"high pressure hose to cement head to pump and bleed air from 9 5/8"csg.\Confirm open flow path line-up. 10:00 13:30 3.50 13.50 DRILL G 7 P Fill 9 5/8"csg.with of 9.4 ppg LSND mud @ 2 bpm in stages to let air and mud to swap./Start loading 4 1/2"tbg.in pipe shed. 13:30 14:30 1.00 14.50 DRILL H 7 P Change hoses to circulate for cement job./Load plugs into cement head(ENI and Schlumberger witness). 14:30 18:30 4.00 18.50 DRILL H 7 P Break circulation with 1/2 bpm @ 180 psi.stage rate to 8 bpm @ 320 psi.with total 3 1/2 bottoms-up./Condition mud for �� cement job(YP 17)-monitor for loses. r 18:30 22:00 3.50 22.00 DRILL H 7 P Hold PJSM w/all personnel involved with cement job.SLB pump 10 bbls H2O&test lines to 3500/psi./Rig pumped 73 bbls. cA.5/1lt Mudpush II @ 10.5 ppg.-Pump rate of 5.2 bpm @ 230 psi.\Shut-down drop bottom plug.\SLB mix&pump 2021 Is. slurry @ 12.4 ppg.\DeepCrete 736 sks.[Yield 1.56 ft.3/sk,mix water at 5.471 gal/sk.j-Pump rate of 4.5 bpm @ 160 psi./ Shut down&drop top plug=SLB-(iUr51p 10 bbls 1420\Displace with 468 bbls.@ 9.4 ppg LSND mud with rig mud pump at 7 bpm w/ICP 160 psi and FCP 620 psi;at 435 bbls away slow pump to 3.0 bpm with 500/psi.FCP/Bump plug to 500/psi, _\ over to 1000/psi.-Hold for 5 minutes and bleed off(back 2.25 bbls.)-check floats holding-Good.\Cement in place @ /) 2141 hrs.\RID cement head and lines. ex.�!',t s 7 22:00 23:00 1.00 23.00 DRILL H - P Perform injective test down 13 3/8"x 9 5/8"annulus w/9.4 ppg LSND mud-Pump 25 bbls with injection rate 1.5 bpm @ 690 psi./bleed back 5 bbls. 23:00 00:00 1.00 24.00 DRILL G 20 P PJSM-N/D BOP-Flow line,bleeder,fill-up,choke lines./Transfer surface volume to WIF for injection. Daily Contacts Position Contact Name Company Title E-mail Office Mobile Eni representative David F Smith ENI Drilling Supv. iSIDDrilling@enipetroleum.com 907.685-0715 .632-3058 Eni representative Geoff Ackerman ENI HSE geoff.ackerman@enipetroleum.co 907-685-0721 Tool Push Steve Dambacher Doyon Drilling Tool Pusher rig15@doyondrilling.cum 907-685-0716 Tool Push Chad Johnson Doyon Dulling Tour Pusher ng15@doyondrilling.com 907-685-0716 Eni representative Mike Ross ENI Senior Drilling Supv SIDDnIling@enipetroleum.com 907-685-0715 Eni representative John Spaulding ENI Drilling Rig Clerk AKRigClerksDoyon15@enipetroleum.com 907-685-0722 355-2607 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(mKB) Bottom(mKB) Run Date CASING 95/8 8.835 L80 9.44 1.941.39 1/19/2012 Last Leakoff Test Depth(mKB) TVD(mKB) Fluid Type Fluid Density(gIL) P Surf Applied(kgflcm') Eq.Mud Weight(gIL) P LeakOff(kgflcm') 837.59 756.05 LSND mud 1096.4 26.7 1449.8 109.6 1* Eni E&P Division [Well Name: SP23-N3 ENI Petroleum Co.Inc. Daily Report Well Code:26152 Field Name:Nikaitchuq • APIIUWI:50-629-23456-00-00 2^n Date:1/21/2012 - Report#: 20 I) �"Ipage 1 of 1 Wellbore name: SP23-N3 Well Header Permit/Concession N° Operator ENI Share(%) Well Configuration type 211127 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(m) Ground Level(m) Water Depth(m) RKB-Base Flange(m) RKB-Tubing Spool(m) 12.46 16.46 3.99 11.22 9 73 Rig Information Contractor Rig Name Rig Type DOYON DRILLING DOYON 15 LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(mKB) Target Depth(TVD...Depth Dr.(MD)(m) Drilling Hours(hr) Avg ROP(m/hr) DFS(days) SP23-N3 DRILLING 1/6/2012 4.250.74 1,163.32 5.315.68 200.06 26.6 15.31 Daily Information End Depth(mKB) End Depth(TVD)(... Depth Progress(m) Drilling Hours(hr) Avg ROP(m/hr) POB Temperature(°C) Weather Wind 1,947.73 1,187.34 0.00 98.0 -31.3 Clear WC-40 N 6"@ 5mph Daily summary operation 24h Summary N/D and lift BOP stack-Vetco Gray set 9 5/8"csg.emergency slips and pack-off-Set down and tighten connection-Test 9 5/8"csg.pack-off 5/2300 psi.f/10 mins./Set test plug./Change top rams to 4 1/2"x 7"variable.\Test BOP with 5 1/2",5"4 1/2"tubular-AOGCC John Crisp waived witness @ 0724 hrs.\R/D test equipment./Install wear bushing./Install pipe guide,bails,link tilt and elevators on TDS -8. Operation at 07.00 Pickup BHA#5,load nuclear source and RIH. 24h Forecast L/D 5"HWDP from derrick./P/U BHA#5.\RIH to float equipment/Circulate bottoms-up./Test 9 5/8"csg to 3000 psi.for 30 mins./Displace to OBM mud.\Drill out shoe track and 20-50'new hole.) Perform LOT/FIT.\Drill ahead 8 3/4"hole section as per well. Lithology Shows MAASP(kgflcm') Mud Weight(gIL) 1126.4 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00:00 02:00 ' 2.00 2.00 DRILL G 5 P Finished N/D BOP-Flow line.choke lines./Blow down lines./Flush and drain stack./Continue transfer mud to WIF. 02:00 03:00 1.00 3.00 DRILL G 20 P Wait on cement-compressive strength-consult with town./Prep to P/U BOP stack./Clean active pits for OBM. 03:00 07:00 4.00 7.00 DRILL G 5 P PJSM wNetco Gray-Split well head @ casing spool./P/U BOP stack,riser and Multi-bowl to approximate 13'5 Prep&set emergency slip-set slips with 103K./R/U and cold cut 9 5/8"csg.and UD./Clean active pits. 07:00 09:30 2.50 9.50 DRILL G 5 P P/U 5"test joint and pull wear bushing form multi-bowl.\Dress top of 9 5/8"csg.and install pack-off.\Set BOP stack,riser, Multi-bowl and tighten connection./R/D spiders and long bails./Continue cleaning active pits. 09.30 10:30 1.00 10.50 DRILL G 12 P R/U test 9 5/8"csg.pack-off to 2300 psi.for 10 mins. 10:30 1200 1.50 12.00 DRILL E 5 P N/U 4"choke and lines-Set test plug./Cleaning active pits./Little Red R/U and started freeze protected 13 3/8"0 9 5/8"csg. pump rate 1 bpm @ 600 ICP and 880 FCP with 170 bbls.diesel @ 100". 12:00 13:00 1.00 13.00 DRILL E 5 P Change upper rams from 9 5/8"csg.to 4 1/2"x7"variables. 1300 14:00 1.00 14.00 DRILL E 5 P Finished N/U of BOP stack flow line/air boot and tumbuckles-cleanup area P/U tools. 14:00 15:00 1.00 15,00 DRILL E 12 P PJSM for testing-R/U test equipment. 15.00 21:00 6.00 21.00 DRILL E 12 P -.Igs1.S PE to AOGCC requirements.\Annular 5 1/2",5",4 1/2"test joints V250/2500 psi.\Test Upper rams(4 1/2"x7")\ P Lower rams(27/8"x5")Blind rams,Kill-2 manual and HCR valves/Choke manual and HCR valves\Choke manifold valves /J J` /�/ 1-18/A super hydraulic-B&C manual chokes V1500 psi./Upper&lower IBOP valves\Floor dart&IBOP valves 1/250/3500 Yui`{'.V-f�/// psi.-Chart record all for 5 mins.\Accumulator draw down test(Recovery times:(/1450-01675 psi.(200 psi.)in 36 seconds '�(1 with final @ 3000 psi.in 218 seconds-16 bottle bladder pre-charge average 1075 psi.\(5 Nitrogen bottles @ 2400 psi. average)./Flow tested choke manifold and gas buster-16 bbls.volume./Test gas alarms.\Clean pits. 21:00 22:00 1.00 22.00 DRILL E 12 P R/D BOP test equipment. 22:00 22:30 0.50 22.50 DRILL E 5 P Install wear bushing with Vetco Gray. 22:30 00:00 1.50 24.00 DRILL E 5 P Install TD-8 pipe guide,short bails and hook-up linkage and P/U elevators to L/D 5"HWDP. Daily Contacts Position Contact Name Company Title E-mail Office Mobile Eni representative David F Smith ENI Drilling Supv. SIDDnlling@enipetroleum.com .907-685-0715 632-3058 Eni representative Geoff Ackerman ENI HSE geoff.ackerman@enipetroleum.co 907-685-0721 Tool Push Steve Dambacher Doyon Dulling Tool Pusher rig15@doyondrilling.com 907-685-0716 Tool Push Chad Johnson Doyon Dolling Tour Pusher rig15@doyondrilling.com 907-685-0716 Eni representative Mike Ross ENI Senior Drilling Supv SIDDrilling@enipetroleum.com 907-685-0715 Eni representative John Spaulding ENI Drilling Rig Clerk AKRigClerksDoyonl5@enipetroleum.com 907-685-0722 355-2607 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(mKB) Bottom(mKB) Run Date CASING 95/8 8.835 L80 9.44 1.941.39 1/19/2012 Last Leakoff Test Depth(mKB) TVD(mKB) Fluid Type Fluid Density(gIL) P Surf Applied(kgf/cm') Eq.Mud Weight(g/L) P LeakOff(kgf/cm') 1.941.27 1,187.26 OBM(FazePro) 1126.4 38.3 1445.3 172.0 Eni E&P Division 'Well Name:SP23-N3 VI* ENI Petroleum Co.Inc. Daily Report Well Code:26152 Field Name:Nikaitchuq •2^f, Date:1122/2012 - Report#: 21 ii APIIUWI:50 629-23456-00-00 II II page 1 of 1 Wellbore name: SP23-N3 Well Header Permit/Concession N° Operator ENI Share(%) Well Configuration type 211127 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(m) Ground Level(m) Water Depth(m) RKB-Base Flange(m) RKB-Tubing Spool(m) 12.46 16.46 3.99 11.22 9.73 Rig Information Contractor Rig Name Rig Type DOYON DRILLING DOYON 15 LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(mKB) Target Depth(TVD...Depth Dr.(MD)(m) Drilling Hours(hr) Avg ROP(m/hr) DFS(days) SP23-N3 DRILLING 1/6/2012 4.25074 1,163.32 5,315.68 200.06 26.6 16.31 Daily Information End Depth(mKB) End Depth(TVD)(... Depth Progress(m) Drilling Hours(hr) Avg ROP(m/hr) POB Temperature(°C) Weather Wind 1.955.29 1,187.45 7.62 0.12 63.5 97.0 -43.9 Clear WC-68 SW 217'@ 9 mph l Daily summary operation 24h Summary PJSM-P/U BHA#5 vdradioactive sources-RIH 1/291'shallow pulse test.\RIH f/291/-0/6170'/Circulate bottoms-up./Test 9 518"csg.to 3000 psi.f/30 mins./Cut drilling line and inspect brakes and linkage./RIH 1/6170-0/6265'\Displace 9.4 ppg OBM./RIH tag @ 6274'w14K-Drill cement/plugs and shoe 7/6369'.\Ream old hole f/6369'-1/6390'.1 Drill 1/6390'-V6415'(25'new hole)/Circulate bottoms- up and balanced MW=9.4 ppg.Reciprocate and rotate./POOH f/6415'-1/6360'and R/U for LOT/FIT. • Operation at 07.00 Drilling 8 3/4"Production Hole Section. 24h Forecast Perform LOT with 9.4 ppg.OBM(FazePro)-EMW=12.1 ppg.1 Drill ahead 8 3/4"production section as per wet. Lithology Shows MAASP(kgflcm') Mud Weight(gIL) 11264 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00:00 00:30 0.50 0.50 DRILL E 25 P Service and inspect top drive. 00:30 01:30 1.00 1.50 DRILL E 4 P RIH w/4 stands 5"HWDP-POOH UD same. 01:30 03:30 2.00 3.50 DRILL E 4 P PJSM-BHA#5 0/94'as per well plan and Schlumberger DD/MWD. 03:30 05:00 1.50 5.00 DRILL E 4 P PJSM w/Schlumberger for radioactive sources-Notified security and SID operation./Load sources in tool. 05:00 06:30 1.50 6.50 DRILL E 4 P Continue P/U BHA#5 f/94'-t/291'./Swallow pulse test MWD tool pumping 460 gpm @ 550 psi./K&M recorded data points.\ Notified security all clear. 06:30 12:30 6.00 12.50 DRILL E 4 P RIH f/291'-V6170'9 Fill pipe every 10 stands./Up wt.=170K-Dn wt.=130K. CP.-J4P.-J412:30 13:30 1.00 13.50 DRILL E 7 P Circulate bottoms-up pump rate 500 gpm @ 1200 psi./Dn wt=135K. ‘,/45/�J I 13:30 14:30 1.00 14.50 DRILL E 12 P R/U and perform 9 5/8"csg integrity test to 3000 psi.for 30 mins.((chart record)./R/D test equipment., 14:30 16:00 1.50 16.00 DRILL E 25 P PJSM-Cut drilling line(120')-inspect brakes and linkage. L'I 16:00 17:00 1.00 17.00 DRILL E 4 P RIH f/6170'-1/6265'.\Schlumberger calibrated blocks height. 17:00 19:30 2.50 19.50 DRILL E 7 P Pump 40 bbls.LVT spacer pill and displaced with 9.4 OBM(FazePro). 19:30 21:30 2.00 21.50 DRILL E 3 P Wash f/6265'-1/6274'tag with 4K.1 Drill cement/plugs and shoe track(/6274'-916369'.1 Continue reaming 1/6390'old hole section./Pump rate 500 gpm @ 1390 psi.\40 rpm @ 7-10K torque.\WOB=8-12K\Up wt.=175K-Dn wt.=130K-Rot wt.= 145K\MW=9.4 ppg/ECD 10.3 ppg. 21:30 22:00 0.50 22.00 DRILL E 3 P Drill Rotary Steerable f/6390'-116415'(3836'TVD)-Pump rate 490 gpm @ 1390 psi.\80 rpm @ 10-12K torque./WOB=10- 14K/Up wt.=175K-Dn wt.=130K-Rot wt.=145K/MW=9.4 ppg/ECD 10.39 ppg./ADT=0.12 hrs./Jars=0.12 hrs. 22:00 23:00 1.00 23.00 DRILL E 7 P Circulate bottoms-up and balance mud weights 9.4 ppg in/out.\Pumping 500 gpm @ 1390 psi./Rotate and reciprocate pipe (/6415'-1/6330'with 60 rpm @ 7-8K torque. 23:00 00:00 1.00 24.00 DRILL E 12 P POOH f/6415'-1/6360'\Blow down top drive./RIU to perform LOT/FIT with 9.4 ppg.OBM(FazePro)mud-started to perform LOT. Daily Contacts Position Contact Name Company Title E-mail Office Mobile Eni representative David F Smith ENI Drilling Supv. SIDDrilling@enipetroleum.com 907-685-0715 632-3058 Eni representative Geoff Ackerman ENI HSE geoff.ackerman@enipetroleum.co 907-685-0721 Tool Push Steve Dambacher Doyon Drilling Tool Pusher rig15@doyondrilling.com 907-685-0716 Tool Push Chad Johnson Doyon Drilling Tour Pusher rig15@doyondrilling.com 907-685-0716 Eni representative Mike Ross ENI Senior Drilling Supv SIDDnlling@enipetroleum.com 907-685-0715 Eni representative John Spaulding ENI Drilling Rig Clerk AKRigClerksDoyon15@enipetroleum.com 907-685-0722 355-2607 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(mKB) Bottom(mKB) Run Date CASING 9 5/8 8.835 L80 9.44 1.941.39 1/19/2012 Last Leakoff Test Depth(mKB) ND(mKB) Fluid Type Fluid Density(gIL) P Surf Applied(kgf/cm') Eq.Mud Weight(gIL) P LeakOff(kgf/cm') 1.941.27 1.187,26 OBM(FazePro) 1126.4 38.3 1449.3 172.0 fi S Eni E&P Division I Well Name:SP23-N3 ENI Petroleum Co.Inc. Daily Report Well Code:26152 Field Name:Nikaitchuq • APIIUWI:50-629-23456-00-00 2 II n n Date:1/23/2012 - Report#: 22 II �I page 1 of 1 Wellbore name: SP23-N3 Well Header Permit/Concession N' Operator ENI Share(%) Well Configuration type 211127 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(m) Ground Level(m) Water Depth(m) RKB-Base Flange(m) RKB-Tubing Spool(m) 12.46 16.46 3.99 11.22 9.73 Rig Information Contractor Rig Name Rig Type DOYON DRILLING DOYON 15 LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(mKB) Target Depth(ND...Depth Dr.(MD)(m) Drilling Hours(hr) Avg ROP(m/hr) DFS(days) SP23-N3 DRILLING 1/6/2012 4,250.74 1,163.32 5,315.68 200.06 26.6 17.31 Daily Information End Depth(mKB) End Depth(TVD)(... Depth Progress(m) Drilling Hours(hr) Avg ROP(m/hr) POB Temperature(`C) Weather Wind 2,564.89 1,179.96 609.60 14.28 42.7 97.0 -47.8 Clear WC-72++ SSW 274'@11 mph Daily summary operation 24h Summary Perform LOT with 9.4 ppg.OBM(FazePro)-EMW=12.1 ppg.\Drill ahead rotary steerable as per well plan. Operation at 07.00 Dolling 8 3/4"rotary steerable production section. 24h Forecast Drill ahead 8 3/4"production section as per well plan. Lithology Shows MAASP(kgflcm2) Mud Weight(gIL) 1138.4 Time Log __-----.--____ Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. '`. 00:00 01 00 1.00 1.00 DRILL E 12 P -erform LOT with 9.4 ppg.OEM(FazePro)mud-EMW=12.1 pp. ty 01:00 06.00 5.00 6.00 DRILL E '3 P Drill-•..- ""..'- '-'s-- .• :93 r 4 --ump rate 550 gpm @ 1750 psi.\80-120 rpm @ 8-12K torque.\WOB= 2-14K\Up wt.=165K-Dn wt.=133K-Rot wt.=149K\MW=9.4 ppg\ECD 10.64 ppg.\ART=3.34 hrs.\ADT=3.46 hrs.\ Jars=3.46 hrs. 06:00 12:00 6.00 12.00 DRILL E 3 P Drill Rotary Steerable 9/6732'-117280'(3887'TVD)-Pump rate 550 qpm @ 1800 psi.\80-130 rpm @ 10-15K torque./WOB= 2-14K\Up wt.=170K-Dn wt.=115K-Rot wt.=147K/MW=9.4 ppg\ECD 10.83 ppg.\ART=3.33 hrs.\ADT=6.79 hrs.\ Jars=6.79 hrs. 12:00 18.00 6.00 18.00 DRILL E 3 P Drill Rotary Steerable(/7280'-1/7872'(3869'ND)-Pump rate 550 gpm @ 1860 psi.\130 rpm @ 7-15K torque.\WOB=10- 15K/Up wt.=170K-Dn wt.=125K-Rot wt.=145K\MW=9.4 ppg\ECD 10.90 ppg.\ART=3.68 hrs.\ADT=10.47 hrs.\Jars =10.47 hrs. 18.00 0000 6.00 24.00 DRILL E 3 P Drill Rotary Steerable 1/7872'-118415'(3870'TVD)-Pump rate 550 gpm @ 1920 psi.\70-130 rpm @ 7-20K torque.\WOB= 10-15K\Up wt.=190K-Dn wt.=120K-Rot wt.=145K\MW=9.4 ppg\ECD 11.20 ppg.\ART=3.93 hrs.\ADT=14.40 hrs.\ Jars=14.4 hrs. Daily Contacts Position Contact Name Company Title E-mail Office Mobile Eni representative David F Smith ENI Drilling Supv. SIDDrilling@enipetroleum.com 907-685-0715 632-3058 Eni representative Geoff Ackerman ENI HSE geoff.ackerman@enipetroleum.co 907-685-0721 Tool Push Steve Dambacher Doyon Drilling Tool Pusher rig15@doyondnlling.com 907-685-0716 Tool Push Chad Johnson Doyon Drilling Tour Pusher rig15@doyondrilling.com 907-685-0716 Eni representative Mike Ross ENI Senior Drilling Supv SIDDrilling@enipetroleum.com 907-685-0715 Eni representative John Spaulding ENI Drilling Rig Clerk AKRigClerksDoyon15@enipetroleum.com 907-685-0722 355-2607 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(mKB) Bottom(mKB) Run Date CASING 95/8 8.835 L80 944 1,941.39 1/19/2012 Last Leakoff Test Depth(mKB) TVD(mKB) Fluid Type Fluid Density(gIL) P Surf Applied(kgflcm') Eq.Mud Weight(gIL) P LeakOff(kgflcm') 1,941.27 1,187.26.OBM(FazePro) 1126.4 38.3 1449.3 172.0 l Eni E&P Division I Well Name:SP23-N3 EN!Petroleum Co.Inc. Daily Report Well Code:26152 Field Name:Nikaitchuq • API/UWI:50-629-23456-00-00 2^ Date:1/24/2012 - Report#: 23 If l' page 1 of 1 Wellbore name: SP23-N3 Well Header Permit/Concession N° Operator ENI Share(%) Well Configuration type 211127 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(m) Ground Level(m) Water Depth(m) RKB-Base Flange(m) RKB-Tubing Spool(m) 12.46 16.46 3.99 11.22 9.73 Rig Information Contractor Rig Name Rig Type DOYON DRILLING DOYON 15 LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(mKB) Target Depth(ND...Depth Dr.(MD)(m) Drilling Hours(hr) Avg ROP(m/hr) DFS(days) SP23-N3 DRILLING 1/6/2012 4,250.74 1,163.32 5,315.68 200.06 26.6 18.31 Daily Information End Depth(mKB) End Depth(TVD)(... Depth Progress(m) Drilling Hours(hr) Avg ROP(m/hr) POB Temperature(°C) Weather Wind 2.972 41 1,175.86 875.39 45.50 19.2 97.0 -46.9 Clear WC-77 SW 227"@11.6 mph Daily summary operation 24h Summary Drill ahead with rotary steerable 1/8415'-10187'MD hit fault.BROOH to 9815'.Perform side tack from 9815'-9850'.Cont.drilling f/9850'-9950'. Operation at 07.00 Drill ahead 8 3/4"production hole 24h Forecast Drill ahead 8 3/4"production hole as planned. Lithology Shows MAASP(kgflcm') Mud Weight(gIL) 1138.4 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. • 00:00 06:00 6.00 6.00 DRILL E 3 P Dr-1g f/8415'-9099'MD(3884'ND)2-10k WOB,130 rpm,170k puw.110k sow,142k rotw.11-13k tq on.10-14k tq 08,11.21 ecd.3550 max gas. 0.0 AST,4.24 ART,4.24 ADT 18.64 jars. 06:00 12:00 6.00 12.00 DRILL E 3 P Ddg.1/9099'-9750'MD(3858'TVD)2-16k wob,130 rpm.190k puw,100k sow,145k rotw,11-13k tq on.10-14k tq off,11.52 ecd.3123 max gas 0.0 AST,2.61 ART,2.61 ADT.SPR @ 9159'and(3885'TVD)#1 @ 30=320 psi:©40=360 psi #2 @ 30=300 psi;@ 40=380 psi. 12:00 17.00 5.00 17.00 DRILL E 3 P Dig.1/9750'-10,187'MD(3663'ND)550 gpm,2100 psi,10-15k wab,130 rpm,200k puw,75k sow,140k rotw,9-19k tq on, 8-15k tq off,11.3 ecd,2195 max gas.24.62 bit,24.64 jars.Note hit fault. 17:00 19.30 2.50 19.50 DRILL E 4 P .BROOH f/10187'-9815'MD 550 gpm,2050 psi,130 rpm,11-12k tq,140k rotw. 19:30 22:30 3.00 22.50 DRILL F 3 P 'Perform open hole side track 1/9815'-9850'. 22:30 00:00 1.50 24.00 DRILL E 3 P Ddg.f/9850'-9950'MD(3850'ND)550 gpm,2100 psi,10-15 wob.130 rpm,190k puw,120k sow.140k rotw,9-19k tq on, 8-15k tq off,11.3 ecd,38 max gas.27.4 bit,27.4 jars.SPR @ 10,005'MD(3839'ND)w/9.4 ppg mud,#1 @ 30=300psi, @ 40=370 #2 @ 30=310psi,@ 40=380 #3 @ 30=310psi,@ 40=380 Daily Contacts Position Contact Name Company Title E-mail Office Mobile Eni representative David F Smith ENI -Drilling Supv. SIDDnlling@enipetroleum.com '907-685-0715 632-3058 Eni representative Geoff Ackerman ENI HSE geof.ackerman@enipetroleum.co 907-685-0721 Tool Push Steve Dambacher Doyon Dolling Tool Pusher rig15@doyondrilling.com 907-685-0716 Tool Push Chad Johnson Doyon Dolling Tour Pusher rig15@doyondnlling.com 907-685-0716 Eni representative Mike Ross ENI Senior Drilling Supv SIDDolling(genipetroleum.com 907-685-0715 Eni representative John Spaulding ENI Dulling Rig Clerk AKRigClerksDoyonl5@enipetroleum.com 907-685-0722 355-2607 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(mKB) Bottom(mKB) Run Date CASING 95/8 8.835 L80 9.44 1.941.39 1/19/2012 Last Leakoff Test Depth(mKB) ND(mKB) Fluid Type Fluid Density(g/L) P Surf Applied(kgflcm') Eq.Mud Weight(gIL) P LeakOff(kgflcm') 1.941.27 1,187.26 OBM(FazePro) 1126.4 38.3 1449.3 172.0 Yr* Eni E&P Division Well Name:SP23-N3 ENI Petroleum Co.Inc. Daily Report Well Code:26152 Field Name:Nikaitchuq •ii Date:1/25/2012 - Report#: 24 APIIUWI:50-629-23456-00-00 2" " page 1 of 1 Wellbore name: SP23-N3 Well Header Permit/Concession N° Operator ENI Share(%) Well Configuration type 211127 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(m) Ground Level(m) Water Depth(m) RKB-Base Flange(m) RKB-Tubing Spool(m) 12,46 16.46 3.99 11.22 9.73 Rig Information Contractor Rig Name Rig Type DOYON DRILLING DOYON 15 LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(mKB) Target Depth(TVD...Depth Dr.(MD)(m) Drilling Hours(hr) Avg ROP(m/hr) DFS(days) SP23-N3 DRILLING 1/6/2012 4,250.74 1,163.32 5,315.68 200.06 26.6 19.31 Daily Information End Depth(mKB) End Depth(TVD)(... Depth Progress(m) Drilling Hours(hr) Avg ROP(m/hr) POE Temperature(°C) Weather Wind 3.589.63 1,156.61 1,240.14 48.00 25.8 97.0 -45.8 Clear WC-80 SSW 207'@ 11.6 • mph • • Daily summary operation 24h Summary I Drill 1/9950'-11,777'MD(3812'TVD) Operation at 07.00 Drill ahead 8 3/4"production hole. 24h Forecast Drill ahead 8 3/4"production hole as planned. Lithology Shows MAASP(kgf/cm') Mud Weight(gIL) • 1126.4 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00:00 06.00 6.00 6.00 DRILL -E 3 P DrIg.f/9950'-10,387'MD(3847'TVD).550gpm,2100 psi,2-18 web,130 rpm,180k puw,105 sow,140k rotw.13k tq on,12k tq off.11.29 ecd.3000 max gas.0.0 AST,6.53 ART,6.53 ADT,33.93 jars.33.93 bit. 06:00 12.00 6.00 12.00 DRILL E 3 P DrIg.f/10,387'-10,903'MD(3856'ND)550 gpm,2100 psi,2-14k wob,130 rpm,185k puw,105k sow,145k rotw,13k tq on,13-14k tq off,11.40 ecd,2300 nax gas.0.0 AST.2.56 ART,2.56 ADT,36.49 jars,36.49 bit.SPR @ 10,745'MD(3847' TVD)w/9.45 MW#1 @ 30=320 psi,@ 40=390 psi,#2 @ 30=300 psi,@ 40=390 psi,#3 @ 30=330 psi,@ 40=400 psi. 12:00 18.00 6.00' 18.00 DRILL •E 3 P Drip.f/10,903'-11,526'MD(3663'ND)550 gpm.2150 psi,10-15k wob.130 rpm.9-15k tq on,14k tq off,200k puw,80k sow.145k rotw,10.6 ecd.3310 max gas. 18.00 00:00 6.00' 24.00 DRILL .-E 3 P DrIg.f/11,526'-11,777'MD(3812'ND)550 gpm.2300 psi,10-15k web,130 rpm.9-15k tq on,14k tq off,190k puw,110k sow.145k rotw,11.5 ecd,583 max gas.0.0 AST,8.21 ART,8.21 ADT.44.7 jars,44.7 bit.SPR @ 11.493'MD(3851'TVD) w/9.45 MW#1 @ 30=330 psi,@ 40=400 psi,#2 @ 30=330 psi,@ 40=400 psi,#3 @ 30=330 psi,@ 40=400 psi. Daily Contacts Position Contact Name Company Title E-mail Office Mobile Eni representative Russ Wrmmer ENI Drilling Supv. SIDDnlling@enipetroleum.com 907-685-0715 907-320-0058 Eni representative Geoff Ackerman ENI HSE geoff.ackerman@enipetroleum.co 907-685-0721 Tool Push Dave Evans Doyon Drilling Tool Pusher rig15@doyondnlling.com 907-685-0716 Tool Push Pete Martinusen Doyon Drilling Tour Pusher rig15@doyondnlling.com 907-685-0716 Eni representative Mike Ross ENI Senior Drilling Supv SIDDnlling@enipetroleum.com 907-685-0715 Eni representative John Spaulding ENI Drilling Rig Clerk AKRigClerksDoyon15@enipetroleum.com 907-685-0722 355-2607 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(mKB) Bottom(mKB) Run Date CASING 95/8 8.835 L80 9.44 1.941.39 1/19/2012 Last Leakoff Test Depth(mKB) TVD(mKB) Fluid Type Fluid Density(gIL) P Surf Applied(kgf/cm') Eq.Mud Weight(gIL) P LeakOff(kgflcm') 1.941.27 1,187.26 OBM(FazePro) 1126.4 38.3 1449.3 172.0 !Pi* Eni E&P Division (Well Name:SP23-N3 ENI Petroleum Co.Inc. Daily Report Well Code:26152 Field Name:Nikaitchuq • APIIUWI:50-629-23456-00-00 2^ Date:1/26/2012 - Report#: 25 II II page 1 of 1 Wellbore name: SP23-N3 Well Header Permit/Concession N° Operator ENI Share(%) Well Configuration type 211127 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(m) Ground Level(m) Water Depth(m) RKB-Base Flange(m) RKB-Tubing Spool(m) 12.46 16.46 3.99 11.22 9.73 Rig Information Contractor Rig Name Rig Type DOYON DRILLING DOYON 15 LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(mKB) Target Depth(TVD...Depth Dr.(MD)(m) Drilling Hours(hr) Avg ROP(m/hr) DFS(days) SP23-N3 DRILLING 1/6/2012 4,250.74 1,163.32 5,315.68 200.06 26.6 20.31 Daily Information End Depth(mKB) End Depth(TVD)(... Depth Progress(m) Drilling Hours(hr) Avg ROP(mlhr) POB Temperature(°C) Weather Wind 4,215.08 1,155.33 625.45 24.00 26.1 97.0 -42.8 Clear WC-75 SSW 210`@ 11.6 mph Daily summary operation 24h Summary Drill f/11,777'-13829'MD(3809'TVD).. Operation at 07.00 Circ.and BROOH. 24h Forecast TD well @ 14,021'MD Circ.and BROOH Lithology Shows MAASP(kgflcm°) Mud Weight(gIL) 1126.4 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00.00 06:00 6.00 6.00 DRILL -E 3 P Ddg.f/11,777'-12,427'MD(3799'TVD)6-18k wob,130 rpm,14k tq on.13k tq off,183k puw,l0ok sow,141k rotw,11.84 ecd, 623 max gas.2.95 ART/ADT,47.65 Bi/Jars.SPR @ 12.333'MD(3803'TVD)w/9.4 MW,#1 @ 30=390 psi,@ 40=470,#2 @ 30=390,@ 40=470,#3 @ 30=400,@ 40=470 psi. 06.00 12:00 6.00 12.00 DRILL E 3 P Ddg.f/12,427-12,769'MD(3784'TVD)2-18k wob,130 rpm,15k tq on,10k tq off,185k puw,80k sow.140 rotw,11.85 end. 820 max gas.3.61 ART/ADT,51.26 Bit/Jars. • 12:00 .18:00 6.00 18.00 DRILL E 3 P Dig.f/12,769'-13,335'MD(3800'TVD)550 gpm,2350 psi,10-15k wob,130 rpm,10-19k tq on,13k tq off,220 puw,75-90k sow,130k rotw,11.9 ecd.SPR @ 12,893'MD(3787'TVD)w4 9.4 MW,#1 @ 30=390 psi,@ 40=460,#2 @ 30=390,@ 40=460,#3 @ 30=400.@ 40=470 psi. 18:00 00.00 6.00 24.00 DRILL E 3 P Drlg f/13.335'-13,829'MD(3809'TVD)525 gpm.2350 psi,10-15k wob,130 rpm,10-15k tq on.13k tq off,220k puw,75k sow.138k rotw,12.1 ecd,1083 max gas.6.2 ART/ADT,57.46 Bit/Jars. Daily Contacts Position Contact Name Company Title E-mail Office Mobile Eni representative Russ Wimmer ''ENI Drilling Supv. SIDDnlling@enipetroleum.com '907-685-0715 907-320-0058 Eni representative Geoff Ackerman ENI HSE geoff.ackerman@enipetroleum.co 907-685-0721 Tool Push Dave Evans Doyon Drilling Tool Pusher ng15@doyondrilling.cow 907-685-0716 Tool Push Pete Martinusen Doyon Drilling Tour Pusher rig15@doyondrilling.com 907-685-0716 Eni representative Mike Ross ENI Senior Drilling Supv SIDDnlling@enipetroleum.com 907-685-0715 Eni representative Tom Norvig ENI Dulling Rig Clerk AKRigClerksDoyonl5@enipetroleum.com 907-685-0722 229-6100 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(mKB) Bottom(mKB) Run Date CASING 95/8 8.835 L80 9.44 1,941.39 1/19/2012 Last Leakoff Test Depth(mKB) TVD(mKB) Fluid Type Fluid Density(gIL) P Surf Applied(kgflcm') Eq.Mud Weight(gIL) P LeakOff(kgf/cm') 1,941.27 1,187.26 OBM(FazePro) 1126.4 38.3 1449.3 172.0 IllY* Eni E&P Division Well Name:SP23-N3 EN!Petroleum Co.Inc. Daily Report Well Code:26152 Field Name:Nikaitchuq • APIIUWI:50-629-23456-00-00 2 �I^,1 Date:1/27/2012 - Report#: 26 I' I� page 1 of 1 Wellbore name: SP23-N3 Well Header Permit/Concession N° Operator ENI Share(%) Well Configuration type 211127 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(m) Ground Level(m) Water Depth(m) RKB-Base Flange(m) RKB-Tubing Spool(m) 12.46 16_46 3.99 11.22 9.73 Rig Information Contractor Rig Name Rig Type DOYON DRILLING DOYON 15 LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(mKB) Target Depth(ND...Depth Dr.(MD)(m) Drilling Hours(hr) Avg ROP(m/hr) DFS(days) SP23-N3 DRILLING 1/6/2012 4,250.74 1,163.32 5,315.68 200.06 26.6 21.31 Daily Information End Depth(mKB) End Depth(TVD)(... Depth Progress(m) Drilling Hours(hr) Avg ROP(m/hr) POB Temperature(°C) Weather Wind 4,273 60 1,153.95 58.52 0.90 65.0 99.0 -42.8 Wind,Blowing Snow, 270 W @ 14 mph WC-83 Daily summary operation 24h Summary TD well @ 14,021'MD Circ.and BROOH Operation at 07.00 BROOH 24h Forecast BROOH to inside of casing.Circ.until clean.POOH on elevators and LD BHA. Lithology Shows MAASP(kgf/cm') Mud Weight(gIL) 1126.4 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00:00 01 30 1.50 1.50 DRILL E 3 P Dig.f/13,829'-14,021'MD(3804'ND)500 gpm.2200 psi,2-12k wob,130 rpm,15k tq on,15k tq off,185k puw 140k rotw, 11.8 ecd,606 max gas.1.37 ART/ADT,58.83 BIT/JARS.SPR @ 14,021'MD(3804'TVD)w/9.4 MW#1 @ 30=490 psi,@ 40=580.#2 @ 30=500,@ 40=580.#3 @ 30=480.@ 40=580 psi. 01:30 02:00 0.50 2.00 DRILL E 20 P Monitor well-Static.L/D single jt of DP. 02:00 02:30 0.50 2.50 DRILL E 4 P BROOH to 13.994'520 qpm.2340 psi,13k tq,135 rpm,140k puw.Observed losses @ 160 bph.Reduce gpm and RIH to 14,014'MD.Total of 70 bbls lost. 02:30 03:00 0.50 3.00'DRILL E 7 P Circ.@ 300 gpm,1110 psi 12k tq,135 rpm,min.losses. 03:00 04:30 1.50 4.50 DRILL 'E 7 P Circ.50 bbl 17ppb calcium carb pill while bringing pump rate up in stages to 510 gpm,2250 psi.losses @ 40 bph. 04:30 06:00 1.50 6.00'DRILL E 4 P BROOH to 13,939'510 qpm,2250 psi 12k tq,135 rpm,140k puw.Losses increased to 84 bph. 06:00 12:00 6.00 12.00 DRILL E 4 P 'BROOH f/13,924'-13,453'450-500 gpm,2180 psi,12k tq,132k puw.Loss rate @<4obph. 12.00 18:00 6.00 18.00'DRILL E 4 P CBU and BROOH f/13,453'-12,900'500 gpm,2050 psi,13k tq,135 rpm.140k puw,110k sow,142k rotw.racking 2-stds per BU.30 bbls total losses.Monitor well-Static. 18.00 00:00 6.00 24.00`DRILL E 4 P BROOH f/12,900'-12.047'.500 gpm,1975 psi,12-13k tq,135 rpm.140k puw,110k sow.142 rotw,racking 2-stds per BU. 39 bbls total losses.Monitor well-Static. Daily Contacts Position Contact Name Company Title E-mail Office Mobile Eni representative Russ Wimmer ENI Drilling Supv. -SIDDdlling@enipetroleum.com 907-685-0715 '907-320-0058 Eni representative Geoff Ackerman ENI HSE geoff.ackerman@enipetroleum.co 907-685-0721 Tool Push Dave Evans Doyon Drilling Tool Pusher ng15@doyondrilling.com 907-685-0716 Tool Push Pete Marlinusen Doyon Drilling Tour Pusher rig15@doyondrilling.com 907-685-0716 Eni representative Mike Ross ENI 'Senior Drilling Supv SIDDnlling@enipetroleum.com 907-685-0715 Eni representative Tom Norvig ENI Dulling Rig Clerk AKRigClerksDoyon15@enipetroleum.com 907-685-0722 229-6100 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(mKB) Bottom(mKB) Run Date CASING 95/8 8.835 L80 9.44 1,941.39 1/19/2012 Last Leakoff Test Depth(mKB) ND(mKB) Fluid Type Fluid Density(gIL) P Surf Applied(kgflcm') Eq.Mud Weight(gIL) P LeakOff(kgf/cm') 1.941.27 1.187.26 OBM(FazePro) 1126.4 38.3 1449.3 172.0 Eni E&P Division I Well Name:SP23-N3 ENI Petroleum Co.Inc. Daily Report Well Code:26152 Field Name:Nikaitchuq c19* • API/UWI:50-629-23456-00-00 2 illi^ Date:1/28/2012 - Report#: 27 page 1 of 1 Wellbore name: SP23-N3 Well Header Permit/Concession N' Operator EM Share(%) Well Configuration type 211127 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(m) Ground Level(m) Water Depth(m) RKB-Base Flange(m) RKB-Tubing Spool(m) 12.46 16.46 3.99 11.22 9.73 Rig Information Contractor Rig Name Rig Type DOYON DRILLING DOYON 15 LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(mKB) Target Depth(TVD...Depth Dr.(MD)(m) Drilling Hours(hr) Avg ROP(m/hr) DFS(days) SP23-N3 DRILLING 1/6/2012 4,250.74 1,163.32 5,315.68 200.06 26.6 22.31 Daily Information End Depth(mKB) End Depth(TVD)(... Depth Progress(m) Drilling Hours(hr) Avg ROP(m/hr) POB Temperature('C) Weather Wind 4,273.60 1,153.95 0.00 102.0 -38.9 Cloudy,WC-67' 310'WNW @ 14 mph Daily summary operation 24h Summary BROOH to 9065'. Operation at 07.00 BROOH to 5500' 24h Forecast BROOH to 5500'.CBU x 3.POOH and L/D BHA.R/U Casing equip.PJSM and run 5.5"liner. Lithology Shows MAASP(kgflcm') Mud Weight(g/L) 1126.4 Time Log Start End Cum Time Time Our(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00.00 06:00 6.00 6.00 DRILL E 4 P BROOH f/12,047'-10.840'500 gpm,2000 psi,12k tq,135 rpm,138 puw,115k sow.86 bbls total losses. 06:00 12:00 6.00 12.00 DRILL E 4 P BROOH fl 10,840'-9952'500 gpm,1950 psi,10-11k tq,135 rpm,135k puw.83 bbls total losses. 12:00 13:30 1.50 13.50 DRILL 'E 4 P BROOH f/9952'-9687',500 gpm,1750 psi,135 rpm,12k tq,140k puw,115 sow,142k rotw.Monitor well-Static.4 bbls total losses. 13:30 14:30 1.00 14.50 DRILL E 4 P Began BROOH and noticed 8 bbl loss.Monitor well Breathing.Well went Static. 14.30 18:00 3.50 18.00 DRILL E 4 P BROOH f/9687'-9440'500 gpm,1750 psi,135 rpm,l0k tq,140k puw,115k sow,145k rotw.34 bbls total losses. 18.00 00:00 6.00 24.00 DRILL E 4 P BROOH 1/9440'-9065'500 gpm,1700 psi,135 rpm,ilk tq,140k puw.120k sow.145k rotw.48 bbls total losses.Note Canning shales causing torque and packoff problems.Worked clean. Daily Contacts Position Contact Name Company Title E-mail Office Mobile Eni representative Russ Wimmer ENI Dnlling Supv. SIDDrilling@enipetroleum.com 907-685-0715 907-320-0058 Eni representative Geoff Ackerman ENI HSE geof.ackerman@enipelroleum.co 907-685-0721 Tool Push Dave Evans Doyon Dulling Tool Pusher rig15@doyondrilkng.cons 907-685-0716 Tool Push Pete Martinusen Doyon Dulling Tour Pusher ug15@doyondrilkng.com 907-685-0716 I-- Eni Eni representative Mike Ross ENI Senior Drilling Supv SIDDrilling@enipetroleum.com 907-685-0715 Eni representative Tom Norvig ENI Dulling Rig Clerk AKRigClerksDoyon15@enipetroleum.com 907-685-0722 229-6100 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(mKB) Bottom(mKB) Run Date CASING 9518 8.835 L80 9.44 1.941.39 1/19/2012 Last Leakoff Test Depth(mKB) TVD(mKB) Fluid Type Fluid Density(gIL) P Surf Applied(kgf/cm') Eq.Mud Weight(g/L) P LeakOff(kgf/cm') 1.941.27 1.187.26 OBM(FazePro) 1126.4 38.3 1449.3 172.0 Eni E&P Division f Well Name:SP23-N3 EN!Petroleum Co.Inc. Daily Report Well Code:26152 Field Name:Nikaitchuq 011* � API/UWI:50-629-23456-00-00 2 II^ Date:1/29/2012 - Report#: 28 I' II Ipage 1 of 1 Wellbore name: SP23-N3 Well Header Permit/Concession N° Operator ENI Share(%) Well Configuration type 211127 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(m) Ground Level(m) Water Depth(m) RKB-Base Flange(m) RKB-Tubing Spool(m) 12.46 16.46 3.99 11.22 9.73 Rig Information Contractor Rig Name Rig Type DOYON DRILLING DOYON 15 LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(mKB) Target Depth(ND...Depth Dr.(MD)(m) Drilling Hours(hr) Avg ROP(mihr) DFS(days) SP23-N3 DRILLING 1/6/2012 4,250.74 1,163.32 5,315,68 200.06 26,6 23.31 Daily Information End Depth(mKB) End Depth(TVD)(... Depth Progress(m) Drilling Hours(hr) Avg ROP(mlhr) POB Temperature(°C) Weather Wind 4,273.60 1.153.95 0,00 102.0 -35,0 Cloudy,Snow 225`SW @ 10 mph Fluries,Patchy Fog, WC-59° Daily summary operation 24h Summary BROOH to 5500'.CBU x 3.POOH and L/D BHA. Operation at 07.00 M/U and run 5.5"liner as planned. 24h Forecast • R/U,M/U and run 5.5"liner WI Baker liner packer to 13,967'and set. Lithology Shows MAASP(kgflcm°) Mud Weight(gIL) 1126.4 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00.00 06:00 6.00 6.00 DRILL E 4 P BROOH f/9065'-7140'.500 gpm,1700 psi.135 rpm.9-10 tq,142k puw.68 bbls total losses. 06.00 09:30 3.50 9.50 DRILL E 4 P Brooh 5 7140'-6366'(9 5/8"Csg shoe).500 gpm,1400 psi,135 rpm,9k tq.Monitor well-Static. 09.30 12:00 2.50' 12.00 DRILL E 4 P BROOH f/6366'-5703'500 gpm,1300 psi,135 rpm,8k tq,143k puw.46 bbls total losses. 12:00 14:30 2.50 14.50 DRILL E 4 P BROOH f/5703'-5500'500 gpm,1300 psi,135 rpm,8-10k tq,145k puw,135k sow,145k rotw.CBU until shakers were clean.8 bbls total losses. 14:30 15:00 0.50 15.00 DRILL E 19 P B/D TD.Monitor well,Static. 15:00 18:00 3.00 18.00 DRILL E 4 P POOH on elevators f/5500'-3720'148k puw,135k sow. 18:00 21:30 3.50 21.50 DRILL E 4 P POOH II 3720'-291'85k puw,85k sow.Well static. 21:30 22:00 0.50 22.00 DRILL E '20 'P PJSM for L/D BHA&Nuclear source W/Schlumberger. 22:00 00:00 2.00 24.00 DRILL E 4 'P Unload Nuclear source and L/D.L/D BHA f/291'-73'. Daily Contacts Position Contact Name - Company Title E-mail Office Mobile Eni representative Russ Wimmer ENI Drilling Supv. SIDDnlling@enipetroleum.com 907-685-0715 907-320-0058 Eni representative Geoff Ackerman ENI HSE geoff.ackennan@enipetroleum.co 907-685-0721 Tool Push Dave Evans Doyon Dnlling Tool Pusher ng15@doyondrilling.com 907-685-0716 Tool Push Pete Martinusen Doyon Drilling Tour Pusher ng15@doyondrilling.com 907-685-0716 Eni representative Mike Ross ENI Senior Dolling Supv SIDDrilling@enipetroleum.com 907-685-0715 Eni representative Tom Norvig ENI Drilling Rig Clerk AKRigClerksDoyonl5@enipetroteum.com 907-685-0722 229-6100 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(mKB) Bottom(mKB) Run Date CASING 95/8 8.835 L80 9.44 1.941.39 1/19/2012 Last Leakoff Test Depth(mKB) ND(mKB) Fluid Type Fluid Density(gIL) P Surf Applied(kgflcm°) Eq.Mud Weight(gIL) P LeakOff(kgflcm°) 1.941.27 1,187.26 OBM(FazePro) 1126.4 38.3 1449.3 172.0 11* Eni E&P Division I Well Name:SP23-N3 ENI Petroleum Co.Inc. Daily Report Well Code:26152 Field Name: Nikaitchuq • APIIUW1:50-629-23456-00-00 2^ Date:1130/2012 - Report#: 29 II �I page 1 of 1 Wellbore name: SP23-N3 Well Header Permit/Concession N° Operator ENI Share(%) Well Configuration type 211127 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(m) Ground Level(m) Water Depth(m) RKB-Base Flange(m) RKB-Tubing Spool(m) 12.46 16.46- 3.99 11.22 9.73 Rig Information Contractor Rig Name Rig Type DOYON DRILLING DOYON 15 LAND RIG _ Job Information Wellbore Job Phase Spud Date Target Depth(mKB) Target Depth(TVD...Depth Dr.(MD)(m) Drilling Hours(hr) Avg ROP(m/hr) DFS(days) SP23-N3 DRILLING 1/6/2012 4,250.74 1.163.32 5,315.68 200.06 26.6 24.31 Daily Information End Depth(mKB) End Depth(TVD)(... Depth Progress(m) Drilling Hours(hr) Avg ROP(m/hr) POB Temperature(°C) Weather Wind 4,273.60 1,153.95 0.00 105.0 -41.1 Partly Cloudy.WC- 290`NW @6 mph 56 Daily summary operation 24h Summary R/U.M/U and run 5.5"liner w/Baker liner packer to 13,967'and Drop ball. Operation at 07.00 Displace OBM mud to 9.0 ppg KCL brine. 24h Forecast Set Packer and test.Release from packer and pull 1-std.Displace OBM mud to 9.0 ppg KCL brine.POOH L/D DP. Lithology Shows MAASP(kgflcm°) Mud Weight(g/L) 1126.4 - Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00.00 01:00 1.00 1.00 DRILL E 4 P PJSM.L/D BHA f/73' 01'.00 01 30 0.50 1.50 DRILL E 20 P Clear and clean rig floor. 01:30 02:30 1.00 2.50 DRILL E 20 P PJSM,R/U GBR Casing equipment. 02:30 12:00 9.50 12.00 DRILL E 4 P RIH w/5.5"15.56 Hydril 521 slotted liner 1/4821'(115 jts.). 12:00 16:30 4.50 16.50 DRILL E 4 P RIH w/5.5"slotted liner f/4821'-7760'(Total of 185 its.).145k puw,120k sow. 16:30 17:30 1.00 17.50 DRILL E 20 P PJSM,M/U Baker packer assy.w/running tool.as per Baker and well plan.RIH 1/7804'. 17:30 18:00 0.50 18.00 DRILL E 20 P R/D and clear floor of GBR casing equipment.Prep.to run 5"DP from derrick. 18.00 18:30 0.50 18.50 DRILL E 4 P RIH w/5.5"liner on 1 std of 5"DP f/7804'-7897'and record parameters.145k puw,120k sow,133k rotes,4-7k tq. 18.30 00.00 5.50 24.00 DRILL E 4 P RIH w/5.5"slotted liner on 5"DP f/7897'-13,966',100k sow.Liner went to bottom without rotating.Total losses on liner job were 8 bbls. Daily Contacts Position Contact Name Company Title E-mail Office Mobile Eni representative Russ Wimmer 'ENI Dolling Supv. SIDDnlling@enipetroleum.com 907-685-0715 907-320-0058 Eni representative Geoff Ackerman ENI HSE geoff.ackerman@enipetroleum.co 907-685-0721 Tool Push Dave Evans Doyon Drilling Tool Pusher ng15@doyondrilling.com 907185-0716 Tool Push Pete Martinusen Doyon Drilling Tour Pusher ng15@doyondnlling.com 907185-0716 Eni representative Mike Ross ENI Senior Drilling Supv SIDDnlling@enipetroleum.com 907-685-0715 Eni representative Tom Norvig ENI Drilling Rig Clerk AKRigClerksDoyon15@enipetroleum.com 907-685-0722 229-6100 Completion Engineer Michele Cesan ENI Completion Engr. Michele.Cesari@enipetroleum.com 907-865-3338 907-230-9701 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(mKB) Bottom(mKB) Run Date CASING 9 5/8 8.835 L80 9.44 1.941.39 1/19/2012 Last Leakoff Test Depth(mKB) TVD(mKB) Fluid Type Fluid Density(g/L) P Surf Applied(kgflcm°) Eq.Mud Weight(g/L) P LeakOff(kgflcm°) 1,941.27 1,187.26 OBM(FazePro) 1126.4 38.3 1449.3 172.0 1 if* Eni E&P Division Well Name:SP23-N3 ENI Petroleum Co.Inc. Daily Report Well Code:26152 Field Name:Nikaitchuq • 2^n Date:1/31/2012 - Report#: 30 APIIl1Wl:50-629-23456 -00 I' II II page 1 of 1 Wellbore name: SP23-N3 Well Header Permit/Concession N° Operator ENI Share(%) Well Configuration type 211127 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(m) Ground Level(m) Water Depth(m) RKB-Base Flange(m) RKB-Tubing Spool(m) 12.46 16.46 3.99 11.22 9.73 Rig Information Contractor Rig Name Rig Type DOYON DRILLING DOYON 15 LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(mKB) Target Depth(ND...Depth Dr.(MD)(m) Drilling Hours(hr) Avg ROP(m/hr) DFS(days) SP23-N3 DRILLING 1/6/2012 4,250.74 1,163.32 5,315.68 200.06 26.6 25.31 Daily Information End Depth(mKB) End Depth(TVD)(... Depth Progress(m) Drilling Hours(hr) Avg ROP(m/hr) POB Temperature(°C) Weather Wind 4,273.60 1,153.95 0.00 105.0 -45.0 Partly Cloudy,WC- 270"W @ 8 mph 73' Daily summary operation 24h Summary Set Packer and test.Release from packer and pull 1-std.Displace OBM mud to 9.0 ppg KCL brine.POOH L/D DP. Operation at 07.00 Prep.4.5"completion tools and equipment. 24h Forecast Finish L/D DP and stand back 26 stds for surface hole.Prep.8 run 4.5"completion tubing as per plan. Lithology Shows MAASP(kgf/cm') Mud Weight(g/L) 1078.4 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. _ Act. Plan Oper.Descr. 00:00 00:30 0.50' 0.50 DRILL E 4 P Fill pipe and drop 1.75"frac ball.P/U 5"single DP M/U and establish rotary parameters(/13,968-13,981'@ 30 rpm,12k tq, 150k rotw.Release torque and pull up to 13,966',200k pow. 00:30 01:00 0.50 1.00 DRILL E '19 -P Establish circ.@ 3 bpm,230 psi for 500 stks.then 2 bpm,180 psi.Pressure liner to 3000 psi for 5 min.to start hanger/packer set.pressure to 4000 psi for 5 min..Sheared packer setting tool @ 3400 psi.Bleed pressure to 0 psi. 01:00 01:30 0.50 1.50'DRILL E 12 P Close upper rams and pressure up IA to 1500 psi for 10 min.to test packer.Good.Bleed pressure to 0 psi and open rams. 01.30 03:00 1.50 3.00 DRILL E 12 P Altemot to release from liner hanger.Set down on hanger and repressure liner to 4000 psi.Bleed to 0 psi and released from hanger,160k puw.Establish rotary @ 20 rpm.3-4k torq,150k rotw and set down wI 90k sow w/dog sub.6175'TOL. 5.5"shoe @ 13.966'.Rack 1 std in derrick. 03:00 06:00 3.00 6.00 DRILL E 7 P PJSM.Displace well with 610 bbls of 9.0 ppg KCL bnne @ 5 bpm,310 psi ICP,110 psi FCP.Monitor well-static. 06:00 12:00 6.00 12.00 DRILL E 4 P PJSM.POOH 8 LID DP f/6100'-1213',170k puw. 12:00 13:30 1.50 13.50 DRILL E 4 P POOH UD DP f/1213'-surf.UD Baker running tool.Monitor well-static. 13:30 19:30 6.00 19.50 DRILL E 4 P RIH w/31 stds 5"DP and POOH L/D singles. 19:30 00:00 4.50 24.00 DRILL E 4 P RIH w/52 stds 5"DP 8 POOH UD 21 jts. Daily Contacts Position Contact Name Company Title E-mail Office Mobile Eni representative Russ Wimmer ENI Dolling Supv. SIDDrilling@enipetroleum.com 907-685-0715 907-320-0058 Eni representative Geoff Ackerman ENI HSE geof.ackerman@enipetroleum.co 907-685-0721 Tool Push Dave Evans Doyon Drilling Tool Pusher rig15@doyondrilling.com 907-685-0716 Tool Push Pete Martinusen Doyon Drilling Tour Pusher rig15@doyondrilling.com 907-685-0716 Eni representative Mike Ross ENI Senior Drilling Supv SIDDnlling@enipetroleum.com 907-685-0715 Eni representative Tom Norvig ENI Dulling Rig Clerk AKRigClerksDoyon15@enipetroleum.com 907-685-0722 229-6100 Completion Engineer Michele Cesan ENI Completion Engr. Michele.Cesan@enipetroleum.com 907-865-3338 907-230-9701 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(mKB) Bottom(mKB) Run Date LINER 51/2 4.950 L80 9.12 4.266.26 1/31/2012 Last Leakoff Test Depth(mKB) ND(mKB) Fluid Type Fluid Density(gIL) P Surf Applied(kgflcm') Eq.Mud Weight(gIL) P LeakOff(kgflcm') 1.941.27 1,187.26 OBM(FazePro) 1126.4 38.3 1449.3 172.0 Eni E&P Division ..} (Well Name:SP23-1J3 fill*• ENI Petroleum Co.Inc. Daily Re p o l l Well Code:26152 Field Name: Nikaitchuq • APIIUWI:50-629-23456-00-00 2^ Date:2/1/2012 - Report#: 1 II 'I page 1 of 1 Wellbore name: SP23-N3 Well Header Permit/Concession N° Operator ENI Share(%) Well Configuration type 211127 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(m) Ground Level(m) Water Depth(m) RKB-Base Flange(m) RKB-Tubing Spool(m) • 12.46 16.46 3.99 11.22 9.73 Rig Information Contractor Rig Name Rig Type • DOYON DRILLING DOYON 15 LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(mKB) Target Depth(TVD...Depth Dr.(MD)(m) Drilling Hours(hr) Avg ROP(mlhr) DFS(days) SP23-N3 COMPLETION 1/6/2012 4,273.60 26.31 Daily Information End Depth(mKB) End Depth(TVD)(... Depth Progress(m) Drilling Hours(hr) Avg ROP(mlhr) POB Temperature(°C) Weather Wind 0.00 104.0 -35.0 Partly Cloudy.WC- 20°NNE @ 24 mph 59- Daily summary operation 24h Summary Finish L/D DP and stand back 26 stds for surface hole.Prep.&run 4.5"completion tubing as per plan.WO weather. Operation at 07.00 Running 4.5"completion stung. 24h Forecast Running 4.5"completion tubing as per plan. Lithology Shows MAASP(kgflcm') Mud Weight(g/L) 1078.4 Time Log Start End Cum Time Time Dur(hr) Our(hr) Phase Opr. Act. Plan Oper.Descr. 'OMNI 03.30 3.50 3.50 COMP K 4 P PJSM,POOH L/D DP T/2418'.POOH rack back 26 stds for next well.Flush and wash BOP stack. 03:30 04:00 0.50 4.00'COMP K 20 P Clear and clean floor. 04:00 04:30 0.50 4.50 COMP K '19 P Pull wear bushing. 04:30 06:00 1.50 6.00 COMP K 20 P PJSM,Mob.centrilifl tools and equip.to rig floor. 06:00 0830 2.50 8.50 COMP K 20 'P -R/U Centrilifl tools and GBR casing. 08:30 0930 1.00 9.50 COMP K '20 P PJSM,M/U XO sub,pressure dicharge sub,XO pup,1-jt.4.5"tbg.,4.5"pup jt,TTC,XO w/screen intake,116 STG pump as per Centrilift.Stand in demck. 09:30 12.00 2.50 12.00 COMP K '22 U Shut down operations do to weather conditions of-54 degrees F. 12:00 18.00 6.00 18.00 COMP K 22 U WO Weather.Rig performing maintenance and housekeeping. 18:00 20.00 2.00 20.00'COMP K 4 P PJSM,Install wear bushing and TIH U 2237'. 20:00 20.30 0.50 20.50'COMP K 7 P Circ.well 84 gpm,37 psi to keep from freezing. 20:30 22.30 2.00 22.50 COMP K '22 U WO weather. 22 30 23:30 1.00 23.50'COMP K 7 P Circ.well.84 gpm.20 psi.Mon/or well-static. 23:30100.00 0.50 24.00-COMP K 22 U WO weather. Daily Contacts Position Contact Name Company Title _ E-mail Office Mobile Eni representative Russ Wimmer ENI Dulling Supv. SIDDnlling@enipetroleum.cow 907-685-0715 907-320-0058 Eni representative Geoff Ackerman ENI HSE geoff.ackerman@enipetroleum.no 907-685-0721 Tool Push Dave Evans Doyon Dulling Tool Pusher rig15@doyondrilling.com 907-685-0716 Tool Push Pete Marlinusen Doyon Drilling Tour Pusher rig15@doyondrilling.com 907-685-0716 Eni representative Mike Ross ENI Senior Drilling Supv SIDDnlling@enipetroleum.com 907-685-0715 Eni representative Tom Norvig ENI Drilling Rig Clerk AKRigClerksDoyont5@enipetroleum.com 907-685-0722 229-6100 Completion Engineer Michele Cesan ENI Completion Engr. Michele.Cesari@enipetroleum.com 907-865-3338 907-230-9701 I Last Casing seat Cas.Type OD(in) ID(in) Grade Top(mKB) Bottom(mKB) Run Date LINER 51/2 4.950 L80 9.12 4,266.26 1/31/2012 Last Leakoff Test Depth(mKB) TVD(mKB) Fluid Type Fluid Density(gIL) P Surf Applied(kgflcm') Eq.Mud Weight(gIL) P LeakOff(kgflcm') 1,941.27 1,187.26 OBM(FazePro) 1126.4 38.3 1449.3 172.0 1� Eni E&P Division Well Name:SP23-N3 EN!Petroleum Co.Inc. Daily Report Well Code:26152 Field Name: Nikaitchuq 2Date• API/UWI:50-629-23456-00-00 ^ii :2/2/2012 - Report#: 2 " II page 1 of 1 Wellbore name: SP23-N3 Well Header Permit/Concession N° Operator ENI Share(%) Well Configuration type 211127 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(m) Ground Level(m) Water Depth(m) RKB-Base Flange(m) RKB-Tubing Spool(m) 12.46 16.46 3.99 11.22 9.73 Rig Information Contractor Rig Name Rig Type DOYON DRILLING DOYON 15 LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(mKB) Target Depth(TVD...Depth Dr.(MD)(m) Drilling Hours(hr) Avg ROP(m/hr) DFS(days) SP23-N3 COMPLETION 1/6/2012 4,273.60 27.31 Daily Information End Depth(mKB) End Depth(TVD)(... Depth Progress(m) Drilling Hours(hr) Avg ROP(mlhr) FOB Temperature(°C) Weather Wind 0.00 101.0 -27.8 Cloudy,WC-46° 50°ENE @ 24 mph Daily summary operation 24h Summary Running 4.5"completion tubing as per plan. Operation at 07.00 Running 4.5"completion tubing. 24h Forecast Run 4.5"completion tubing as per plan and land. Lithology Shows MAASP(kgf/cm') Mud Weight(gIL) 1078.4 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00:00 01:30 1.50 1.50 COMP K -22 U WO weather.Monitor well with trip tank. 01:30 02:00 0.50 2.00 COMP K 7 P Circ.kill string @ 2 bpm,50 psi.R/D circ.equipment. 02:00 03:00 1.00 3.00 COMP 'K 4 'P POOH wl kill string and rack back in derrick. 03.00 03:30 0.50 3.50 COMP K 19 P Pull wear bushing. 03:30 05:30 2.00 5.50 COMP K '20 P PJSM,P/U Tubing assy.from derrick and RIH.R/U Halco wire line equipment. 05:30 06:00 0.50 6.00 COMP 'K 20 'P P/U pump assy.and set w/wire line. 06:00 06:30 0.50 6.50 COMP K '20 P P/U and set pump pack off assy.and test tool. 06:30 08:00 1.50 8.00 COMP K 20 P Fill tubing w/water and seals leaked.Pull test tool,repin and reset. 08:00 09:00 1.00 9.00 COMP K 20 'P Fill tubing w/water and R/U to test pack off.Tested to 1000 psi f/15 min.Charted.R/D test equipment.Set tubing stop. 09:00 10:30 1.50 10.50 COMP 'K -20 P R/D Halco wire line equip.M/U XO.POOH and check pump rotation vd centrilift.Good.Rack tubing in derrick. 10:30 13:30 3.00 13.50 COMP K 20 P PJSM,R/U ESP and Cap.tube sheaves w/Cables.Tie down at rig floor. 13:30 18:00 4.50 18.00 COMP K 20 P PJSM,P/U&M/U motor and seal assy.as per Centrilift. 18:00 19:00 1.00 19.00 COMP K 20 P Connect 1/4"TEC tube to Discharge sub and RIH. 19:00 21:00 2.00 21.00 COMP K 20 P Install clamps as per plan while RN w/jt.of 4.5"tubing.Splice MLE to power cable. 21:00 21:30 0.50 21.50 COMP K 20 P Baker perform MEG and Continuity test on ESP line.Good.Connect cap tube. 21:30 00:00 2.50 24.00 COMP K '4 P RIH wl 4.5"12.6#L-80 HYD 563 ESP completion tubing U 600'.90k sow Daily Contacts Position Contact Name Company Title E-mail Office Mobile Eni representative Russ Wimmer ENI Drilling Supv. SIDDnlling@enipetroleum.com 907-685-0715 907-320-0058 Eni representative Geoff Ackerman ENI HSE geoff.ackerman@enipetroleum.co 907-685-0721 Tool Push Dave Evans Doyon Dolling Tool Pusher rig15@doyondrilling.com 907-685-0716 Tool Push Pete Martinusen Doyon Drilling Tour Pusher rig15@doyondrilling.com 907-685-0716 Eni representative Mike Ross ENI Senior Drilling Supv SIDDnlling@enipetroleum.com 907-685-0715 Eni representative Tom Norvig ENI Drilling Rig Clerk AKRigClerksDoyon15@enipetroleum.com 907-685-0722 229-6100 Completion Engineer Michele Cesari ENI Completion Engr. Michele.Cesari@enipetroleum.com 907-865-3338 907-230-9701 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(mKB) Bottom(mKB) Run Date LINER 51/2 4.950 L80 9.12 4,266.26 1/31/2012 Last Leakoff Test Depth(mKB) TVD(mKB) Fluid Type Fluid Density(gIL) P Surf Applied(kgflcm°) Eq.Mud Weight(gIL) P LeakOff(kgflcm') 1,941.27 1,187.26 OBM(FazePro) 1126.4 38.3 1449.3 172.0 IP* Eni E&P DIVI510Division ..} I Well Name:SP23-N3 ENI Petroleum Co.Inc. Daily Repo 1 Well Code:26152 Field Name:Nikaitchuq � APIIUWI:50-629-23456-00-00 n Date:2/3/2012 - Report#: 3 • sS i II ii page 1 of 1 Wellbore name: SP23-N3 Well Header Permit/Concession N° Operator ENI Share(%) Well Configuration type 211127 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(m) Ground Level(m) Water Depth(m) RKB-Base Flange(m) RKB-Tubing Spool(m) 12.46 16.46 3.99 11.22 9.73 Rig Information Contractor Rig Name Rig Type DOYON DRILLING DOYON 15 LAND RIG Job Information , Wellbore Job Phase Spud Date Target Depth(mKB) Target Depth(TVD...Depth Dr.(MD)(m) Drilling Hours(hr) Avg ROP(m/hr) DFS(days) • SP23-N3 COMPLETION 1/6/2012 4,273.60 28.31 Daily Information End Depth(mKB) End Depth(TVD)(... Depth Progress(m) Drilling Hours(hr) Avg ROP(m/hr) POB Temperature(°C) Weather Wind 0.00 102.0 -30.3 Partly Cloudy.WC- 228 SW @ 10 mph 48 Daily summary operation 24h Summary Run 4.5"completion tubing as per plan and land.Install BPV and nipple down stack. Operation at 07.00 Test Tree. 24h Forecast Complete N/D of stack,N/U and test Tree.Check ESP integrity.Shear GLM valve and displace completion fluid to diesel.R/U Halco wire line and replace upper GLM valve.R/D wire line.Release ng. Lithology Shows MAASP(kgflcm°) Mud Weight(gIL) 1078.4 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00:00 13:30 13.50 13.50 COMP K 4 P PJSM,RIH w/4.5"12.68 L-80 H563 ESP completion tubing f/600'-5912'.(143 total jts.,153 Total damps as follow,141 Cannon XC clamps,2 MLE Cannon clamps,2 Cannon 562,1 Cannon Gator,4 Cannon 513,3 Chnstolizers • 13:30 14:00 0.50 14.00 COMP K '19 P PJSM for P/U&M/U tubing hanger.Monitor Well. 14:00 16:30 2.50 16.50 COMP K 20 P P/U&M/U tubing hanger and make final splices.Test ESP cable.Vetco,Centrilift and Completion Eng.present. 16:30 17:30 ' 1.00 17.50 COMP K 19 P Drain stack and rinse.Land tubing hanger and run in lock down screws.135k puw,115k sow.Test upper and lower seals • to 5000 psi for 10 min..Witnessed by Completion Eng.Check electrical integrity of ESP.Pull&UD landing jt.Install BPV. 1730 19.30 2.00 19.50 COMP K 20 P PJSM,Unstring cap line and ESP cable.Clear floor of all remaining completion tools and equipment.Leave sheaves in demck until testing is done. 19.30 22:00 2.50 22.00 COMP K 20 P Clean and isolate drip pan.Disconnect flow line.Prep.to N/D stack. 22:00 00:00 2.00 24.00 COMP K 20 P R/D choke and kill line.Cont.to prep.stack for removal. Daily Contacts Position Contact Name Company Title _ E-mail Office Mobile Eni representative Russ Wimmer 'ENI Drilling Supv. SIDDrilling@enipetroleum.com 907-685-0715 907-320-0058 Eni representative Jack Potter ENI HSE jack.potter@enipetroleum.com 907-685-0721 Tool Push Dave Evans Doyon Dolling Tool Pusher rig15@doyondrilling.com 907-685-0716 Tool Push Chad Johnson Doyon Dolling Tour Pusher ng15@doyondrilling.com 907-685-0716 Eni representative Mike Ross ENI Senior Dolling Supv SIDDrilling@enipetroleum.com 907-685-0715 Eni representative Tom Norvig ENI Drilling Rig Clerk AKRigClerksDoyon15@enipetroleum.com 907-685-0722 229-6100 Completion Engineer Michele Cesan ENI Completion Engr. .Michele.Cesarkgenipetroleum.com 907-865-3338 907-230-9701 Last Casing seat • Cas.Type OD(in) ID(in) Grade Top(mKB) Bottom(mKB) Run Date LINER 51/2 4.950 L80 9.12 4.266.26 1/31/2012 Last Leakoff Test Depth(mKB) TVD(mKB) Fluid Type Fluid Density(gIL) P Surf Applied(kgflcm°) Eq.Mud Weight(gIL) P LeakOff(kgf/cm') 1.941.27 1,187.26.OBM(FazePro) 1126.4 38.3 1449.3 172.0 r 1 Eni E&P Division I Well Name:SP23-N3 011* ENI Petroleum Co.Inc. Daily Report Well Code:26152 Field Name: Nikaitchuq • APIIUWI:50-629-23456-00-00 2^[I Date:2/4/2012 - Report#: 4 I' IIpage 1 of 1 Wellbore name: SP23-N3 Well Header Permit/Concession N° Operator ENI Share(%) Well Configuration type 211127 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(m) Ground Level(m) Water Depth(m) RKB-Base Flange(m) RKB-Tubing Spool(m) 12.46 16.46 3.99 11.22 9.73 Rig Information Contractor Rig Name Rig Type DOYON DRILLING DOYON 15 LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(mKB) Target Depth(TVD...Depth Dr.(MD)(m) Drilling Hours(hr) Avg ROP(m/hr) DFS(days) SP23-N3 COMPLETION 1/6/2012 4,273.60 29.31 Daily Information End Depth(mKB) End Depth(TVD)(... Depth Progress(m) Drilling Hours(hr) Avg ROP(m/hr) POB Temperature(°C) Weather Wind 0.00 104.0 -10.3 Partly Cloudy.WC- 186"W @ 13.8 mph 11.3` Daily summary operation 24h Summary Complete N/D of stack,N/U and test Tree.Check ESP integrity.Shear GLM valve and displace completion fluid to diesel.R/U Halco wire line and replace upper GLM valve.R/D wire line.Release rig. Operation at 07.00 Move rig to SI29-S2. 24h Forecast R/D and move rig to SI29-S2. Lithology Shows MAASP(kgf/cm') Mud Weight(g/L) 1078.4 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00:00 06:30 6.50 6.50 COMP K 20 P N/D BOPE and riser.Prep.well head and install adapter and tree.Pull BPV and install test plug.Test hanger void/packoff to 5000 psi for 10 min.Test tree assy.to 5000 psi for 10 min.Charted.All tests witnessed by Vetco and Co-man.R/D testing equip.and secure well head area.Centrilift performed last ESP tests-Good.R/U to freeze protect well w/Lil Red. 06:30 10:30 4.00 10.50 COMP K 9 P PJSM w/LIL Red on freeze protecting well.Pressure test lines to 2500 psi.Pump diesel and shear upper GLM valve© 2400 psi.Displace well w/170 bbls diesel.Shut well in,R/D LIL Red and hook up to U-Tube. 10:30 12:00 1.50 12.00 COMP K 20 P R/U Halco wire line.Blow down choke manifold. 12:00 14:00 2.00 14.00 COMP K 20 P Cont.to R/U vote line,BOPE and lubricator. 14.00 18:00 4.00 18.00 COMP K 12 P Pressure test lubricator to 2500 psi.RIH and set plug catcher.Run#2 Attempt to retrieve sheared valve no success.POOH and change tools. 18.00 21:00 3.00 21.00 COMP K 19 P Halco RIH#3 and retrieve sheared valve from GLM. Run#4 set new shear valve in GLM.Pressure test to 500 psi for 5 min.Run#5 RIH and retrieve plug catcher. 21:00 22:00 1.00 22.00 COMP K 20 P PJSM R/D Halco slick line and well control equipment.R/D Centrilift sheaves from derrick. 22:00 00:00 2.00 24.00 COMP K 20 P Secure well and prep.for rig move.Did not install BPV in well.Rig Release @ 2400 hrs. Daily Contacts Position Contact Name Company Title E-mail Office Mobile Eni representative Russ Wimmer 'ENI Drilling Supv. 'SIDDrilling@enipetroleum.com 907-685-0715 907-320-0058 Eni representative Jack Potter ENI HSE jack.potter@enipeyoleum.com 907-685-0721 Tool Push Dave Evans Doyon Dnlling Tool Pusher rig15@doyondrilling.com 907-685-0716 Tool Push Chad Johnson Doyon Drilling Tour Pusher rig15@doyondnlling.com 907-685-0716 Eni representative Mike Ross ENI Senior Dolling Supv SIDDrilling@enipetroleum.com 907-685-0715 Eni representative Tom Norvig ENI Drilling Rig Clerk AKRigClerksDoyonl5@enipetroleum.com 907-685-0722 229-6100 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(mKB) Bottom(mKB) Run Date LINER 51/2 4.950 L80 9.12 4,266.26 1/31/2012 Last Leakoff Test Depth(mKB) TVD(mKB) Fluid Type Fluid Density(g/L) P Surf Applied(kgflcm°) Eq.Mud Weight(g/L) P LeakOff(kgf/cm') 1.941.27 1,187.26 OBM(FazePro) 1126.4 38.3 1449.3 172.0 v `m 666 666 66 ava :1813 $N0NNOOQN3pmpV 6p60p86Qve eevvev4av44va 2Q0 23 ssn82 52 35 § 2CG GG GG GG O OO CC GG 0 rr.rr 1...,,,, rrr.,,,,,.., rrrAN,rr NrnNN2N2p II: V WNpApp 2OPOAA2gA mc0O2N 2AMM0,2pOmf� A 0p2N ON mo/ UNuUNoO lmYY00 OOMN 20 mG0pCOAIO8S'AFIS O522OtQa. c4gggG � gV Ag Ati � R N 7 88 88 33 88 88 88§88 33 &0NN Nrd aNnaONr,-N .GNt0C N000 - 044a, NNd00NIt •=v 00 -01 ONOr A28%4 3AgRS NP421:: A283 N3QA- mAa-N 2 -88 q v NON V N m W W t 0 W2Ao1 feOOnA W�r1�Nr r Sqfg ON arD r7N0 . . 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Inc.Alaska Dispatched To: Christine Shartzer Well No SP23-N3 Date Dispatched: 24-Feb-12 Installation/Rig Doyon 15 Dispatched By: Hector Echeto Data No Of Prints No of CDs SP23-N3 Log 1 2 in MD 1 2inTVD 1 5 in MD 1 5 in TVD 1 Received By: Et/4L12) Please sign and return one copy to: 3800 Centerpoint Drive,Suite 300 Anchorage,Alaska 99503, Andrew Buchanan andrew.buchananc enipetroleum.com LWD Log Delivery V2.1,03-06-06 Scblumberger Drilling &Measurements MWD/LWD Log Product Delivery Customer ENI US Operating Co.Inc.Alaska Dispatched To: Christine Shartzer Well No SP23-N3BP1 Date Dispatched: 24-Feb-12 Installation/Rig Doyon 15 Dispatched By: Hector Echeto Data No Of Prints No of CDs SP23-N3BP1 Log 1 2 in MD 1 2 in TVD 1 5 in MD 1 5 in TVD 1 Received By: MeilgOte,c,, &TA,/ Please sign and return one copy to: 3800 Centerpoint Drive,Suite 300 Anchorage,Alaska 99503, Andrew Buchanan andrew.buchanan( enipetroleum.com LWD Log Delivery V2.1,03-06-06 HALLIBURTON Sperry Drilling To: Alaska Oil and Gas Conversation Commission 333 W 7th Ave Suite 100 Anchorage, AK 99501 Attn: Howard Oakland From: Sperry Drilling -Alaska Attn: Robert Haverfield 6900 Arctic Blvd. Anchorage, AK 99518 907-273-3559 Office 907-273-3535 Fax Robert.Haverfield(a�Halliburton.com Re: Eni Well — SP23-N1 AFE # 5454 Rig — Doyon 15 Spy Island —Nikaitchuq, Alaska Shipment Includes: 1 End of Well Reports I $ 1 Final Data Listing on CD-ROM 1 Sets of Final Logs —each contains: • 2" Color Log — Formation Evaluation TVD' • 2" Color Log — Formation Evaluation MD" • 2" Color Log — Drilling Engineering MD • 2" Color Log Gas Ratio MD ✓ Received By: Print Name NO\/J\ Sign Name Date Please sign acknowledgement of receipt - email, fax, or mail back. Thank you. 2 tI7 HALLIBURTON 211 11 Enii Piir©Ikuirn Sperry Drilling PACKING LIST Spy Island Drillsite Nikaitchuq SP23-N3&SP23-N3 ST1 Shipping Date: 28-Jan-2012 Spy Island,Alaska Ship From: Ship To: ENI Petroleum AOGCC C/O Sperry Drilling Alaska 333 West 7th Avenue; Suite 100 301 East 92nd Avenue;Suite 2 Anchorage,AK 99501 Anchorage,AK 99515 Attn: Howard Oakland 907-739-1235 tem Description Interval Packaging Box Description SP23-N3 Washed and Dried Samples-50' 2,787'to 5,500' Paper envelopes 1 of 5 Washed and Dried Samples-50' 5,500'to 7,800' Paper envelopes 2 of 5 Washed and Dried Samples-50' 7,800'to 10,100' Paper envelopes 3 of 5 Washed and Dried Samples-50' 10,100'to 12,200' Paper envelopes 4 of 5 Washed and Dried Samples-50' 12,200 to 14,021'TD Paper envelopes 5 of 5 SP23-N3 ST1 Washed and Dried Samples-50' 9,850'to 10,187'TD Paper envelopes 5 of 5 One(1)Bundle Contains all Five(5)Boxes Notes:Box#5 contains samples from both wells Total Packages this Shipment: 1 Please notify sender upon receipt of delivery; Andrew Buchanan 907-865-3388 Received by Expediter: \a\ Date: cIL �� �6 a1 � - 1Pl. 7 Page 1 of 2 Schwartz, Guy L (DOA) From: Davies, Stephen F(DOA) Sent: Tuesday, January 03, 2012 11:17 AM To: Schwartz, Guy L (DOA);joe.longo@enipetroleum.com Cc: Johnson, Elaine M (DOA) Subject: RE: SP23-N3 API Number J)7 T 2-1/— /17 Guy,Joseph: Thank you for catching my error. The current API number for SP23-N3 is wrong. I apparently assigned 50-029-23456-00-00 based on the cover letter text stating it was an onshore well. Since the well is actually drilled from an offshore location, the proper API number is 50-629-23456-00-00. I'll have it changed in the AOGCC's databases and I'll place a copy of this email in the well history file. Elaine, Could you please make this API number change in the RBDMS database? Thanks to all, Steve Davies AOGCC From: Schwartz, Guy L(DOA) Sent: Tuesday, January 03, 2012 10:46 AM To: Davies, Stephen F (DOA) Subject: FW: SP23-N3 API Number Can you help with the API? Guy Schwartz Senior Petroleum Engineer AOGCC 793-1226 (office) 444-3433 (cell) From: Longo Joseph [mailto:joe.longo@enipetroleum.com] Sent: Tuesday, January 03, 2012 10:40 AM To: Schwartz, Guy L (DOA) Subject: SP23-N3 API Number Guy, Happy New Year! I have a question about the SP23-N3 API Number. Looking at the API Number's for our previous wells on the island they all have the following format 50-629- 2345X-00-00. SP23-N3's API Number is 50-029-23456-00-00, should this be 629 being that is on the island/ offshore? Looking at the original APD it looks like we incorrectly specified that it was "onshore" in the cover letter which the AOGCC corrected but I don't think the API number reflects the correction. SD37-DSP1: 50-629-23451-00-00 SP18-N5: 50-629-23453-00-00 1/4/2012 Page 2 of 2 SP27-N1: 50-629-23458-00-00 SP23-N3: 50-029-23456-00-00 Also I was wondering what the status of the 2 week BOP test window is? Sorry to bombard you I'm sure you are busy coming back from the Holidays! Regards, Joseph Longo Drilling Engineer Anchorage, AK Office (Anchorage): (907) 865-3323 Office (North Slope): (907) 685-1226 Cell: (907) 947-4323 Email: Joseph.Longo@ienipetroleum.com Message for the recipient only, if received in error, please notify the sender and read http://www.eni.it/disclaimer/ This message may contain information that is confidential, and is being sent exclusively to the Recipient. If you are not the designated Recipient, you are prohibited from utilizing, copying or divulging the information contained in this message,or taking any action whatsoever on the basis of the information herein. If you have received this message by mistake, we ask you to kindly inform the Sender and to delete the message. It is understood that, with regard to messages sent by its network, the Company is not responsible for any statements made or opinions expressed, that are not strictly related to the Company's operations. 1/4/2012 iftkir VLF T" SEAN PARNELL,GOVERNOR ALASKA OIL AND GAS 333 W.7th AVENUE,SUITE 100 CONSERVATION COMMISSION ANCHORAGE,ALASKA 99501-3539 PHONE (907)279-1433 FAX (907)276-7542 Maurizio Grandi Well Operation Manager ENI US Operating, Co. Inc. 3800 Centerpoint Drive, Suite 300 Anchorage, AK 99503 Re: Nikaitchuq Field, Schrader Bluff Oil Pool, SP23-N3 ENI US Operating, Co. Inc. Permit No: 211-127 Surface Location: 4449.8' FSL, 1374.2' FEL, SEC. 19, T14N, R9E, UM Bottomhole Location: 3976' FSL, 3655' FEL, SEC. 13, T14N, R8E, UM Dear Mr. Grandi: Enclosed is the approved application for permit to drill the above referenced development well. This permit to drill does not exempt you from obtaining additional permits or an approval required by law from other governmental agencies and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. Sincerely, I / I iel T. Sea ,ount, Jr. Chair DATED thisa,day of September, 2011. cc: Department of Fish 86 Game, Habitat Section w/o encl. (via e-mail) Department of Environmental Conservation w/o encl. (via e-mail) STATE OF ALASKA RECE V Dj A (A OIL AND GAS CONSERVATION COM, ;ION SEP 14 2011 PERMIT TO DRILL 20 AAC 25.005 �iele la.Type of Work: lb.Proposed Well Class: Development-Oil Q• Service- Winj ❑ Single Zone nu c Drill Q- Redrill ❑ Stratigraphic Test ❑ Development-Gas ❑ Service-Supply ❑ Multiple Zone ❑ Coalbed Gepffirn6lydrates ❑ Re-entry ❑ Exploratory ❑ Service- WAG ❑ Service-Disp ❑ Shale Gas ❑ 2.Operator Name: 5. Bond: Blanket E. Single Well ❑ 11.Well Name and Number: ENI US Operating Co.Inc. Bond No. RLB0008627 SP23-N3 ' 3.Address: 6.Proposed Depth: 12.Field/Pool(s): 3800 Centerpoint Drive Suite 300,Anchorage 99503 MD: 13610 ' TVD: 3801 Nikaitc uq 4a. Location of Well(Governmental Section): 7.Property Designation(Lease Number): .3,/,,,,l,„ /„(.-- Surface: 4449.8 FSL 1374.2 FEL S19 T14N R9E UM ADL 391283,388583,388574 041 ,"�} A ,2 ,/ Top of Productive Horizon: 8.Land Use Permit: 13.Approximate Spud Date: 3845 FSL 3417 FEL 19 T14N R9EUM ADL 417493 11/13/2011 Total Depth: 9.Acres in Property: 14.Distance to Nearest Property: 3976 FSL 3655 FEL 13 T14N R8EUM 1280 11064'to unit boundary 4b.Location of Well(State Base Plane Coordinates-NAD 27): 10.KB Elevation above MSL: .53.4 feet 15.Distance to Nearest Well Open Surface:x- �5 1582" _... y- 6053640Zone- 4 n GL Elevation above MSL: .12.4 feet to Same Pool: OP09-S1 SlI53S.�j (,c)5.3(•'a[- 5�t 1 •/ r/ 16.Deviated wells: Kickoff depth: 200 feet , 17.Maximum Anticipated Pressures in psig(see 20 AAC 25.035) Maximum Hole Angle: 90° degrees Downhole: 1776 psig . Surface: 1342 psig 18.Casing Program: Specifications Top - Setting Depth - Bottom Cement Quantity,c.f.or sacks _Hole Casing Weight Grade Coupling Length MD i TVD MD ' TVD (including stage data) Driven 20" 178.89 X-65 Welded 124 36 36 160 160 pre-installed 16" 13-3/8" 68 L-80 BTC 2249 35 35 2284 2173 1033 sx 10.7#ASL,240 sx 12.5#Deeperete • : 12.25" 9-5/8" 40 L-80 Hydril 563 6025 33 33 6058 3958 665 sx 12.5#Deeperete . _8.75" 5.5" 15.5 L-80 Hydril 521 7752 5858' 3958 13610 3801 uncemented liner in open hole , 19. PRESENT WELL CONDITION SUMMARY(To be completed for Redrill and Re-Entry Operations) Total Depth MD(ft): Total Depth TVD(ft): Plugs(measured): Effect.Depth MD(ft): Effect.Depth TVD(ft): Junk(measured): Casing Length Size Cement Volume MD ND Conductor/Structural Surface Intermediate - Production Liner Perforation Depth MD(ft): Perforation Depth TVD(ft): 20. Attachments: Property Plat Q BOP Sketch Q Drilling Program ❑✓ Time v.Depth Plot ❑ Shallow Hazard Analysis Q Diverter Sketch Seabed Report ❑ Drilling Fluid Program ❑., 20 AAC 25.050 requirements 21. Verbal Approval: Commission Representative: Date 22. I hereby certify that the foregoing is true and correct. Contact Luca Boni @ 907-865-3328 Printed Name Maurizio Grandi Title Well Operation Project Manager Signature At(C ),/(46"/( Le ' Phone 907-865-3320 Date 9/9/2011 Commission Use Only Permit to Drill API Number: �. Permit App v I See cover letter for other Number: 21 i7 50-� .�_ �'C Date: ��a 1 1) requirements. Conditions of approval: If box is checked,well may not be used to explore for,test,or produce co Ibed mettine,gas hydrates,or gas contained in shales: Er Other: 4 3500 ps. OIp (e41 Samples req'd: Yes❑ No Er Mud log req'd: Yes ❑ No Er 'I'E 250.0 r S.- /4K n w� /d... eS C+�i K g---- Z.-NoJ H2S measures: Yes❑ No Directional svy req'd: Yes No ❑ / (2.- I/ / APPROVED BY THE COMMISSION DATE: ,COMMISSIONER 7/ . Z(.rc ORIGINAL d A9,( Form 10-401(Revised 7/2009) This permit is valid for 24 months from the date of approval(20 AAC 25.005(g)) Submit in Duplicate TA. E i '' troHeum em RECEIVED, SEP 14 2O1 Mega l+ 3800 Centerpoint Drive Suite 300 �a Anchorage,Alaska 99503 01118 Oil&Gas OAS, CO Maurizio Grandi �111SS1011 Phone(907)865-3320 Anchorage Email: Maurizio.Grandi@enipetroleum.com September 09,2011 Alaska Oil and Gas Conservation Commission 333 West 7th Avenue,Suite 100 Anchorage,Alaska 99501 RE: Application for Permit to Drill producer SP23-N3 Dear Commissioners, ap a to�P ENI US Operating Co.Inc.hereby applies for a Permit to Drill for the.9.ustr5re producer well SP23-N3.The well will be drilled and completed using Doyon rig 15. The planned spud date is 11/13/2011. Please find attached for the review of the Commission forms 10-401 and the information required by 20 ACC 25.005 for this well bore. If you have any questions or require further information,please contact Joseph Longo at 907-865-3323 or Jason Brink at 907-865-3321 or Luca Borri at 907-865-3328. Sincerely, /1/k VIA— Maurizio Grandi Well Operation Project Manager If* Oliktok Point Nikaitchuq Field o ' 2no petroleum SP23-N3 (P3) Alaska DIR/LWD FORM DEPTH HOLE CASING MUD INFO Drilling MWD MD TVD SIZE SPECS Hazards Cement to Surface 20" X-65 20"Conductor Shoe 160' 160' N/A Welded/Driven N/A 0 GR/Res Surface Csq Dir -a 13-3/8" Base Permafrost 1847 1,843' m 68 lbs/ft MW(ppg) Wellbore Stability Mud Motor 1— L-80,BTC 9.2-9.5 Lost Circulation Hole Cleaning it a a m a , m an n 7 13-318"Casing Point 2,284' 2,173' m 16" 50°F WBM GR/RES PWD i Inter.Casing Wellbore Stability 9-5/8" Lost Circulation 40 lbs/ft MW(ppg) Hole Cleaning L-80,Hydril 563 9.4 Torque&Drag TOC 3,917' l PM N " "N"Sand Top 4,917' c ; GG 5"f/ / 1•S' 43 n s ; TOL 5,858' 9-5/8"Casing Point 6,058' 3,958' 12-1/4" 85`F LSND GR/RES Periscope/PWD Wellbore Stability Neutron/Density Lost Circulation Schrader Bluff Slotted Liner Hole Cleaning Lateral 5-1/2" Torque&Drag 15.5 lbs/ft MW(ppg) Xceed 675 L-80,Hydril 521 9.4 (Geo-Steering) 5-1/2"Slotted Liner TD/5-1/2"Lnr 13,610' 3,801' 8-3/4" 85"F FazePro volt • Cin Petirolleum 2rnno Application for Permit to Drill Saved:9-Sep-11 Application for Permit to Drill Document Table of Contents 1. Well Name 3 Requirements of 20 MC 25.005(f) 3 2. Location Summary 3 Requirements of 20 MC 25.005(c)(2) 3 Please see Attachment 7:Surface Platt 3 Requirements of 20 MC 25.050(6) 3 3. Blowout Prevention Equipment Information 4 Requirements of 20 MC 25.005(c)(3) 4 4. Drilling Hazards Information 4 Requirements of 20 MC 25.005(c)(4) 4 5. Procedure for Conducting Formation Integrity Tests 4 Requirements of 20 MC 25 005(c)(5) 4 6. Casing and Cementing Program 5 Requirements of 20 MC 25005(c)(6) 5 7. Diverter System Information 5 Requirements of 20 MC 25005(c)(7) 5 8. Drilling Fluid Program 6 Requirements of 20 MC 25005(c)(8) 6 Surface Hole Mud Program (extended bentonite) 6 Intermediate Hole Mud Program(LSND) 6 Lateral Mud Program(MI FazePro Mineral Oil Base) 6 9. Abnormally Pressured Formation Information 6 Requirements of 20 MC 25 005(c)(9) 6 10. Seismic Analysis 7 Requirements of 20 MC 25005(c)(10) 7 11. Seabed Condition Analysis 7 Requirements of 20 MC 25 005(c)(11) 7 AOGCC PERMIT Document.doc Page 1 of 9 Printed.9-Sep-11 trot • BM PetiroHeuirn enn Application for Permit to Drill Saved:9-Sep-11 12. Evidence of Bonding 7 Requirements of 20 MC 25,005(c)(12) 7 13. Proposed Drilling Program 7 Requirements of 20 MC 25.005(c)(13) 7 14. Discussion of Mud and Cuttings Disposal and Annular Disposal 8 Requirements of 20 MC 25.005(c)(14) 8 15. Attachments 9 Attachment 1 Directional Plan 9 Attachment 2 Drilling Hazards Summary 9 Attachment 3 BOP and Diverter Configuration 9 Attachment 4 Cement Loads and CemCADE Summary 9 Attachment 5 Well Schematic 9 Attachment 6 Formation Integrity And Leak Off Test Procedure 9 Attachment 7 Surface Platt 9 AOGCC PERMIT Document.doc Page 2 of 9 Printed:9-Sep-11 *A • • En tiroIIe Application for Permit to Drill Saved:9-Sep-11 1. Well Name Requirements of 20 MC 25.005(0 Each well must be identified by a unique name designated by the operator and a unique API number assigned by the commission under 20 MC 25.040(b). For a well with multiple well branches, each branch must similarly be identified by a unique name and API number by adding a suffix to the name designated for the well by the operator and to the number assigned to the well by the commission. Well Name: SP23-N3 2. Location Summary Requirements of 20 AAC 25.005(c)(2) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (2)a plat identifying the property and the property's owners and showing (A)the coordinates of the proposed location of the well at the surface,at the top of each objective formation, and at total depth, referenced to governmental section lines. (B)the coordinates of the proposed location of the well at the surface, referenced to the state plane coordinate system for this state as maintained by the National Geodetic Survey in the National Oceanic and Atmospheric Administration; (C)the proposed depth of the well at the top of each objective formation and at total depth; Location at Surface 4449.8 FSL 1374.2 FEL S19 T14N R9E UM ASP Zone 4 NAD 27 Coordinates RKB Elevation 53.4'AMSL Northing 6053631.530' Easting: 511535.620' Pad Elevation 12.4'AMSL Location at Top of 3845 FSL 3417 FEL 19 T14N R9E UM Productive Interval ("OA"Sand) ASP Zone 4 NAD 27 Coordinates Measured Depth, RKB: 6010' Northing: 6053023.60' Easting:509496.20' Total Vertical Depth, RKB: 3953' Total Vertical Depth, SS:: 3890' Location at Total Depth 3976 FSL 3655 FEL 13 T14N R8EUM ASP Zone 4 NAD 27 Coordinates Measured Depth, RKB: 13610' Northing:6058429.60' Easting: 504168.90 Total Vertical Depth, RKB: 3748' Total Vertical Depth, SS: 3801' , Please see Attachment 7:Surface Platt and (D)other information required by 20 MC 25.050(b); Requirements of 20 MC 25050(b) If a well is to be intentionally deviated, the application for a Permit to Drill(Form 10-401)must (1)include a plat, drawn to a suitable scale,showing the path of the proposed wellbore,including all adjacent wellbores within 200 feet of any portion of the proposed well; Please see Attachment 1: Directional Plan and (2)for all wells within 200 feet of the proposed wellbore AOGCC PERMIT Document.doc Page 3 of 9 Printed:9-Sep-11 *411.' .111. • Enii c Lr`! eum Application for Permit to Drill Saved:9-Sep-11 (A)list the names of the operators of those wells, to the extent that those names are known or discoverable in public records, and show that each named operator has been furnished a copy of the application by certified mail;or (B)state that the applicant is the only affected owner. The Applicant is the only affected owner. 3. Blowout Prevention Equipment Information Requirements of 20 MC 25.005(c)(3) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (3)a diagram and description of the blowout prevention equipment(BOPE)as required by 20 MC 25.035,20 MC 25.036, or 20 MC 25.037, as applicable; Please see Attachment 3: BOP and Diverter Configuration 4. Drilling Hazards Information Requirements of 20 MC 25.005(c)(4) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (4)information on drilling hazards,including (A)the maximum downhole pressure that may be encountered, criteria used to determine it, and maximum potential surface pressure based on a methane gradient; The expected reservoir pressure in the Schrader Bluff sand is 0.45 psi/ft, or 8.6 ppg EMW (equivalent mud weight). The maximum potential surface pressure (MPSP) based on the above maximum pressure gradient, a methane gradient(0.11), and the planned vertical depth of the OA sand formation is: MPSP = (3946'TVD)(0.45 - 0.11 psi/ft) = 1342 psi (B)data on potential gas zones; The well bore is not expected to penetrate any gas zones. and (C)data concerning potential causes of hole problems such as abnormally geo-pressured strata, lost circulation zones, and zones that have a propensity for differential sticking; Please see Attachment 2: Drilling Hazards Summary. 5. Procedure for Conducting Formation Integrity Tests Requirements of 20 MC 25 005(c)(5) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (5)a description of the procedure for conducting formation integrity tests, as required under 20 MC 25.030(1); Please see Attachment 6: Formation Integrity And Leak Off Test Procedure AOGCC PERMIT Document.doc Page 4 of 9 Printed:9-Sep-11 • Chi • ` eum _ent Application for Permit to Drill Saved:9-Sep-11 6. Casing and Cementing Program Requirements of 20 MC 25.005(c)(6) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (6)a complete proposed casing and cementing program as required by 20 MC 25.030, and a description of any slotted liner,pre- perforated liner, or screen to be installed; Casing and Cementing Program See also Attachment 4: Cement Summary Hole Casing Weight Grade Coupling Length MD ND MD TVD (including stage data) Driven 20" 178.89 X-65 Welded 124 36 36 160 160 pre-installed 16" 13-3/8" 68 L-80 BTC 2249 35 35 2284 2173 1033 sx 10.7#ASL,240 sx 12.5# Deeperete 12.25" 9-5/8" 40 L-80 Hydril 563 6025 33 33 6058 3958 665 sx 12.5#Deeperete 5858 8.75" 5.5" 15.5 L-80 Hydril 521 7752 3958 13610 3801 uncemented liner in open hole 7. Diverter System Information Requirements of 20 MC 25.005(c)(7) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (7)a diagram and description of the diverter system as required by 20 MC 25.035, unless this requirement is waived by the commission under 20 MC 25.035(h)(2); Please see Attachment 3: BOP Configuration. 76, 7•L/•f1 - - - = - waive •iv- - -". .• - .. . - .1 . . 5, TA-4...ft rs /)4✓�0►4--ey AOGCC PERMIT Document.doc Page 5 of 9 Printed:9-Sep-11 lot4,... • Eno elL= tir * Ileum _em. Application for Permit to Drill Saved:9-Sep-11 Drilling Fluid Program Requirements of 20 MC 25.005(c)(8) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (8)a drilling fluid program,including a diagram and description of the drilling fluid system, as required by 20 AAC 25.033; Drilling will be done with muds having the following properties over the listed intervals: Surface Hole Mud Program (extended bentonite) Spud to Base of Permafrost Base of Permafrost to Casing Point Initial Value l Final Value Initial Value Final Value Density(ppg) 8.8 9.2 9.2 9.5 Funnel Viscosity 150 250 200 300 (seconds) Yield Point 50 70 30 50 (lb/100 sO Plastic Viscostiy 30 55 15 20 (CP) pH 9.0 9.5 9.0 9.5 API Filtrate NC 8.0 8.0 8.0 (cc/30 min)) Intermediate Hole Mud Program Lateral Mud Program (LSND) (MI FazePro Mineral Oil Base) b 8M 13-3/8"Csg Shoe to 9-5/8"Csg Point Value Value Density(ppg) 9.4 _ Density(ppg) 8.8 - 9.5 J Plastic Viscostiy 15 - 25 Funnel Viscosity 45 - 60 (CP) (seconds) Yield Point 15 - 20 Plastic Viscostiy 12 - 18 (lb/100 sf) (CP) HTHP Fluid loss Yield Point 18-24 (ml/30 min c <5.0 (lb/100 st) 200psi& 100°F API Filtrate4 - 6 Oil/Water 60/ 40 (cc/30 min)) Ratio Chlorides(mg/I) <500 Electrical >600 pH 9.0- 10.0 Stability MBT <18.0 Drilling fluid practices will be in accordance with appropriate regulations stated in 20 MC 25.033. 8. Abnormally Pressured Formation Information Requirements of 20 MC 25 005(c)(9) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (9)for an exploratory or stratigraphic test well, a tabulation setting out the depths of predicted abnormally geo-pressured strata as required by 20 AAC 25.033(f) AOGCC PERMIT Document.doc Page 6 of 9 Printed:9-Sep-11 root Eni :triIeu _em Application for Permit to Drill Saved:9-Sep-11 Not applicable: Application is not for an exploratory or stratigraphic test well. 9. Seismic Analysis Requirements of 20 AAC 25.005(c)(10) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (10)for an exploratory or stratigraphic test well,a seismic refraction or reflection analysis as required by 20 MC 25.061(a); Not applicable: Application is not for an exploratory or stratigraphic test well. 10. Seabed Condition Analysis Requirements of 20 AAC 25.005(c)(11) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (11)for a well drilled from an offshore platform,mobile bottom-founded structure,jack-up rig, or floating drilling vessel,an analysis of seabed conditions as required by 20 MC 25.061(6); Not applicable: Application is not for an offshore well. nn (r v,/di 3O4. o skO,C 11. Evidence of Bonding7.244 Requirements of 20 AAC 25.005(c)(12) 7 An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (12)evidence showing that the requirements of 20 AAC 25.025{Bonding}have been met; Evidence of bonding for ENI is on file with the Commission. 12. Proposed Drilling Program Requirements of 20 AAC 25.005(c)(13) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: The proposed drilling program is listed below. Please refer also to Attachment 5, Well Schematic. 1. Move in / rig up Doyon 15. 2. Rig up Diverter and test , 3. Spud and directionally drill 16" hole to casing point as per directional plan. Run Gyro and MWD tools as required for directional monitoring. 4. Run and cement 13-3/8", 68#, L80, BTC casing to surface. Pump cement and displace with mud, land casing hanger and bump plug. 5. Install and test wellhead to 5000 PSI. 6. Nipple up 13-5/8"5K BOP and test to 3500 PSI. Notify AOGCC 24 hrs before test. ' 7. Pressure test casing to 2500 psi per AOGCC regulations. Record results. . 8. PU 12-1/4"bit and directional drilling assembly with MWD, LWD and PWD. - f IT. 9. Drill out cement and between 20'and 50' of new hole. Perform formation integrity test, recording results. 10. Directionally drill to 9-5/8"casing point per directional plan. Pull out of hole backreaming to the surface casing shoe. 11. Install 9-5/8"casing rams in the BOP and test to 3500 PSI. - AOGCC PERMIT Document.doc Page 7 of 9 Printed:9-Sep-11 Enii :tFi :' UT Application for Permit to Drill Saved:9-Sep-11 12. RU casing drive system. 13. Run 9-5/8", 40# L80, Hydril 563 casing to setting depth. Pump cement and displace with mud. Bump plug with casing on depth. 14. Install 9-5/8"Emergency Slips. 15. Install 9-5/8" packoff and test to 5000 psi. 16. Flush 13-3/8"x 9-5/8"annulus with diesel freeze protect. 17. Pressure test casing to 3000 psi per AOGCC regulations. Record results. 18. PU 8-3/4" bit and directional drilling assembly including MWD, LWD, PWD and rotary steerable tool. RIH, clean out cement to top of float equipment. 19. Drill out cement and between 20'and 50' of new hole. Perform formation integrity test, recording . results. 20. Directionally drill 8-3/4" hole to TD as per directional plan. Pull out of hole backreaming to casing shoe: 21. PU and run 5-1/2"slotted liner to TD. 22. Land liner, set liner hanger with 200' Liner lap inside the 9-5/8"intermediate casing. POOH laying down DP as required. 23. PU ESP completion as required and RIH to depth. Land tubing. Set BPV 24. Nipple down BOP, nipple up tree and test. Pull BPV. • ENI requests that the AOGCC waive surface safety valve requirements per 20 AAC 25.265. (c). (1). 6K • The Vetco horizontal wellhead utilized physically prevents locating the SSV in the vertical run of the tree as there is no vertical tree on this wellhead. • Wellhead schematics should be on file with the AOGCC. 25. Freeze protect well with diesel by pumping into 4-1/2"x 9-5/8"annulus, taking returns from tubing. 26. Move rig off. 13. Discussion of Mud and Cuttings Disposal and Annular Disposal Requirements of 20 AAC 25.005(c)(14) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (14)a general description of how the operator plans to dispose of drilling mud and cuttings and a statement of whether the operator intends to request authorization under 20 AAC 25.080 for an annular disposal operation in the well.; Waste fluids generated during the drilling process will be disposed of by injection down an Oliktok Point Class I disposal well or by hauling the fluids to the Prudhoe Bay Grind and Inject Facility. All cuttings generated will be disposed of either down an Oliktok Point Class I grind and inject disposal well or hauled' to the Prudhoe Bay Grind and Inject Facility for temporary storage and eventual processing for injection down an approved disposal well. 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O 223;27 M NidN N0a2 mg'42-,22 M m m 0 h d M N N �m 0 no 0 0 0 0 0 pphMdOm O r -12; r3 8,%g22 .°224:2P- 4- 0 MO V4,000 QQOa*bMN 2380 r00x00 mb04m22t;82!0Ni Tmd NN 000100 000180M M000 2E8 82888 000 0 00 0 0 0 0 0 m O ;:88'.48 N000M 0 g O N 28888 88888 b0Om 0OOO7 881288 01-Om m'0(N MIRO O a p 0 0 0 0 0 0 0 0 Mil 0*00 n m 0 Hill a 0 0 0 0 0 p O O O N O OC O i V m b 0 O r O O O ee��O r 0 0 O O O O M O N O M O mmN M b O N d �N N M R N m M A N O O m m O N N M N d m m 1D 4,D O O ::: Mdddd dddd< QaN hm ipmmmb bbbbip bbrrr mmmmOOc0O>ONd? aUG m CyF-— m N d Oj 2 10 :2 02� rnOUP10M NU ryMUN O Cl �- m 0(¢i¢ 2 2 0 2 zv 2 i v 2i9 2 V > J 0) 2 Z 2 W 2 0;0 01 U U W U COW U N W 001110 M O Oe O 22282 MOOb 128:24'8 OuiO W O d O orW W 22228 Ommd p� tph V Op MO 0OINmN g284'.3 n r 0 M H� N WNMON 8,7,'"g2 ni1 :22 42P.nn 422'42D mMN ONOrb MANN' 'NM O wron roErr 'HRH 'inn EMI 00000 000 000 0 '' 001 d b b b N N N N N W b W m b b In b b m W W W uI W m b b b b m W W b b b b b a M M...... 0 0 d b 0 N 0,4.0.1.0 b O O d 0 M W O Q r,- O O N rWN O W WNlQ0•rtM-O N N bb O N Q M NNP Ob b r 0 2; ymmNO 0dNb MOOd0 WWO NMNO OMW MmWW MWW bNW N Z WNNNNNN hNNWbN NbNMb bWbWb 'MI5 nnnr Hili md e;N N Y go ro 22,742 bMNN OW NN n i2,32222 7 2 7 NW '42'2.°3n ;'.-3,';44 d g 2 P Q N NN O ro ro 00 NC m 8122% 22222 222c%,% 22222 22222W m W W 2 m m m m m 22222 W W W C O W NY C O o C O Y 7a W 70 ! !!n! n"19! nWH W co W w Wen Wtcmao o M w!W rW m W o ,FH Y r Al 0 J K O 88888 SSSSO 88888 88888 OOOO OOOOO 88888 0000 O O O N O 88888 OOOO 000 08N NONNV NGCVG NNV NNNV0 NNONN NNONN NONV 004040101 04040 F ,„ 222222 KN Nm 22922 iQI iL'EK SJJKbJ b KNm n11Kmn mJ= 'VJJb KKK Kb Y 0) NN X ONO l") M MMM p NN.-.- NO O O O rn 000 W^ 00000 O 222222 M MM d m bdMd WC.-d2 W0b 0 M .t- ,-.t n=oOvV N 2:=2202 b:2lNWV W0)MbD DeW' mv<O W NOf N ONpp V 24'2;4' 4b NW e;W 1.cI O2 N N n M,+,o1022,,t221WW O4>bP2'42.1 rN0 O0 20 N MO W Nd 1N222 .V , MrdOi -N,2unDA4MQ eOrWM NONb OoNnV .7'1°51 2 go Qggq yoqn nnoub vvvvu '.'4T. bio iq u?iq )grnrr ' 'NI N a N m M 7 2,2'g-7; 0 O n W n 1 2,181'6- N m m n n b M�p O ,7 O a n ti ro O 00 O Z Z 2.'1;R:1'53 O O N b I d OI d O b O O N d M O m n O b 0 r O V b b A O M 1� m n�lV m n7 MIH O to <V n M Yi N W�b m N(V n� �O m Oi lV O Oi Oi C 'O h b S N O O N N N m M N I N n W d t0 M n N O n p W W d d i-N N N t0 W W N N N M b b W i0� O N M M d n r 0 O O d d d N ,‘1,,c‘ M N d �- N N N N N N N N N N N M MMM M M MMM M M d d d d d d d d d P L W O d N =N O O ZiObb C N tO OWi N rN Nb °)cdDb rN OO �'nN nON MOW m NO MCd,In o• OQ�QO(, l IO t0 m M m MEI N lV M Oi Q of t0 N m 0))p O M Yi MOP W M 0)C Oi ,O to <lV (V .,.,,,7,707,§ o 0• X� d `I �vI M n 5 M NfOP M oOP W m0 W mn W o ro+d d M N d N N M N n Wn m m 2ND m b M N O MddP V d dPP bYlbb MI5 bN W�Otp iOtOrnr nn n� m m r 333�3p u j4,'1(711731 mmmmmEi I N b b b m 2 N C O m O N 1f N W Yni�C IW m N d 0 WN NW CWN W n W „;.—,-0mO m ,..--<,,, N m bN<,MW c.W v I Wb W bWbWN ' Oro W M, -NN VOMMM 10mb- Mb 2ND 0 E b r o N N N N M d N b M b n N N Q b M W o o O'”0 0 0 0 0 0 b Ip n W OrN r m W�m M�raN OIh W � b 0)0 b �X000000 O W lV N N fV lV O t0 � N O b n 1� Cl G Oi,n i[i tD n n� n y 0 0 0 0 0 0 � W W W m ro W M� �000 W r b,O tp EI iOO W LL C O C C G C F M MMM MM M MMM M MM M MM M MM MMI C M tnnM M MMMMM MM tn]M M MIR M nCr1 Cr'f 7 000000 ` Q W m J W Y WO hbWNm (0 U go g§F0SV0 ZEE W W ~ M M MMM o 0C 0000 ~ZZ N bbb M M MMM M M MMM M M MMM M M MMM M M MMM M M MMM M M MMM M M M M N M,O W Q I5,71': O r12.°2:2 O M r Nn NWJ 76'.1-- 2 WWbOOiiOOd r m" . ,P6.'8O WWO WM0N W2 2 8 2 WmOm '03 ',L.' 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N T T'""7 i T 7 7''�/_ 'T• ii•••'OM N 3 1 I 1 N 1 1 1 5 !hi;1 11 W 1 1 1 N 1 1 15 t1 1 1 1 N 1 1 I00 .11 11 = C _ 1 I 1 ii i i i V ii 11 :ZZ O T i i n i g ii Iii N1 N i i i• ;! ;CD i i W ii to In _ 00 i i i i i i is g: iil ii g O to cn p T T'""T i T T 414"i1"71'7'r OO SS N 1 1 1 i i 1 1•5 t 11• w ID N 8 1 1 I 11 1 1 1 111 M F E s 1 1 1 11 1 1 I• 1111 1 $ co " i i i 11 i i ; iiii t q N — 1 I I 11 1 1 l epp ... V n 1 1 1 11 1 1 1 ,F1 p 1111 o II 1 I 1 11 I 1 1 p iiii V C •n O I 1 1 II 1 I I a g 11111 W p °pp W i i'""7 ■ T 7 7 It TIT 1`. W 0 o V i i i A i i •i is i i i i g fr V $;= i i i i i i i Z 1 g i i i i i i ; i iiiii u y O F i i i M i N i i r .. s 0.1111 V e- H ii1 1 1 1 1 1 f 01111 1 W V l lSI C ii 7 1 1 1 1 1 1 1 t l l 11 I .19 2 1 1 1 ■ 1 1 1 p 11 111 1 I I ' n�n C:1111 y a ii§:i O 1 1 1 ■ 1 1 I a()1�1111 g H p g'�^ T i'•'"7 1 1 7 T 'Ei i4;. 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Ila a P Y U i i i o ii g i SI i i i ' iia a M 6 i il i if.) i V ig V a i ';11 i:p Z 0 ... ;...�....ia.k t ips .iiii i" O 1 i/ ., i i22 fA ♦ :J' 1111 ilio M y N i i 1 1• W u 1" 1111 I la CO, eR i i i ' �,.. i :: iiii id t1 1 1 N YI 1g1 1 11111° I I 1 11 1 1 11111 Y 1 1 I II 1 1 1 11111¢ s,4 i i 1 1 1 ■ 1 1 1 111111 1 ; ; i i ; 1 ;iiiii S S 0 S N N M • I (u)OOzOu!)I.=aleos o/LL vot en II Schlumberger WELL FI SP23-N3 (P3) "D Nikaitchuq S RDD URE Spy Island Magnate Parameters Sudo.Location 01A1227 Alaska State Nana,Zone 04,US Feet MlauIbuous Modal: BGGM 2011 Dip 81079' 0.b: May 15,2012 Ld'. N 703327.880 Northing'. 8053831.53RUS Grid Com:009921902' Slot'. SP23 TVD Ret'. Rotary Table(53.45 above MSL) Mag Dec. 2.543' FS: 57647 257 Lon-. W 149 5019.389 Easing: 511535132 RUS Scale Fad:099880015 Plan: SP23-N3(P3) Sr 5 Data.0092011,2011 -7500 -6000 -4500 -3000 -1500 0 6000 .N' 6000 SP23-N3(P3) TD 4500 End CIVEnd Civ 4500 SI-N3 Tgt 13 SI-N3 Tgt 14 Cry 2/100 Cry 21100 End Cry Ertl Cry SI-N3 Tgt 11 Cry 2/100 SI-N3 Tgt 12 Cry 2/100 3000 End Cry 3000 A End Cry Tg(S A SI-N3 Tgt 10 Cry 2/100 I Z Cry Q/100 End Cry C_ End Cry SINS Tgt 7 SI-313 Tgt 8 Cry 2/100 p End CryCry2/100 SI-N3 Tgt 6 5 1500 Cry 21100 1500 ii - End Cryo. N End Cry SI-N3 Tgt 4 Tar U SI-N3 Tgt 6 �'2/100 U) Civ 2/100 U) End Cry V End Cry SI-N3 Tgt 2 RTE V SI-N3 Tgt 3 Cry 2/100 KOP Cry 1.6/100 Cm 2/100 Cry 1.76/100 0 End Cry Cry 0.6/100 • Cry 2.6/100 e 4 Cry 4.4/100 Cry 2.6/100 13-3/8"Cl g 94/3"Csg End Cry SI-N3 heel Cry 4.4/100 End Cry -1500 -1500 -3000 -3000 I 1 -7500 -6000 -4500 -3000 -1500 0 «< W Scale=1(in):1500(ft) E >>> klimierver SP23-N3 (P3) Anti-Collision Summary Report Analysis Date-24hr Time: August 24,2011-14:32 Analysis Method: Normal Plane Client: Eni Petroleum Reference Trajectory: SP23-N3(P3)(Def Plan) Field: Nikaitchuq Depth Interval: Every 5.00 Measured Depth(ft) Structure: Spy Island Rule Set: D&M AntiCollision Standard S002 v5.1 Slot: SP23 Min Pts: All local minima indicated. Well: SP23-N3 Borehole: SP23-N3 Offset Trajectories Summary Offset Selection Criteria Wellhead distance scan: Not performed! Selection filters: Definitive Surveys-Definitive Plans-Definitive surveys exclude definitive plans -All Non-Def Surveys when no Def-Survey is set in a borehole-All Non-Def Plans when no Def-Plan is set in a borehole Offset Trajectory Separation Allow Sep. Reference Trajectory Separation Factor Alert Status Ct-Ct(ft)I EOU(ft) Dev.(ft) Fact. MD(ft) I TVD(ft) Alert I Minor I Major SP22-FN1(P2)(Def Plan) Warning Alert 8.09 6.87 1.37 5.61 0.00 0.00 CtCt<=15m<15.00 Enter Alert 7.04 4.63 0.32 2.42 329.90 329.87 MinPts 7.05 4.62 0.33 2.40 334.88 334.85 MinPt-O-EOU 7.15 4.66 0.43 Ellal 344.83 344.80 MinPt-0SF 48.50 44.41 41.78 11.56 583.27 582.49 CtCt<=15m>15.00 Exit Alert 2601.59 2569.84 2554 84.521 4479.62 3642.85 MinPt-0SF 2585.9 2554.801 2539.74 85.87 4640.03 3716.69 MinPts 1 2585.95 255480 2539.76 85.93 4645.08 3718.83 MinPt-CtCt 2348.96 2306.60 2285.9.,MOE 6077.01 3958.91 MinPt-O-SF 1 785.981 703.43 66264 9.62 11093.40 3833.16 MinPt-CtCt 795.20"11 694.371 644.40 7.95 1135658 3824.53 MinPt-0-EOU 806.82 696.5 641.9 7.38 11488.17 3820.22 MinPt-O-ADP 1031.31 866.85 785.11 6.301 12462.74 3834.37 MinPt-OSF 1401.83 1193.12 1089.26 6.74 13609.59 3801.20 - TD 11049.54 11018.96 11004.1 ® 3053.67 270329 MinPt-0SF 14480.14 14440.45 14421.1.MIME 3123.29 2751.66 MinPt-OSF SP24SE1(P2)(Def Plan) Warning Alert 7.95 6.72 1.34 5.49 0.00 0.00 CtCt<=15m<15.00 Enter Alert 7.95 5.93 1.34 3.33 200.00 200.00 MinPts 796 5.92 136 3.30 210.00 210.00 MinPt-O-EOU 8.06 5.97 1.46® 229.99 229.99 MinPt-0-SF 48.53 4471 41.93 12.37 534.54 534.03 CtCt<=15m>15.00 Exit Alert 2861.86 2830.58 2815.45 94.671 4448.34 362721 MinP1-0-SF 2831.59 2801.61 27872 98.11 4687.56 3736.42 MinPt-0-ADP 2831.54 280165 2787.24 98.20 4691.91 3738.17 MinPt-O-EOU 2831.51 2801.68 2787.30 98.40 4700.60 3741.66 MinPt-CtC1 2644.07 2605.721 2587.081 70.901 6040.20 3955,70 MinPts 157253 1527.11 1504.89 35.37 7050.78 393318 TD 528.26 500.74 10.60 461968 3707.93 MinPt-CtCt 585.26 II1B38hSE 498.69 10.24 4680.56 3733.58 MinPI-0-EOU 586.56 5274:MIKE10.08 4714.55 3747.17 MinPt-O-ADP 1 591.921 527.63 495.98 9.33 5685.80 3924.81 MinPt-CtCt 5919'•'71 527.61 495.95 9.33 5695.53 3925.66 MinPt-O-EOU 591.95 527.6 495. 9.33 5700.38 3926.08 MInPt-O-ADP 592.73 52825 496.5 9.32 5753.60 3930.72 MinPt-0-SF SI17SE2(P2)(Def Plan) Warning Alert 56.09 5487 23.28 44.83 0.00 0.00 Surface 4921 46.41 16.40 17.12 439.06 438.88 CtCt<=15m<15.00 Enter Alert 47.99 44.81 15.18 14.74 487.69 487.37 MinPts 48.02 44.77 15.22 14.39 497.33 496.98 MinPt-O-EOU 48.96 45.48 16.15 13.73 526.07 525.60 CtCt<=15m>15.00 Exit Alert 51.38 4766 18.57 13.48 554.49 553.88 MinPt-O-SF 2283.91 2271.23 2251.11 179.97 1917.66 1854.98 MinPt-OSF 2458.54 244403 2425.73 169.29 2281.34 217147 MinPt-0SF 2193.33 2172.08 2160.53 103.16 2880.23 2586.31 MinPt-OSF 2860.17 2828.78' 2813.62 94.28 4662.84 3726.29 MinPts 2859.93 2828.6 2813.611 94.76 4720.88 3749.64 MinPts 1 2859.90 2828.71 2813.65 94.91 4727.97 3752.39 MinPl-CtCI 2667.69 2626.02 2605.72 6561 6057.04 3957.17 MinPts I 1947.46 1897.07 1872.37 39.40 6892.43 3936.88 TD 1569.0. 1526.32 1505.43 37.54 3467.48 2996.98 MinPt-CtCt 1569.Or MEM MEM 37.53 3468.60 2997.78 MinPts 1574.18 1531.17 1510.16 MEM, 3500.07 3020.35 MinPt-O-SF 1670.83 1625.04 1602.6, alEfi 3769.32 3210.78 MinPt-OSF 1654.17 1593.04 1562.x•11111111111ME 6078.19 3959.01 MinPt-O-SF 1649.16 15862:;IMMIE 27.98 6257.46 3967.80 MinPt-O-ADP 1649.0 1559.84 28.02 6268.08 3967.90 MInPt-0-EOU �'°°1 1589.34 1560.02 28.10 6294.62 3967.92 MinPt-CtCt 5120-N4(P4)(Def Plan) Warning Alert 24.02 2280 4.56 18.63 0.00 0.00 CtCt<=15m<15.00 Enter Alert 24.02 21.99 4.56 11.19 200.00 200.00 MinPts 2403 2198 456 11.17 215.02 215.02 MinPt-O-EOU 24.14 22.07 46 Mr y 300.10 300.09 MinPt-0SF 49.14 39.80 29.68 5.13 1328.08 1306.72 CtCt<=15m>15.00 Exit Alert 51.97 42.05 32.51 5.111 1383.42 1358.73 MinPt-O-SF ENEEM 46401 42.89 4.72 1879.04 1819.42 MinPts 62.39 49.01 42.93 4.571 1922.67 1859.58 MinPt-0-SF 62.47 48.99 42.86 5.00 1933.41 1869.45 OSF<5.00 Enter Alert Drilling Office 2.0.960.0 Nikaitchuq\Spy Island\SP23-N3\SP23-N3\SP23-N3(P3) 8/24/2011 2:33 PM Page 1 of 13 Offset Trajectory Separation Allow Sep. Reference Trajectory Separation Factor Alert Status Ct-Ct(ft)I EOU(ft) Dev.(ft), Fact. MD(ft) I TVD(ft) Alert I Minor I Major 62.58 4901 42.84 4.97 1943.09 1878.30 MinPt-O-ADP 6359 49.70 43.36 4.921 198156 1913.31 MinPt-0SF 6546 51.36 44.91 4.99 2014.85 1943.30 OSF>5.00 Exit Alert 107.04 93.68 87.5:6 2198.77 2103.34 MinPt-0-SF 627.86 615.93 608.4. EllE 2626.40 2424.10 MinPt-O-SF 1206.11 1003.30 902.38 5.97 13609.59 3801.20 TD 8284.02 826345 8253.66=EKE 1364.41 1340.90 MinPt-0-SF 7340.50 7321.18 731201 NI= 1552.69 1516.95 MinPt-O-SF 687023 6851.50 6842.6 man 1659.01 1615.88 MinPt-0SF 6405.38 6387.19 63786.�..' 177667 1724.92 MinPt-O-SF 2538.83 2524.26 2517.4 I3Ll''l 2620.43 2420.24 MinPt-0-SF 2063.98 2049.26 2042.3'MIME 2853.02 2568.52 MinPt-O-SF 2075.73 2060.94 2054.0 MERU 2864.98 2576.32 MinPt-O-SF 2565.29 2548.03 2539.8'=ME 3078.56 2720.50 MinPt-O-SF 8615.94 8590.84 8578.7 1111112RE 3314.62 2887.43 MinPt-0-SF S120-N4PB1(P1)(Def Plan) Warning Alert 24.02 22.80 456 1863 0,00 0.00 CtCt<=15m<15.00 Enter Alert 24.02 21.99 4,58 11.19 200.00 200.00 MinPts 24.03 21.98 456 11.17 215.02 215.02 MinPt-O-EOU 24.14 22.07 4.6 mum300.10 300.09 MinPt-0-SF 49.14 39.81 2968 5.13 1328.08 1306.72 CtCt<=15m>15.00 Exit Alert 51.97 42.05 32.51 5.121 138342 1358.73 MinPt-0SF MEM 49.34 4289 4.72 1879.04 1819.42 MinPts 6238 4962 42.91 4581 1918.86 1856.09 MinPt-0-SF 62.4 48.98 42.85 4.99 193341 1869.45 OSF<5.00 Enter Alert 62.58 49.01 42.8 4.97 1943.09 1878.30 MinPt-O-ADP 63.59 49.69 43.3 4.921 1981.56 1913.31 MinPt-0-SF 65.46 51.35 44.90 498 2014.85 1943.30 OSF>5.00 Exit Alert 107.04 93.67 87.5+MIMI 2198.77 2103.34 MinPt-0SF 1519.82 1502.25 1493.96 91.57 3909.91 330653 TD SP27-N1(P3)(Def Plan) Warning Alert 47.07 45.85 14.26 37.46 0.00 0.00 CtCt<=15m<15.00 Enter Alert 47.07 45.04 14.26 2250 200.00 200.00 MinPts 47.0 45.03 14.27 2245 224.95 224.95 MinPt43-EOU 47.12 45.06 14.31 MEE1EE 299.81 299.80 MinPt-0SF 49.20 44.12 16.39 9.46 888.88 884.12 CtCt<=15m>15.00 Exit Alen 4959=Miln 16.78 8.81 933.88 928.10 MinP1-0-EOU 77.07 61.71 44.261111=0 1936.39 1872.17 MinPt-O-SF 77.33 60.87 4453 4.62 2117.32 2033.76 OSF<5.00 Enter Alert 73.31 54.72 40.5.Miii 2280.08 2170.45 MinPt-O-SF 72.94 53.96 40.1 2311.14 2195.41 MinPt-0-SF 7291 53.8 40.1. 3.77 2321.45 220361 MinPts 731 53.5 40.33 3.68 2352.26 2227.85 MinPt-0-EOU 7467 54,33 41.86 EIDS 2398.08 2263.13 MinPt-0SF 104.60 82.81 71.80 4.75 2590.12 2400.30 OSF>5.00 Exit Alert 515.41 493.23 482.61 MEE 4520,57 3682.73 MinPt-0-SF 793.21 761.81 746.61 5110.32 3864.04 MinPt-O-SF 1779.31 1723.29 1695.7 ® 6059.11 3957.35 MinPt-0-SF 1987.65 1926.39 1896.2 =Ea 6529.48 3955.05 MinPt-0SF 2097.74 2030.31 1997.09 31.55 7024.86 3933.79 MinPt-0-EOU 2098.12 2030.39 1997.021 31.42 7038.22 393347 MinPt-0-ADP 2164.511 2082.48 2041.96 26.70 8046.74 3941.98 MinPt-O-EOU 2164.77 2082.53 2041.901 2663 8066.57 3942.52 MinPt-O-ADP I 2394.94 2206.61 211294 12.78 13434.38 382431 TD 8771.42 8715.00 8687.2'�'' �. 1715.64 1668.41 MinPt-0SF 8663.95 8608.20 8580.8•'. r'1 1747.68 1698.09 MinPt-0SF 8591.04 8535.75 8508.5'=IIME 1769.69 1718.46 MinPt-0SF 8531.10 8476.18 8449. •=EIE 1787.95 1735.35 MinPt-0SF 8428.18 8373,91 8347.2 =EMI 1818.61 1763.68 MinPt-0SF 8406.62 8352.48 8325.91 MEM 1824.67 1769.27 MinPt-O-SF 8372.11 8318,20 8291,7 =En 183430 1778.16 MinPt-O-SF 8311.81 8258.28 8232.01 11MIME 1851.24 1793.80 MinPt-O-SF 8093.13 8039.35 8012.9 =HE 2485.55 2327.85 MinPt-O-SF SI19FN2(P2)(Det Plan) Warning Alert 32.06 30.83 6.17 2519 0.00 0.00 CtCt<=15m<15.00 Enter Alert 27.63 2486 1,74 9.53 434.09 433.92 MinPts 27.64 24.83 1 75 9.40 439.00 438.82 MinPt-O-EOU 29.91 26.62 4.0•EMU 492.68 492.34 MinPt-0-SF 48.83 44.72 22.94 11.56 597.66 596.78 CtCt<=15m>15.00 Exit Alert 2663.60 2631.51 2616.0 85. 4520.34 3662.62 MinPt-0-SF 2641.711 2 2610.391 2595.2 87.24 4700.18 3741.49 MinPts 1 2641.711 2610.40 259527 87.31 4704.95 374338 MinPl-CtCt 2424.24 2380.79 2359.5 57.06 6076.89 3958.90 MinPt-0SF 453.87 381.77 346.21 637 12056.93 3831,41 MinPt-O-SF 345.82 275.73 241.17 4.99 12600.59 3835.22 OSF<5.00 Enter Alert 313.4 192.74 132.88 2.61 13051.31 3843.21 MinPt-CtCt 331. 137.5 41.04 1.71 13548.82 3809.39 MinPt-0{OU ! 339.55 139 39.281 1.70 13608.19 3801.39 MinPt-O-ADP I 339.77 139.11 39.28 1.70 13609.59 3801.20 OSF>5.00 Exit Alert 19490.34 19456.90 19440.6: 600.5 815.55 812.18 MinPt-O-SF 11594.54 11576.96 115686 =MEW 1162.20 1149.01 MinPt-O-SF 10838.22 10808.74 10794.4•MIMI 3170.05 2784.50 MinPt-O-SF SP16-FN3(P2)(Def Plan) Warning Alert 64.02 62.79 31.21 51.30 0.00 0.00 Surface 56.68 53.46 23.87 17.25 502.70 502.33 MinPts 56.70 53.45 23.89 17.09 507.54 507.15 MinPt-O-EOU 61.64 57.81 28.84® 588.61 587.79 MinPt-O-SF 10833.92 10805.00 10791.. MAI 3280.35 2862.79 MinPt-O-SF Drilling Office 2.0.960.0 Nikaitchuq\Spy Island\SP23-N3\SP23-N3\SP23-N3(P3) 8/24/2011 2:33 PM Page 2 of 13 Offset Trajectory Separation Allow Sep. Reference Trajectory Separation Factor Alert Status Cl-Ct(ft)I EOU(ft) Dev.(ft) Fact. MD(ft) I TVD(ft) Alert I Minor I Major 2755.24 2722.92 2707.29 88.12 4585.35 3692.75 MinPt-O-SF 2726.50 2694. 2679.72 89.43 4776.99 3770.74 MinPt-O-ADP I 2726.481 2894.9 2679.73 89.49 4781.37 3772.32 MinPts 2535.74 2490.84 2468.8'MOE 6083.06 3959.43 MinPt-O-SF 955.64 763.56 668.01 5.00 13021.09 3842.68 OSF<5.00 Enter Alert 854.99 643.99 538.98 4.07 13609.59 3801.20 OSF>5.00 Exit Alen SI25-N2(P2)(Def Plan) Warning Alert 31 06 29.83 5.97 24.37 0.00 0.00 CtCt<=15m<15.00 Enter Alen 31.01 28.95 5.92r14. 299.87 299.86 MinPts I 30.02 27.45 4.93 11.19 519.55 519.10 MinPts 30.11 27.36 5.02 10.51 549.50 548.92 • MinPt-O-EOU 31.97 28.76 6.8:Imo' '•-' 644.36 643.12 MinPt-O-SF 48.63 44.48 23.54 11.42 844.05 840.17 CtCt<=15m>15.00 Exit Alen 440.04 426.92 414.9 .1111EEIE 2166.04 2075.65 MinPt-0SF 451.78 438.30 426.6'MIKE 2226.96 2126.88 MinP1-0SF 460.55 446.78 435. •mEEE 2283.38 2173.12 MinPt-O-SF 469.31 452.26 444. M.: 2661.73 2448.64 MinPt-O-SF 276.6 249.18 235.94 10.41 4023.47 3381.00 MinPt-CtCt 276. 248.82 235.24 10.16 4061.07 3404.99 MinPt-O-EOU 277.33 248.891 235.16 10.06 4077.81 3415.55 MinPt-O-ADP 291.12 259.76 244.57 9.55 4263.01 3527.04 MinPt-O-SF 1089.34 1015.50 979.0 MUM 6688.10 3942.59 MinPt-O-SF 1147.34 1062.41 1020.' 13.•• 7276.66 3927.93 MinPt-OSF 1086.38 887.19 788.09 5.48 13466.97 3820.35 TD SP18-N5(P3)(Def Plan) Warning Alert 48.05 46.83 15.24 38.26 0.00 0.00 CtCt<=15m<15.00 Enter Alen I 48.0 45.991 15.24122.731 300.20 300.19 MinPts 48.2 46.4 15,48 15.46 26.13 440.54 440.36 MinPt-O-EOU 49.16 48.73 16.35 19.75 555.86 555.24 CtCt<=15m>15.00 Exit Alert 80.12 7313 47.311'16 1093.60 1083.07 MinPt-0SF 83.84 76.51 51.03 IIIMEME 1128.88 1117.03 MinPt-O-SF 259.48 240.39 226.6 jrn 2257.94 2152.42 MinPt-O-SF 5210.54 5177.00 5160.7 160.0. 3579.61 3077.23 MinPt-O-SF 2412.66 2186.44 2073.82 10.71 13609.59 3801.20 TD 4874.40 4847.63 4834.7.=EU 2020.66 1948.52 MinPt-O-SF 1006 26.11KM MN=11M113. 2688.20 2463.43 MinPts SI29-52(P2)(Def Plan) Pass 63.09 61.87 30.29 50.55 0.00 0.00 Surface 6309 61.08 30.29 30.69 200.00 200.00 MinPts 63.11 61.07 30.30 30.33 209.97 209.97 MinPt-0-EOU 84.74 81.49 51.93 25.72 491.38 491.05 MinPt-O-SF 679.72 670.85 646.91 ija 1215.35 1199.82 MinPt-O-SF 2569.70 2538.92 2524..: 86.'' 4250.93 3520.09 MinPt-OSF 2554.80 2524.5 2509.8 87.34 4442.80 362440 MinPt-O-ADP 2554.7 2524.4 2509.88 87.39 4448.19 3627.14 MinPt-O-EOU 25541 2524.50 2509.90 87.44 4453.59 3629.86 MinPt-CtCt 2285.88 2248.47 2230.2'M:ElE 6074.83 395872 MinPt-O-SF 1688.04 1657.79 1643.1. 7037.83 3933.48 MinPt-O-SF [1420.12' 1387.46 1371.62 44.80 7647.30 3925.30 MinPt-CtCt 1420.5`91)1 1387.06 1370.82 43.71 7675.17 3926.48 MinP1-0-EOU 1421.10 1387.1-,,/1 1370.70 43.10 7691.31 3927.16 MinPt-O-ADP 175543 1890.15 1658.00 27.28 8374.99 3949.35 MinPt-O-SF I 1798.38 1731.52 1698.59 27 29 8390.40 3949.69 MinPt-O-SF 1939.93 1869.23 1834.37 27.81 8410.34 3950.13 TD 2699.80 2597.15 2548.31 26. 4610.45 3703.90 MinPt-O-SF 2598.26 2503.771 2457.0 27.78 4914.78 3816.11 MinPt-O-ADP 2597.94 2503.71 2457.08 27.85 4924.52 3818.96 MinPt-O-EOU I 2597.7 2503.92 2457.50 27.97 4940.16 3823.44 MinPt-CtCt 2840.11 2751.32 2707.4.Y] 6057.52 3957.21 MinPt-OSF • 8-.' t'' t 2957.0 ' 7042.48 3933.37 MinPts 2934.42 2857.10 2818.9' 7367.64 3925.82 MinPt-O-SF 2921.16 2844.04 2805.9 7434.86 3924.26 MinPt-O-SF 2895.99 2819.51 2781.7 MS, 7529.19 3922.85 MinPt-O-SF 1943.0 �.. ;6' 8410.33 3950.13 MinPts SP3O-W1(P2)(Def Plan) Pap 71.07 69.84 38.26 57.06 0.00 0.00 Surface 71.07 69.05 38.26 34.64 200.00 200.00 MinPle 71.07 69.05 38.26 34.60 209.97 209.97 MinPt-O-EOU 71.18 69.13 38.3 299.71 299.70 MinPt-O-SF 126.20 107.00 93.3 2283.18 2172.95 MinPt-O-SF 127.58 108.04 94.77 6.48 2326.13 2207.31 MinPt-0SF 133.08 112.48 100.27 6.41 2432.33 2288.90 MinPt-O-SF 133.85 113.13 101.04 6.41 2442.84 2296.70 MinPt-O-SF 554.15 531.95 521.34 24.92 4276.56 3534.77 MinPt-O-SF 2777.08 2720.95 2693.37 50. 6079.38 3959.11 MinPt-O-SF ' 3004.73 2944.20 2914.44 50. 6530.50 3954.94 MinP1-0SF 3611.48 3417.00 3320.25 18.66 13609.59 3801.20 TD 9741.23 9671.89 9637 71.11ZEKE 1709.53 1662.75 MinP1-0SF 9673.01 9604.15 9570.21 142 49 1727.31 1679.23 MinPt-O-SF 9609,18 9540.77 9507.06® 1744.10 1694.78 MinPt-O-SF 10146.70 10073.43 10037 28® 2645.64 2436.44 M1nPt-O-SF ' SI14-N6(P2)(Def Plan) Pap • 79.99 78.77 47.19 E 3E 0.00 0.00 Surface 79.99 77.961.7 19 38.73 200.00 200.00 MinPte 80.03\ 77.94 47.23 37.57 260.20 260.20 MinPt-O-EOU 80.331 77.93 47.52 33.02 365.59 365.53 MinPt-O-EOU 81.53 77.13 48.72 18.26 526.23 525.75 MinPt-O-EOU Drilling Office 2.0.960.0 Nikaitchuq\Spy Island\SP23-N3\SP23-N3\SP23-N3(P3) 8/24/2011 2:33 PM Page 3 of 13 Offset Trajectory Separation Allow Sep. Reference Trajectory Separation Factor Alert Status Ct-Ct(ft)1 EOU(ft) Den.(ft) Fact. MD(ft) I TVD(ft) Alert I Minor 1 Major 134.52 117.48 101.71 7.82 1941.60 1876 94 MinPt-0SF 4235.88 4191.70 4170.10 98.03 4853.04 3796.93 MinPt-O-SF 3617.22 3410.58 3307.75 17.58 13609.59 3801.20 TO 5089.02 5051.71 5033.55\ 140.0 1981.28 1913.05 MinPt-0SF 5037.23 5000.29 4982.31 140.07 1987.66 1918.82 MinPt-O-SF 4342.83 4311.10 4295.73‘ 122 2083.26 2004.04 MinPt-OSF 3727.92 3697.95 3683.5 128.95 2190.67 2096.52 MinPt-O-SF 3477.21 3449.62 3438.36 131.09 2236.60 2134.87 MinPt-OSF 3439.77 3412.58 3399.5 131.63 2244.62 2141.49 MinPt-O-SF 3106.92 3084.74 3074.11 140.07 2317.98 2200.83 MinPt-0SF 2822.85 2803.29 2790.04 144.24 237244 2243.50 MinPt-0SF I 1105.861 1087.971 1073.05 61.76 2636.18 2430.40 MinPts SP12-SE3(P2)(Def Plan) Pau 111.14 109.92 78.33 89.80 0.00 0.00 Surface 101.81 97.99 69.00 26.32 545.92 545.35 MinPts 101.8 97.91 6908 25.26 560.11 559.46 MinPt-O-EOU 124.04 117.70 91.23 MIMI 718.47 716.48 MinPt-O-SF 2577.67 2561.13 2544.86 MIME 2282.84 2172.68 MinPt-O-SF 2574.24 2552.08 2541.4 =ma°.�8 2412.76 2274.24 MinPt-0SF 2403.31 2367.93 2350.73 69.84 253921 2365.72 MinPt-CtCt 2403.5 2367.7 2350.29 68.96 2542.67 2368.12 MinPt-O-EOU 2403.78 2367.7 2350.2 68.60 2544.15 2369.14 MinPt-0,ADP 2601.43 2559.34 2538.7 63.261 2794.19 2530.64 MinPt-O-SF Ir U 2931.93 2902.75 2888.65 103.95 4485.69 3635.93 MinPt-CtCt 2932.061 2902.601 2888.36 102.92 4499.94 3652.79 MinPt-0-EOU 2932.23 2902.64 2888.33 102.45 4515.82 3660.45 MinPt-O-ADP 2937.88 2907.27 2892.51 99.43 4674.24 3730.99 MinPt-O-SF 2941.73 2911.19 2896.45 99.76 4719.52 3749.11 MinPt-0SF 2960.15 2929.25 2914.34 99.22 4855.75 3797,81 MInPt-O-SF 2746.02 2701.54 2679.7 6075.89 3958.81 MinPt-O-SF 2347.67 2294.78 2268.83 45.21 6854.99 3937.65 TD 2751.94 2728.64 80.07 4881.11 3733.80 MinPt-CtCt 2799.91=ME 2727.76 59.00 473780 3758.16 MinPt-0{OU 2800.43 2751.5,=HUM 58.49 4766.83 3767.03 MinPt-O-ADP 2361.46 2305.83 2278.5.MIZEIC 6760.30 3939.66 MInPt-O-SF 2352.59 2297.17 2269.9 MEC 6790.24 3938.94 MinPt-O-SF 2333.61'Man 43.71 6842.84 3937.89 MinPts WOE 2279.29 2252.64 43.76 6844.37 3937.86 MinPt-CtCt 5132-W2(P2)(Def Plan) Peas 95.01 93.79 62.20 76.63 0.00 0.00 Surface 95.01 93.00 62.20 46.52 200.00 200.00 MinPts 95.01 92.99 82.20 4649 204.98 20498 MinPt-O-EOU 95.17 93.13 62. •mg= 299.61 299.60 MinPt-0SF 95.7• L6l 62.91 50.21 414.07 413.95 MinPt-O-EOU • 134.52 128.83 101.71_ 23.431 958.52 953.10 MinPt-OSF 305.85 296.21 273.05 31.57 1477.97 1447.22 MinPt-O-SF 688.15 671.73 655.34 41.8 2891.72 2593.88 MinPt-0SF 941.94 921.74 909.13, 46.5 3552.81 3058.10 MinPt-O-SF 966.87 946.12 93406 46.56 355401 3087.48 MinPt-0SF 974.69 953.78 941.88` 46.56 3606.59 3096.43 MinPt-0SF 1012.76 991.02 979.95 46.54 3665.74 3138.33 MinPt-O-SF 1033.37 1011.20 1000.57 46.56 3696.48 3159.97 MinPt-O-SF 1069.28 1046.32 1035.3 48.61 3748.16 3196.09 MinPt-O-SF 1101.79 1078.13 1066.7 48. 3793.17 3227.25 MinPt-O-SF 1112.79 1088.90 1077.45 48. 3808.05 3237.49 MinPt-0SF 1141.76 1117.24 1105.48 48.4 384650 3263.77 MinPt-0-SF 4815.47 4612.20 4511.06 23.80 13609.59 3801.20 TD 11031.68 10945.34 10902.::MIME 1648.30 1605.93 MinPt-OSF 11002.73 10916.61 10874.. NEBEH 1655.78 1612.88 MinPt-O-SF 10827.60 1074273 10700.7•I)M 213404 2048.22 MInPt-0SF SP33-W3(P2)(De(Plan) Pees • 103.10 101.88 70.29 83.24 0.00 0.00 Surface 103.10 101.08 70.29 50.53 200.00 200.00 MinPts 10310 101.08 7029 50.51 204.98 204.98 MinPt-0-EOU 103.42 101.38 70.61e 50.21 299.58 299.56 MinPt-O-SF 179.55 172.29 148.74 24.56 1133.36 1121.34 MinPt-O-SF 506.58 490.8"6, 473.77 32.16 2207.06 2110.29 MinPt-O-SF 525.90 509.31 493.09 31.67 2738.25 2495.16 MinPts 525.99 509.2 493.18 31.38 2758.24 2507.83 MinPt-O-EOU 529.67 51231 496.8 11111.0M 2855.50 2570.13 MinPt-O-SF I 545.21 527.23 512.''MEM! 2985.99 2656.98 MinPt-O-SF I 5640.6 5544.0 5496.28 59.00 821650 394584 MinPt-O-EOU 5641.89 5544. 5496.031 58.41 8261.45 3946.84 MinPt-O-ADP 6025.62 5795.23 568053 26.26 13609.59 3801.20 TD S107-SE4(P2)(Oaf Plan) Paas 151.14 149.91 118.33 122.48 0.00 0.00 Surface 146.43 142.87 113.63 40.68 517.74 517.31 MinPts 148.53 142.74 113.73 38.28 536.86 536.33 MinPt-O-EOU 189.77 182.33 156.96 1111MME 785.51 782.62 MinPt-OSF 3198.66 3176.47 3165.•• 2152.83 2064.37 MinPt-O-SF MM:ZEE 3229.64 3211.91 92.04 2296.13 2183.40 MinPt-CtCt 3266.31 I :-: 3211.40 90.83 2299.78 2186.33 MinPt-O-EOU 3266.59 3229.4. 90.24 2301.60 2187.79 MinPt-O-ADP 3302.24 3260.11 3239.5 - 2340.59 2218.71 MinPt-0-SF 3360.31 3318.02 3297.3 NEM 2380.07 2249.37 MinPt-O-SF 3783.06 3734.54 3710.7 - 2528.81 2358.50 MinPt-O-SF 3808.32 3759.48 3735. •- 2534.09 2362.17 MinPt-O-SF 4764.03 4704.94 4675.8:- 2783.60 2523.91 MinPt-OSF Drilling Office 2.0.960.0 Nikaitchuq\Spy Island\SP23-N3\SP23-N3\SP23-N3(P3) 8/24/2011 2:33 PM Page 4 of 13 Offset Trajectory Separation Allow Sep. Reference Trajectory Separation Factor Alert Status Ct-Ct(ft)I EOU(ft) Dev.(ft) Fact. MD(ft) I TVD(ft) Alert 1 Minor I Major 317626 314459 3129.29 _ 103.76 4889.46 380848 MinPt-0SF 3159.90 3128.78 311376 105.13 504328 3849.85 MinPt-O-ADP 3159.87 3128.7-',11 3113.76 105.19 5046.20 3850.51 MinPt-0-EOU 1 3159.86 3128.78 3113.77 105.24 5049.12 3851.17 MinPt-CtCt 3051.63 3005.371 2982.731 67.371 6064.44 3957.81 MinPts I 2969.79 2918.20 2892.90 58.66 6885.11 3937.03 MinPt-CtCt 2969.87 2918.15 2892.78 58.51 6888.45 3936.96 MinPt-O-EOU 2969.93 291816' 2892.7 58.46 6889.55 3936.94 MinPt-O-ADP 3050.34 2994.81 2967. 55.901 6954.05 3935.51 MinPt-O-SF 3076.84 3020.90 299342 55.97 695526 3935.48 TD I 3078.511 3022.54 2995.051 55.981 6955.26 393548 MinPis SD37-DSP1(P4b)(Def Plan) • Pass 143.77 142.65 110.96 127.99 0.00 0.00 Surface 143.77 141.84 110.96 73.99 200.00 200.00 MinPts 143.94 141.68 111.13 63.36 289.45 289.44 MinPt-0-EOU 200.15 193.17 167.34 11:E13 1078.19 1068.20 MinPt-OSF 1584.95 1562.85 1552.1 mon 3843.54 3261.76 MinPt-0SF 177018 1740.46 1726.10 mmEE 4681.46 3733.94 MinPt-O-SF 3488.72 346283 3450.38 14005 5280.75 3889.30 TD SP04SE5(P2)(Det Plan) Pas 181.68 178.50 148.87 56.80 50593 50554 MinPts 181.79 178.36 148.99 52.63 540.32 539.78 MinPt-0-EOU 228.33 221.03 195.52® 868.91 864.56 MinPt-O-SF 3137.93 3124.29 3105.1 MEM. 1942.44 1877.71 MinPt-O-SF 3853.86 3831.66 3821.06® 2060.18 1983.70 MinPt-O-SF 4322.23 4278.22 4256.7 100.6. 2202.69 2106.63 MinPt-O-SF 5808.71 574485 5713.41 imEEE. 2506.02 2342.46 MinPt-OSF 7399.36 7321.59 7283.20�r3'a 2783.36 2523.76 MinPt-OSF 313473 3101.95 3086.0' 5100.17 3862.04 MinPt-OSF 3104.31 IIIME 3056.91 100.47 5233.76 3883.91 MinPts MIME. 3072.37 3056.94 100.54 5236.32 3884.23 MinPt-CtCt 3065.82 3048.99 92.11 5447.37 3904.03 MinPt-CtCt 3100.7 3065.60 3048.55 90.93 5465.08 3905.57 MinPt-0-EOU 3101.08 3065.66 0 90.23 5475.78 3906.51 MinPt-O-ADP 3232.19 3184.20 3160.6'mug 6076.75 3958.89 MinPt-0SF 339273 3340.88 3315.' 66.6" 6885.00 3937.04 MinPl-OSF 3838.04 3783.15 375620 71.19 6970.41 393513 TD 1 3841.54 3786.64 3759.681 71.241 6970.40 3935.13 MinPts SI35-W4(P2)(Def Plan) Pass 119.09 117.87 86.28 96.30 0.00 0.00 Surface 1 119.091 117.071 8628 58.46 200.00 200.00 MinPts 119.37 117.35 86.57 58.29 264.68 264.68 MinPt-OSF 240.53 233.72 207.73 35.11 1059.30 1049.95 MinPt-O-SF 250.50 243.41 217.6 1087.89 1077.56 MinPt-O-SF I 420.73 409.76 387.92 38.24 1453.42 1424.27 MinPt-OSF 786.05 767.52 753.25 42.36 2277.90 2168.68 MinPt-OSF 831.72 809.96 798.91 38.18 2801.19 2535.10 MinPt-OSF 6309.81 6249.68 6220.11 106.67 6080.38 395920 MinPt-OSF 7196.96 6999.67 6901.51 36.66 1360959 380120 TD 14323.12 14202.41 14142.5 .I 2199.22 2103.71 MinPt-O-SF I SP01-SE7(P2)(Def Plan) Peas 20723 206.01 174.42 188.31 0.00 0.00 Surface I 206.90 204.39 174.10 81.67 361.34 36129 MinPts 207.00 204.31 17419 76.63 406.61 406.50 MinPt-O-EOU •• 27598 268.95 243.17 39.09 87219 867.77 MinPt-OSF • 4536.07 4485.65 4460.93 91.73 6068.50 3958.17 MInP5-OSF 4702.14 4648.42 4622.0 6848.78 3937.78 MinPt-OSF 5489.25 5428.57 5398.72_ 91.93 7114.85 3931.69 MinPt-OSF 6223.30 6160.95 6130.26 101.39 7338.86 3926.49 TD I 7579.64 7517.77 7487,3 124.47 6086.21 3959.70 MinPt-O-SF 6179.98 6157.78 6147.18, 278.29 1934.63 1870.56 MinPt-O-SF 6633.61 6582.41 6557.31 132.10 2055.27 1979,35 MinPt-O-SF 8945.16 8844.12 8794.0 2390.26 2257.18 MinPt-OSF 7644.83 7579.86 7547.86 119.46 6847.45 3937.80 MinPt-O-SF 1 6227.831 6165.471 6134.78 101.46 7338.85 3926,49 MinPts 5102-SE6(P2)(Def Plan) Pass 19912 197.90 166.31 161.69 0.00 0.00 Surface 199.12 197.10 166.31 98.15 200.00 200.00 MinPts 19923 196.87 166.43 83.89 300.76 300.75 MInP1-0-EOU 277.60 270.12 244.79 838.14 834.37 MinPt-O-SF 5056.29 5034.12 5023.4'X00' 1951.44 1885.93 MinPt-OSF 5415.6 5375.31 535569 137.92 2053.33 1977.83 MinPt-O-EOU 5416.15 5375.4 5355.59 136.51 2055.52 1979.57 MinPt-O-ADP 5472.86 5422.39 53976510..L3 2106.01 2023.93 MinPt-0SF 5475.66 5425.16 540041 110.58 2107,41 2025.15 MinPt-OSF 7197.19 7116,42 707652 9019 2419,46 2279.28 MinPl-OSF 3430.30 3396.94 3380.80 106.20 5247.42 3885.60 MinPl-OSF 3940.06 3890.78 3866.63`0156 6085.66 3959.65 MinPt-O-SF 4315.13 4259.36 4231.97 78.75 6982.98 3934.83 MinPt-OSF 5092.59 5033.90 5005.05 88.24 725526 3928.43 TD 6545.68 6486.71 6457.72 112.87 544013 3903.40 MinPt-O-SF 6523.82 6464.99 6436.06 112.76 5536.25 3911.78 MinPt-O-SF 6359.18 6299.01 626941 107.42 6077.81 3958.98 MinPt-OSF 1 5096.70 5038.001 5009.15 88.30 7255.24 3928.43 MinPts SP36-W5(P2)(Dei Plan) Pass 127.151 125.131 94.341 62.45 200.00 200.00 MinPts Drilling Office 2.0.960.0 Nikaitchuq\Spy Island\SP23-N3\SP23-N3\SP23-N3(P3) 8/24/2011 2:33 PM Page 5 of 13 Offset Trajectory Separation Allow Sep. Reference Trajectory Separation Factor Alert Status Ct-Ct(ft)I EOU(ft) Dev.(ft) Fact. MD(ft) I TVD(ft) Alert I Minor I Major 127.48 125.45 94.67 62.22 264.66 264.66 MinP1-0-SF 264.82 257.89 232.01 38.03 1065.67 1056.11 MinPI-O-SF 28301 275.60 250.20 38.01 111268 1101.45 MinPt-O-SF 451.29 440.20 418.48 40.60 1444.47 1415.90 MInPt-OSF 840.10 820.82 807.2 2273.59 2165.19 MinPt-O-SF 877.61 855.43 844.801 39.52 2695.00 2467.73 MinPt-O-SF 896.23 872.78 861.58 39.98 2799.79 2534.20 MinPt-O-SF I 7666.711 7597.201 7562.94 111.87 704049 3933.42 MinPts 8145.81 7948.25 7849.97 41.43 13609.59 3801.20 TD I 13421.831 13306.60 13249.41 117.47 1914.11 185172 MinPts SP11-N7(P2)(Del Plan) Peas 119.17 117.95 86.36 96.36 0.00 0.00 Surface 119.17 117.15 86.36 58.50 200.00 200.00 MinPts 119.17 117.15 86.37 58.30 210.05 210.05 MinPt-O-EOU 119.60 117,50 86.7'0•,1. 300.50 300.48 MinPt-0SF 154.47 148.10 121.66 Z l 903.60 898.51 MinPt-OSF 351.85 334.65 319.04®" 1974.38 1906.80 MinP1-0SF 7181.77 7117.60 7086...mins 3972.44 3347.89 MinPt-O-SF 7142.72 7078.89 704746 Min 3979.52 3352.53 MinPt-O-SF 5950.15 5898.05 5872.4'IMEE 4363.37 3582.83 MinPt-OSF 5914.50 5862.66 58372 MEE 4385.17 3594.48 MinPt-0SF 5507.83 5455.49 5429.81=11:ThE 4811.48 3782.96 MinPt-OSF 5376.74 5309.19 5275.91 80.76 660436 3948.14 MinPt-O-SF 4819.75 4613.57 4510.98 23.48 13609.59 3801.20 TD 6177.73 6124.21 6097.94 117.56 1812.82 1758.33 MinPt-O-SF 6132.48 6079.34 6053.26 117.56 1827.14 1771.55 MinPt-OSF 4878.62 4838.31 4818.65. 124.04 204720 1972.19 MinPt-O-SF 4654.33 4814.81 4595.54 12076 2088.25 2008.41 MinPt-OSF 388428 386207 385148 174.84 2231.78 2130.88 MinPt-OSF 3509.44 3488.96 3476.64 171.26 2283.34 2173.08 MinPt-OSF I1311.221 1289.911 1278.41 61.48 2581.09 2394.26 MinPts Sx34-N Sand(P2)(Def Plan) Peas 111.09 109.87 7828 89.77 0.00 0.00 Surface 111.09 109.06 7828 53.93 200.00 20000 MinPts 111.26 108.90 7846 46.55 289.57 289.56 MinPt-O-EOU 111.31 108.90 78,5.mmEE. 299.52 299.51 MinPt-O-SF 325.34 311.07 292.5 NENE. 1742.15 1692.98 MinPt.OSF 387.28 370.15 354.•: ilE. 1987.65 1918.82 MinPt-OSF 405.12 387.15 37231 3gE 2117.81 2034.18 MinPt-0SF 415.98 397.26 383.1 3311E 2282.76 2172.62 MinPt-O-SF 415.54 395.54 382.7 .". 2480.33 2324.09 MinPt-0SF =MR 388.7'MEM 18.67 2658.40 2444.53 MinPts 410.:,Ma•t 378.0'mum 2670.82 2452.40 MinPts 424.52 40048 388.95 mins 2782.40 2523.15 MinPt-OSF 47507 452.90 442.251111101E 2994.14 2682.51 MinPt-0SF 783.73 76154 750.9• 4310.73 3554.01 MinPt-O-SF 1 808.851 767.25 746.95 19.89 5457.88 3904.95 MinPl-CtCt 8094'`7' 76666 745.76 19.34 5501.31 3908.73 MinPt-O-EOU 810.13 766.8 745.65' 19.12 5520.69 3910.42 MinPt-O-ADP 819.44 718.92 669.16 8.22 8463.06 3951.30 TD OP09-S1(Def Survey) Pass 17849.94 17848.37 17817.1 �a 243.65 243.65 MinPt-O-SF 16614.59 1659229 16581.7'=O00 3684.97 3151.88 MinPt-0SF 1244.29 1031.65 928.68 6.01 5037.13 3848.43 MinPt-CtCt 1245.22 1030.91 927.04 596 5062.95 3854.25 MinPt-O-EOU 1246.58 1031.18 926.73 5.94 5080.21 3857.96 MinPt-O-ADP 1283.06 1058.23 948.67 5.831 5256.56 3886.68 MinP1-0-SF 1638.90 1388.87 1266.35 6.67 6556.79 3952.32 TD 5113-FN4(P2)(Def Plan) Peas 87.99 86.77 55.19 70.89 0.00 0.00 Surface 79.37 75.99 46.57 23.08 531.90 531.40 MinPts 79.41 75.96 46.60 22.69 541.48 540.93 MinPt-0•EOU 84.03 80.08 51.22 2099 621.59 620.54 MinPl-OSF 10971.01 1094292 10929.37 404.77 3388.94 2940.58 MinP8-OSF 2810.98 2778.63 2762.98 89.81 4672.27 3730.18 MinPt-OSF 2786.51 2754881 2739.59 91.08 4840.27 3792.73 MinPts I 2786.5'•,71 2754.90 2739.62 91.15 4844.37 3794.09 MinPt-CtCI 2621.07 2575.29 2552.8'imma 6075.75 3958.80 MinPt-O-SF 1929.88 1717.86 1612.35 9.14 13609.59 3801.20 TD 17638.15 17613.55 17601.7 Man 844.15 840.27 MinPt-OSF 17598.88 17574.34 17562. ;MIEME 845.37 841.47 MinPt-0SF 1577620 15754.16 15743.40 mm 907.40 902.23 MinPt-OSF 15702.86 15680.92 156700 910.14 904.91 MinP1-0SF 15624.65 15602.81 15591.:,mum. 913.08 907.79 MinP1-0SF 15546.44 15524.72 155136 miums 916.05 910.68 MinPt-O-SF 14662.91 14642.43 14630.1. 951.29 945.08 MinPI-0-SF 14545.92 14525.60 14513.11 1111113M 956.21 949.88 MinP1-0SF 14419.23 14399.09 14386.4..MEEIM. 961.61 955.14 MinPt-O-SF 4 1829.0 =6tn 1626.95 1586.08 MinPts SP1O-FN5(P2)(Def Plan) Paas 127.25 12602 94.44 102.96 0.00 0.00 Surface 119.55 115.75 86.74 31.21 551.48 550.88 MinPls 119.62 115.68 86.82 30.04 56575 565.07 MinPt-O-EOU 145.55 138.93 112.74 EINEM 756.19 753.72 MinPt-0-SF 19668.56 19629.73 19610.81 3417.90 2961.37 MinPt-0-SF 2927.21 2895.64 2880.3'M:33 l 4830.66 3789.52 MinPt-0-SF 2913.84 2882.61 MEMEE 96.57 4943.65 3824.43 MinPt-O-ADP Drilling Office 2.0.960.0 Nikaitchuq\Spy Island\SP23-N3\SP23-N3\SP23-N3(P3) 8/24/2011 2:33 PM Page 6 of 13 Offset Trajectory Separation Allow Sep. Reference Trajectory Separation Factor Alert Status Ct-Ct(ftj EOU Iftj. Dev.(ft) Fact. MD(ft) I TVD(ft) Alert I Minor I Major 2913.8 2882.60 2867.53 96.61 4947.26 3825.44 MinPts 2796.18 2749.73 2727.0.MME 6075.17 3958.75 MinPt-0-SF 2712.63 2653.25 2624.05 46.44 7567.87 3923.12 MinPt-CtCt 2713.36 2652.53 2622.61 45.32 7637.31 3924.91 MinPt-O-EOU 2729.391'=651. 2612.96 35.45 8527.31 3952.72 MinPt-0-EOU 2765.14 2639.82 2577.65 22.23 10438.58 3873.85 MinPt-O-EOU 2767.32 2640.12 2577.011 21.92 10502.02 3867.13 MinPt-O-ADP 3057.28 2845.48 2740.07 14.50 13609.59 3801.20 TD 1402445 14002.25 139916 631.9 968.24 961.59 M1nPt-O-SF 1 1826.041 1814.131 1793.2 153.2 1601.76 1562.65 MinPts Kigun 1(Def Survey) Pass . 5013.4'wrrsEE3249.06 188.37 168.37 MinPts 5015.0:MMILII 4982.27 3003.95 198.37 198.37 MinPt-O-EOU 5015.43 5013.70 4982.6.=am 296.74 296.73 MinPt-0SF 5015.7 111= 4982.98 3005.83 417.69 417.55 MinPt-0-EOU 5016.71 MIME 4983.90 2123.81 590.10 589.27 MinPt-0-EOU 5097.60 5083.77 506479 368.721 2024.77 1952.19 MinPt-0SF 1 5082.09 5068.331 5049.28 369,29 2110.85 2028.14 MinPts 5328.94 5313.66 5296.13 348.631 2448.11 2300.59 MinPt-O-SF 3470.18 3424.15 3401.97 78.21 6632.81 3946.00 TD 1 3194.19 3145.241 3121.84 68.22 6582.63 394996 MinPts 3194.25 314529 3121.90 68.221 6583.54 3949.88 MinPt-0-SF Kigun 1 PB1(Def Survey) Pass j 5013.4•wEEEE 3249.06 168.37 168.37 MinPts 5015.0: 4982.27 3003.95 198.37 198.37 MinPt-0-EOU 5015.43 5013.70 4982.6. 2888.86 29674 296.73 MinPt-0SF 5015.7:=am 498298 3005.63 417.69 417.55 MinPt-O-EOU 5016.71 NEE= 4983.90 2123.8'1f 590.10 589.27 MinPt-0-EOU 5097.60 5083.77 506479 368.721 2024.77 1952.19 MinPt-O-SF I 5082.09 5068.331 504928 369.29 2110.85 2028.14 MinPts 5328.94 5313.66 5296.13 348.63 2448.11 2300.59 MinPt-0SF 1 3410.63 3337.371 3301.63 47.681 6642.12 3945.35 MinPts OP14S3(Dal Survey) Pass i 17860.84 17859.27 17828.• =ME 243.58 243.58 MinP1-0-5F 13598.64 13575,72 13565.8 0". 3767.96 3209.84 MinPt-0-SF 13998.72 13975.87 13965.91 669.7 3778.63 3217.22 MinPt-O-SF j 14071.28 14048,34 14038.3 ®" 3780.59 3218.58 MinPt-0SF 14144.31 14121.49 14111.51=MC 3782.58 3219.95 MinPt-0-SF 983257 9799.14 9784.9 =mu 3677.34 3146.51 MinPt-O-0F 1 3729.77 3513.52 340824 17.69 4950.32 382629 M1nPt-CtCt • 3731.06 3512.53 3406.04 17.49 498029 3834.37 MinPt-0-EOU • 3734.54 3513.25 3405.32 17.28 5018.48 3844.00 MinPt-0-ADP li 3868.34 3630.51 3513.76 16.55 5294.60 3890.67 MinPt-O-SF 3871.38 3633.38 3516.53 16.55 5297.82 3890.97 MinPt-0SF 3985.43 3740.20 3619.68 16.52 5641.55 3920.96 MinPt-0SF 4047.93 3798.91 3676.49 16.52 5831.10 3937.48 MinPt-O-SF 4083.33 3832.18 3708.68 16.52 5936.43 3946.66 MinPt-0SF 4157.04 3901.80 3776.23 16.54 6133.51 3963.18 TD 5108-FN6(P2)(Def Plan) Pass 138.38 13463 105.57 36.61 593.03 592.19 MinPts 138.45 13452 105.64 34.87 612.20 811.22 MinPt-O-EOU ' 173.67 166.60 14086 24.38 851.37 847.36 MinPl-0SF 2902.66 2870.81 2855.4 94.2 4936.74 3822.48 MinPt-O-SF 2892.69 2861.191 28459 95.01 5032.74 3847.40 MinPts 1 2892.69 2861.20 2845.99 95.06 5036.25 3848.22 MinPt-CtCt ' 2829.76 2786.39 2765.20 68.74 5923.53 3945.53 MinPt-CtCt 2830.05 2786.111 2764.63 65.86 5955.15 3948.29 MinPt-O-EOU 283048 2786.21 2764. 65.36 5973.31 3949.87 MinPt-0-ADP 2836.70 2790.62 2768.07 62.891 6089.87 3960.00 MinPt-O-SF MIME. 2789.69 2766.92 62.28 6613.73 3947.41 MinPt-CtCt 2836.2'MEM 2766.71 62.00 6641.03 3945.43 MinPt-O-EOU 2836.40 2789.6* 2766.6' 61.89 6652.06 3944.70 MinPt-O-ADP 4180.91 3966.72 3860.12 19.61 13609.59 3801.20 TD 13057.87 13035.68 13025.061 588.4 100441 996.76 MinPt-OSF 1 1767.37 1775.53 1754.56 150.871 169102 1645.59 MinPts SP05-FN7(P2)(Def Plan) Paas 175.25 174.02 142.44 142.18 0.00 000 Surface 171.81 168.35 139.00 49.39 51370 513.28 MinPts 171.92 168.22 139.12 46.07 537.78 537.25 MinPl-0-EOU • 221.41 213.59 188.60 28.16 831.87 828.21 M1nPt-OSF 1 • 3123.65 3091.39 3075.7 100.0 4984.46 3835.46 MInPt-0SF 3100.70 3069.031 3053.7 101.29 5111.27 3864.22 MinPts j I3100.69 3069.03 3053.74 101.35 5114.14 3864.77 MinPt-CtCt 3069.31 3028.87 3009.19 77.93 5735.31 3929.13 MinPt-CtCt 3069.70 3028.42 3008.31 76.31 5768.41 3932.01 MinPt-O-EOU 3070.21 3028.511 3008.1 75.53 5785.10 3933.47 MinPt-0-ADP 3108.48 3060.70 3037.3 66.401 607620 3958.84 MinPt-OSF 5317.09 5105.73 5000.53 2527 13609.59 3801.20 TD • • 12992.86 12970.68 129600 585.8 1008.04 1000.29 MinPt-O-SF I 1829.411 1817.921 1796.6 159.2 158273 1544.94 MinPts 0115-54(P4)(Def Plan) Pass 17862.43 17860.86 17829.6.MIMIC 243.30 243.30 MinPt-0SFI 14909.07 14886.41 14876.28 MEM 3801.66 3233.10 MinPt-O-SF 1 4949.60 4771.44 4684.94 28.58 4896.50 3810.63 MinPt-CtCt 4951.01 4770.05 4682.08 28.11 4931.13 3820.87 MinPt-O-EOU 4952.69 4770.39 4681.721 27.90 4947.94 3825.63 MinPt-0-ADP Drilling Office 2.0.960.0 Nikaitchuq\Spy Island\SP23-N3\SP23-N3\SP23-N3(P3) 8/24/2011 2:33 PM Page 7 of 13 Offset Trajectory Separation Allow Sep. Reference Trajectory Separation Factor Alert Status Ct-Ct(ft)I EOU(ft) Dev.(ft) Fact. MD(ft) I TVD(ft) Alert I Minor I Major 5327.62 5111.39 5004.97 25.02 6063.25 3957.71 MinPt-O-SF Tuvaaq ST 1(Def Survey) Pass 5015.0 5013.4 4982.2 3249.06 168.37 168.37 MinPts 5015.08 5013.41 4982.27 3003.95 198.37 198.37 MinPt-O-EOU 5015.43 5013.70 4982.6 2888.86 296.74 296.73 MinPt-O-SF 5015.78 mtzlE 4982.98 3005.62 417.69 417.55 MinPt-O-EOU 5016.71 MEM 4983.90 2123.80 590.10 589.27 MinPt-0{OU 5097.60 5083.77 5064.79 368.721 202477 1952.19 MinPt-OSF I 5082.08 5068.331 504928 369.29 2110.85 2028.14 MinPts 5328.94 5313.66 5296.13 348.631 2448.11 2300.59 MinPt-O-SF 1 3565.89' 3516.87 349323 75.36 6767.42 393846 MinPt-CtCt 3565.9 3516.82 3493.12 75.19 6771.52 3939.35 MinPt-O-EOU 3566.00 3516.8311 3493.121 75.14 6772.89 3939.32 MinPt-O-ADP I3568.31 3517.31 3492.68 72.39 6950.99 3935.58 MinPt-CtCt 3567.17 3514.63 3489.23 70.18 7119.56 3931.58 MinPt-CtCt 3567.55 3514.43 3488.74 69.41 7171.62 3930.37 MinPt-O-EOU 3568.29 3514.54 3488.55 68.61 7225.33 3929.12 MinPt-O-ADP 5384.98 5231.05 5154.57 35.20 12070.13 3831.75 MinPt-O-SF 5587.42 5426.85 5347.05 35.00 12615.22 3835.46 MinPt-O-SF 5659.42 5496.86 5416.07 12774.15 3838.29 MinPt-O-SF 5791.96 5625.57 5542.86 35.01 13048.68 3843.17 MinPt-O-SF 6281.70 6108.46 602233 36.46 13609.59 3801.20 TD OP1S-09(Det Survey) Pees .®rte 18135.18 0.27 0.27 MinPts 17851.0*MEM 17818.19 10923.41 168.65 16865 MinPt-O-EOU 17851.0.MM 17818.21 10396.75 210.84 210.84 MinPt-O-EOU :8661u 17849.3.ELME 10859.67 216.29 216.29 MinPts 1400821 13985.45 13975.'* 666.1. 3793.89 3227.75 MinPt-OSF 6060.84 5844.50 573873 28.63 4781.70 377244 MinPt-ClCt 6062.11 5839.10 5729.89 27.73 4833.13 3790.35 MinPt-CtCt 6063.11 5838.07 5727.82 27.48 4849.26 3795.70 MinPt-O-EOU 6064.45 5838.34 5727.54 27.35 4857.90 3798.51 MinPt-O-ADP 6939.40 6647.55 6502.75 23.961 6336.90 3967.33 MinPt-O-SF OP12-01(Def Survey) Pass I17852.68 17850.58 1781985 8489.54 200.32 200.32 MinPts 17854.61 17853.03 1782180 11344.38 243.96 243.96 MinPt-O-SF 15023.18 15000.52 14990.37 705.93 3795.94 3229.16 MinPt-O-SF 7452.66 7311.43 7243.60 54.89 4353.21 3577.35 TD 1 17852.68 17858561 17819.88 8500.701 198.81 198.81 MinPts OPO4-07(Def Survey) Pew I 17839.7 17838.79 17806.971 18124.22 0.04 0.04 MinPts 1784006 17838.53 17807.25 11672.79 160.04 160.04 MinPt-O-EOU 1784010 17838.45 17807.29 10798.70 213.64 213.64 MinPt-O-EOU I 17840.0 17838.45 17807.210913.27 216.37 216.37 MinPts 17840.69 17039.11 17007.88 11338.211 243.34 243.34 MinPt-O-SF 15476.04 15458.04 1544323 911.39 3717.71 3174.85 TD 1389928 13876.50 1386647 660.55 3704.68 3165.72 MinPt-OSF Nikaftchuq 4(Def Survey) Paw 8196.0 8195.06 8119.94 5220 52.20 MinPts 8196.1*micaz 8163.29 7704.77 67.14 67.14 MinPt-O-EOU 820165 8199.80 8168.8 4425.4 301.09 301.08 MinPt-0-SF 81658 8152.8 8133.0 629.42 1994.12 1924.66 MinPts 8165 8152.8 813383 628.01 1997.00 1927.26 MinPt-O-EOU 8042.65 8022.70 8009.85 403.01 2316.00 219928 TO 7654.22 7608.31 7585.841 170.33 2177.18 2085.11 MinPt-O-ADP 765404 7608.26 7585.86 170.85 2177.92 2085.75 MinPt-O-EOU 1 7653.87 7608.44 758621 172.17 217974 2087.28 MinPt-CtCt • 7962.53 7940.37 7929.72 Ming 2314.03 2197.72 MinPt-O-SF I Oliktok Point 1-2(Dei Survey) Pass 1 17835461 17833.561 17802. 9386.69 200.07 200.07 MinPts 17837.39 17835.82 17804.5 11335.45 243.35 243.35 MinPt-O-SF 15922.84 15900.39 15890.04 735.62 3758.19 3203.06 MinPt-OSF 8531.91 8356.41 8270.92 49.87 4479.83 3642.95 TD 17836.49 17835.51 17803.69 18120.88 0.00 0.00 Surface 1 17835.461 17833.561 17802.661 9390.291 199.74 199.74 MinPts OP08-04(Def Survey) Paw 17848.38 17846.81 17815.5 magEEE 243.63 243.63 MinP1-0-SF 14726 94 14704.20 14694.1 698.7 3778.65 3217.23 MinPt-O-SF 10708.50 10675.45 10661.26 377.26 3726.88 3181.25 MinPt-O-SF I 8401.781 8360.061 8342.19 234.87 3875.43 3283.37 MinPts Nikaichuq 4PB1(Def Survey) Pass 8196,0 8195.06 816326 8119.94 52.20 52.20 MinPts 81961 8195. 8163.29 7704.77 67.14 67.14 MinPt-O-EOU 8201.65 8199.80 8168.:•IIMEIE 30189 301.08 MInPt-OSF 8165.82 8152.84 8133.02 629.42 1994.12 1924.66 MinPts 8165.84 815283 8133.03 628.01 1997.00 192726 MinPt-O-EOU 8508.88 8463.35 8440.68 189.871 240726 2270.09 MinPts 0113-03(P6)(Del Plan) Pew 17859.31 17857.74 17826.51 ISIMS 243.30 243.30 MinPt-O-SF 16071.29 16048.85 16038.4:MEE 3731.08 318419 MinPt-O-SF 1 7629.62 7413.64 7307.57 35.95 4818.69 3785.45 MinPt-CtCt 7629.71 7413.56 7307.40 35.92 4823.17 3786.98 MinPt-O-EOU 7629.83 7413.58 7307.36 35.90 482585 3787.89 MinPt-O-ADP 7785.92 7561.87 7451.26 35.191 5067.99 3855.35 MinPt-O-SF • Drilling Office 2.0.960.0 Nikaitchuq\Spy Island\SP23-N3\SP23-N3\SP23-N3(P3) 8/24/2011 2:33 PM Page 8 of 13 Offset Trajectory Separation Allow Sep. Reference Trajectory Separation Factor Alert Status Ct-Ct(ft)I EOU(ft) Day.(ftL Fact. MD(ft) 1 TVD(ft) Alert I Minor I Major 8367.89 8132.33 8015.40( 35.77 6060.02 3957.43 Min%-0SF 8537.10 8297.45 8178.32 35.822 6529.07 3955.09 Min%-0SF 8628.98 8387.36 8267.06 35.86 6663.41 3943.99 MinPt-O-SF 8843.36 8401.38 8280.88 35.86 6686.44 3942.68 Min%ASF 8782.64 8521.41 8391.37 33.76 8710.72 3957.79 Min%-0SF 0111-01(Def Survey) Pass 1 17852.16 17851.1 17819.35 18136.79 0.15 0.15 MinPts 17852.3 178506 17819.53 10546.82 204.05 204.05 MinPts 17853.08 17851.51 17820.27 11346.25 243.60 243.80 Min%-0SF 16808.60 16794.66 16775.79`1243 811 3650.57 3127.61 MinPt-O-SF 12836.61 12813.48 12803.80 63113 3824.44 3248.73 Min%-0SF I 8700.311 8643.33 8617.76 170 05 4023.05 3380.73 • MinPts OPO4-07PB1(Def Survey) Pass 'Mr '.•BEIME 17806.97 16124.22 0.04 0.04 MinPts 17840.0:111ZIE 17807.25 11672.79 160.04 160.04 Min%-0-EOU 17840.10 17807.29 10798.70 213.64 213.64 Min%-0-EOU 51it1.X.0; 17838.. MIME. 10913.27 216.37 216.37 MinPts 17840.69 17839.11 17807.: 243.34 243.34 MinPt-O-SF 15476.04 15458.05 15443.23 911.81 3717.71 3174.85 TD 13894.90 13872.12 13862.09 660.48 3704.63 3165.69 Min%-OSF 0107-04(Def Survey) Pass 17846.83 17845.26 17814.031 11340.56) 243.64 243.64 MinPt-0SF 16113.56 16091.09 16080.751 745.49l 3726.81 3181.21 MinPt-0SF 15659.85 15632.37 15619.70 617.90 3730.61 3183.88 TD 12867.98 12827.82 12809.48 86 3655.80 3131.31 MinPt-0SF 13275.42 13236.38 13218.52. 3667.76 3139.75 Min%-0SF 13441.68 13402.42 13384.40 MKS 3672.24 3142.91 Min%-0SF 14601.15 14564.02 14546.80="1 3708.03 3168.07 Min%-0SF 14761.37 14724.06 14706 72 425.49 3712.82 3171.42 Min%-0SF Nikeitchuq 3PB2(Def Survey) Pass �6. y 7947.0•MOM 7874.25 52.20 52.20 MinPts 7884.19 7870.77 785138 588.24 2044.92 1970.16 MinPts 7884.19 7870.77 785138 587.86 2046.75 1971.79 Min%-0{OU 8514.16 8497.11 8481.3 499.48 2542.73 2368.15 Min%-0SF 8557.04 8539.91 8524 23 499.5: 2555.81 2377.14 Min%-0SF 8621.40 8604.11 8588.5•'1 498.4. 2574.21 2389.64 Min%-0-SF 8777.05 8759.54 8744.2' ) 2613.69 2415.84 Mln%-0-SF 9030.07 9010.79 8997.26 468.50 2784.43 2524.44 Min%-0SF 10642.53 10622.02 10609.72 519.00 3095.14 2732.02 TD 11182.81 11160.81 11150.00 503.1 3085.90 2725.59 Min%-0-SF I10647.041 10626.531 10614.24 518.95 3095.14 2732.02 MinPts OP17-02(Def Survey) Pass ' 17864.6 17863.4 17831.7 15164.05 114.12 114.12 MinPts 17864.6 17863. 17831.82 14556.57 125.15 125.15 Min%-0-EOU 17864.8 17863. 17832.01 11418.68 219.04 219.04 MinPts 16748.20 16723.85 16713.3 766.261 3697.50 3160.69 Min%-0SF I 9115.96 8897.13 8789.31 42.26 4773.71 3769.55 Min%-C1Ct 9116.24 8896.781 8788.63 42.13 4778.19 3771.17 Min%-0-EOU 9116.76 8896.88 8788.52 42.05 4781.19 3772.26 Min%-0-ADP 9638.21 9365.35 9229.53 35.481 5256.59 3886.68 Min%-0SF 9864.67 9391.10 9254.91 35.48 526463 3887.59 TD • OP17-02P01(Def Survey) Peen ' 17864.6 17863. 17831 79 14157 36 114.12 114.12 MinPts 17864.6 17863.3 17831 82 13752.70 125.15 125.15 MinPt-O-EOU 17864.92 17863.32 17832.11 11139.52 213.59 213.59 Min%-0SF I 17864.84 17863.24 17832.01 11167.10 219.04 219.04 MinPts 17864.92 17883.31 17832.11 11153.59 225.35 225.35 Min%-0SF 17865.61 17864.04 17832.81 11352.40 243.58 243.58 Min%-0SF 16747.17 16724.95 16714.36 770.95 3697.18 3160.46 Min%-0SF I 9170.00 8943.57 8831.86 41.03 4825.97 3787.93 Min%-CtCt 9170.35 8943.20 8831.12 40.90 4831.38 3789.76 Min%-0-EOU 9170.76 8943.30 8831.06 40.84 4833.71 3790.54 Min%-0-ADP 9945.56 9658.96 9516.15 34.821 5747.62 3930.20 Min%-0SF OP03-P05(Def Survey) Peas 17838.2 17837.16 17805.4 15882.40 90.20 90.20 Min%s 17838 17836.86 1780565 11114.05 208.13 208.13 Min%-0-EOU 1, 17838178056 17836.86 11177.98 210.86 210.86 MinPts 17839.23 17837.66 178064 11335.6411 243.62 243.62 MinPt-O-SF 16457.31 16438.52 16424.50 905.91 3704.34 3165.48 TD 15731.13 15690.83 15671.65 410.01 3647.99 3125.79 MinPt-OSF 16458.61 16436.23 16425.80 11M/MNI 3697.39 3160.61 MinPt-OSF 16442.9316422.37 16410.12 824.38 3702.60 3164.27 Min%-0-EOU 16442.92 16422.391 16410.111 825.91 3702.71 3164.34 MinPts 0119-08(P7)(Def Plan) Pass i 17870.39 17868.58 17837.5. 9855 051 243.28 243.28 Min%-0SF 16687.31 16665.09 16654.51 MEC 3691.72 3156.62 Min%-0SF 10293.35 10061.29 9946.54 44.84 4779.70 3771.72 Min%-01Ct 10293.65 10060.95 9945.86 44.71 4784.49 3773.44 Min%-0-EOU 10294.11 10061.04 9945.77 44.64 4787.23 3774.43 Min%-O-ADP 10602.46 10331.07 10195.99 39.24 5113.71 3864.69 Min%-0SF Oliktok Point I-2PB2(Def Survey) MININIIIINIIMIIIMIIIINIIIIIO Pace 1 17835.4611 17833 651 17802.6611 9839.46 200.07 200.07 MinPts 15922.84 15900.41 15890.04 735.92 3758.19 3203.06 MinPt-0-SF Drilling Office 2.0.960.0 Nikaitchuq\Spy Island\SP23-N3\SP23-N3\SP23-N3(P3) 8/24/2011 2:33 PM Page 9 of 13 Offset Trajectory Separation Allow Sep. Reference Trajectory Separation Factor Alert Status Ct-Ct(ft)I EOU(ft) Dev.(ft) Fact. MD(ft) 1 TVD(ft) Alert I Minor I Major 10500.18 10377.89 10318.91 88.97 4215.83 3499.63 TD 17836.49 17835.51 17803.69 18120.88 0.00 0.00 Surface I 17835.461 17833.61 17802.65 9843.841 199.74 199.74 MinPts 0106-05(P9c)(Def Plan) Pass 17843.71 17842.13 17810.90\ 11339. 243.34 243.34 MinPt-0SF 16800.79 16786.73 16767.98 12322 3648.42 3126.10 MinPt-0SF 16787.08 1677309 16754.2 1238.8 3655.55 3131.14 MinPt-0SF 1 16781.431 16767.361 1674852 1233.28 3663.96 3137.07 MinPts 17196.55 17176.06 17163.74 853.87 3713.73 3172.06 TD 17428.18 17363 3 17331.47 273.571 3687.30 3153.52 MinPts 17427.671 17363.2 17331.588���sss 275.35 3687.98 3154.00 MinPt-0-EOU 17254.22 17231.94 17221.4 785.731 3713.13 3171.64 MinPt-0SF 1 17198.011 17177.511 171652 853.52 3713.73 3172.06 MinPts 0P08-04PB1(Def Survey) Pass 17848.38 17846.81 17815.5 NEM 243.63 243.63 MinPt-0SF 14726.94 14704.20 14694.1' 698.7: 3778.65 321723 MinPt-0SF 14379.67 14355.59 1434498 677.87 3780.22 3218.32 TD 10707.87 10674.86 10660.68 377.551 3725.56 3180.33 MinP1-0SF 1 10339.071 10307.831 10294.64 391.55 3738.08 3189.07 MinPts Nikaitchuq 3PB1(Def Survey) Pass 7947.0' '. 7874.25 52.20 52.20 MinPts 7884.19 7870.77 7851.38 588.24 2044.92 1970.16 MinPts 7884.19 7870.77 7851.38 587.86 2046.75 1971.79 MinPt-0-EOU 8514.16 8497.11 8481.3 ^ 2542.73 2368.15 MinPt-0SF 8557.04 8539.91 8524.2 =OM 2555.81 2377.14 MinPt-0SF 8621.40 8604.11 8588.5'micE 2574.21 2389.64 MinPt-0SF 8777.05 8759.54 8744.2M"I 2613.69 2415.84 MinPt-0SF 9030.07 9010.79 8997.26 marla 2784.43 2524.44 MinPt-0-SF 10100.02 10080.99 10067.21 MEM 3055.05 2704.24 MinPt-0-SF 10335.07 10315.80 10302.26 mom 3087.99 2727.05 M1nPt-0-SF 10923.35 10873.45 10849.00® 3129.32 2755.88 MinPt-0-SF Nikaitchuq 3PB3(Def Survey) Pass '0: �. 7947.0'MEM 7874.25 52.20 52.20 MinPts 7884.19 7870.77 7851.38 588.24 2044.92 1970.16 MinPts 7884.19 7870.77 7851.38 587.86 2046.75 1971.79 MinPt-0-EOU 8514.16 8497.11 8481.35 499.48 254273 2368.15 MinPt-0-SF 8557.04 8539.91 8524.23 499.58 2555.81 2377.14 MInPt-0SF 8621.40 8604.11 8588.59 498.40 257421 2389.64 M1nPt-0-SF 8777.05 8759.54 8744.24`0114 2613.69 2415.84 MinPt-0-SF 9030.07 9010.79 8997.26 46850 278443 2524.44 MinPt-0-SF 10611.85 10591.56 10579.04, 522.98 3057.70 2706.07 MinPt-0-SF 10702.77 10682.31 10669.97 52294 3061.40 2708.62 MinPt-0-SF 11061.33 11040.22 11028.5 524.01 3072.32 2716.17 MinPt-0-SF 11089.25 11067.17 11056.44, 502.18 3073.07 271669 MinPt-0SF 11109.73 11083.17 11070.38 43430 3073.65 2717.10 MinPt-0-SF 0P18-08P82(Def Survey) Pass 1 17865.64 17862.851 17832.83 6402.81 200.09 200.09 MinPts 15927.50 15904.82 15894 701 728.48 3767.86 3209.77 MinPt-0SF 11582.8 11362.60 11254.03 53.33 4686.32 3735.92 M1nPt-CtCt 11582.5 11358.26 11247.58 52.31 4713.58 3746.79 MinPt-CtCt 11577.58 11346.35 11232.13 50.67 4761.08 3764.91 MinPt-CtCt 11577.8 11346.0811 11231.59 50.55 4764.80 3766.28 MinPt-0-EOU I 11578.18 11346.16 11231.541 50.49 4766.66 3766.96 MinPt-0-ADP 1 11615.19 11338.51 11201.06 42.24 5155.96 3872.34 MinPt-CtCt 11615.951 11337.89 11199.74 42.03 5170.06 3874.67 MinPt-0-EOU 11618.67 11338.59 11199.431 41.74 5191.18 3877.98 MinPt-0-ADP 11620.97 11338.23 11197.75 41.35 5222.48 3882.43 TD 17865.6' :40 34 ME=ME 199.66 199.66 MinPts OP05-06(Def Survey) Pass 1 17841.29 17840.31 17808.481 18125.75 0.14 0.14 MinPts 17841.45 17839.97 17808.64 12053.79 155.14 155.14 MinPt-0-EOU 17841.5 17839.88 17808.71 10834.02 212.24 212.24 MinPt-0-EOU 1 17841.51 17839.89 17808.71 10961.46 214.97 214.97 MinPts 17842.21 17840.64 17809.40 11339.161 243.63 243.63 MinPt-0-SF 16769.66 16751.04 16736.85 924.07 3671.21 3142.19 MinPts 16770.79 16749.69 16737.98 813.20 3675.68 3145.34 M1nPt-0-EOU 16792.93 16771.29 16760.1.MOM 3692.35 3157.07 MinPt-0-SF 16826.90 16804.55 16794.0' 769.01 3703.81 3165.11 MinPt-0-SF 16850.39 16826.83 16815.78 76247 3705.21 3166.09 TD 12457.01 12402.25 12375.7:migEs 3288.24 286842 MinPt-0-SF 12895.97 12838.68 12810.97 mom. 332453 2894,38 MIOPI-0-SF • 13303.76 13243.90 1321491 MEW 3355.52 2916.60 MinPt-0-SF • 13559.43 13499.01 13469.7 mew 3372.45 2928.74 MinPt-0-SF 13820.75 13759.13 137292 3387.37 293945 MinPt-0SF 14165.56 14101,70 14070.6,MM 3404.04 2951.42 MinPt-0-SF 14828.85 14760.35 14726.8 mon. 3430.45 2970.39 MinPt-0-SF 15017.41 14948.30 14914.4: 0 3436.88 297501 MinPt-0-SF 15139.76 15070.47 150365 wEliE 344141 2978.26 MinPt-0-SF 15437.22 15367.11 15332.7 ='"5 3453.71 2987.09 MinPt-0SF ' 15790.03 15717.87 15682.4 3471.03 2999.52 MinPt-0-SF 16816.72 16739.06 16700.7 =Kw 3514.18 3030.47 MinPt-0-SF 17397.63 17317.26 1727757 MIMI 3530.28 3041.99 MinPt-0-SF .11:=5 EMIZI16816.3- 761.14 3705.21 3166.09 MinPts OP18-08(Det Survey) Pass 1 17865.64 17862.85 17832.83 6402.851 200.09 200.09 MinPts 15927.50 15904.81 15894 70 728.421 3767.86 3209.77 MinPt-0-SF Drilling Office 2.0.960.0 Nikaitchuq\Spy Island\SP23-N3\SP23-N3\SP23-N3(P3) 8/24/2011 2:33 PM Page 10 of 13 Offset Trajectory Separation Allow Sep. Reference Trajectory Separation Factor Alert Status Ct-Ct(ft), EOU(ft) Dev.(ft) Fact. MD(ft) I TVD(ft) Alert I Minor I Major 11582.80 1136255 11253.95 53.31 4686.32 373592 MinPt-CtCt 11582.58 11358.21 1124750 52.30 4713.58 3746.79 MinPt-01Ct 11577.58 11346.30 11232.05 50.66 4761.08 3764.91 MinPt-CtCt 11577.83 11346.0 1123151 50.54 4764.80 3766.28 MinPt-0-EOU 1157818 11346.1 11231.461 5048 4766.66 3766.9611 MinPt-O-ADP 11627.6 11343.85 11202.81 41.22 5235.01 3884.07 MinPt-CtCt 11627.78 11343.69 11202.53 41.18 5237.86 3884.42 MinPt-O-EOU 11627.93 11343.7 11202.501 41.16 5239.28 3884.60 MinPt-O-ADP �"'I 11351.08 11205.69 40.04 5439.40 3903.34 _ MinPt-CtCt 11643.71 11349.00 11202.53 39.74 555343 3913.28 MinPt-CtCt 11647.81 113455 11195.44 38.77 5937.09 3946.71 MinPt-O-EOU 11649.40 11345.94 11195091 38.61 6001.93 3952.36 MinPt-O-ADP 11697.61 11388.69 11235.04 38.06 6227.19 3967.28 TD I 17865.64 17862.851 17832.84 6405.191 199.66 199.66 MinPts 0111.01PB1(Def Survey) Pau 17852.16 17851.1 17879.35 18136.79 0.15 0.15 MinPts 17852.349 17850.64 1781953 10546.82 204.05 204.05 MinPts 17853.08 17851.51 17820.27 11346.2 243.60 243.60 MinPt-O-SF 16808.60 16794.66 16775.79 124181 3650.57 3127.61 MinPt-O-SF 12836.61 12813.48 12803.8 631.1 382444 3248.73 MinP1-0SF 12508.01 12484.38 12474.57 636.77 3828.65 3251.60 TD 1 11611.341 11586.971 11577.011 582.211 3828.33 3251.38 MinPts OP03-P05PB2(Def Survey) Pau 1 178382 17837.16 _178054 15882.404 90.20 90.20 MinPts 1783846 17836.86 17805.65 11114.05 208.13 208.13 MinPt-O-EOU 1783846 17836.86 17805.6 11177.98 210.86 210.86 MinPts 17839.23 17837.66 178064 11335.641 243.62 243.62 MinPt-O-SF 16457.31 16438.52 1642450 905.90 3704.34 3165.48 TD 15731.13 15690.83 15671.65 409.99 3647.99 3125.79 MinPt-O-SF 16458.61 16436.23 16425.81 Man 3697.39 3160.61 MinPt-O-SF 16442.93 76422.37 76410.12 824.37 3702.60 3164.27 MinPt-0-EOU ( 16442 .92 16422.391 16410.111 825.90 370271 3164.34 MinPts OP16-03(Def Survey) Pass 1786404 17862.47 17831.2 =Km 243.54 243.54 MinPt-O-SF 16686.48 1666421 16653.6 ma= 3694.15 3158.33 MinPt-O-SF I 12237.46 12030.19 11927.56 59.61 4666.31 3727.72 MinPt-CtCt 12237.63 12030.01 11927.20 59.51 4668.57 3728.66 MinP1-0-EOU 12237.95 12030.06 11927.121 59.43 4670.27 3729.36 MinPt-O-ADP 1 12486.921 12211.04 12073.59 4542 5245.71 3885.39 MinPt-CtCt 12487.21 12210.75 12073.01 45.33 5252.41 3886.19 M1nP6-O-EOU 12487.51 12210.81 12072.9 45.29 5255.10 3886.51 MinPt-O-ADP I 12490.84 12204.71 12062.1 43.801 5571.58 3914.86 MinPts Oliktok Point I-1A-106(P5)(Def Plan) Pau 17835.80 17834.22 17802.9•EMEE 243.57 243.57 MinPt-O-SF 16688.98 16669.71 16656.17 890.18 368095 3149.05 TD 13376.77 13230.32 1315759 91.951 322413 2822.75 MinP1-0SF 16653.80 16624.77 16611.02 605.16 3670.77 3141.88 MinPt-O-ADP 1 16653.59 16624.73 16611.06 609.02 3671.09 3142.10 MinP1-0-EOU 1 16653.33 16624.94 1661150 619.52 3671.95 3142.71 MinPt-CtCt 16682.07 16659.71 16649.26 763.86 3679.50 3148.03 MinPt-O-SF OP23-W W 02(Def Survey) Pau 17876.83 17875.25 1784402 Emig 243.54 243.54 MinPt-O-SF 16627.83 16613.36 1659502=-3 3715.96 3173.62 MinPt-O-SF 14129.56 14106.58 14096.7 45144 3810.62 3239.28 MinP1-0SF 1 11939.661 11899.07 11881.24 334.70 3917.04 3311.28 MinPts 11939.68 11899.07 11881.24 334.58 3917.28 3311.45 • MinPt-O-ADP 12203.14 12162.17 12143.40 324.93 3984.58 3355.82 MinPt-O-SF 12553.48 12513.08 12493.67 323.20 '4045.02 3394.79 MinPt-O-SF 1258053 1254022 1252077 323.42 4049.11 3397.40 TD Nikeilchuq 1(Def Survey) Pass 808009 8078.35 80472 4639.8 297.55 297.54 MinPt-OSF 8056.48 8045,08 802367 706.83 1753.18 1703.19 MinPts 8056.76 8044.78 802396 672.20 1802.25 1748.57 MinPt-O-EOU 8118.19 8099.78 8085.34=En1990.95 1921.80 MinPt-O-SF 8183.56 8162.61 8150.7 =az 2023.68 1951.22 MinPt-O-SF 8257.14 8236.66 8224. . 2048.05 1972.94 MinPt-O-SF 8341.80 832007 8308.9.MEM M 2065.59 1988.47 MinPt-O-SF 8471.38 8449.45 8438.5 =ME 2087.11 2007.41 MinPt-O-SF 8554.36 6532.17 8521. .mom 2099.38 2018.15 MinPt-O-SF 9925.48 9894.68 98797 =MIZE 2228.20 2127.91 MinPt-OSF 10254.07 10221.60 10205.:.mom 2254.60 2149.69 MinPt-O-SF 10710.88 10676.88 10660.34 MENU 2285.17 2174.56 MinPt-O-SF 10830.79 10796.44 10779.7 mom 2292.77 2180.69 MinPt-O-SF 11078.86 11043.68 11026.5:=ma 2307.38 2192.41 MinPt-OSF ' 11331.61 11295.97 11278.6 NEM 2321.95 2204.01 MinPt-O-SF 11571.38 11535.04 11517. :mom 2336.66 2215.62 MinPt-0SF 12689.71 12624.59 1259252 moo 2430.07 2287.22 MinPt-O-SF Oliktok Point I-2PB1(Def Survey) Pass, I 17835.46 77833.56 17802.66 9386.69 200.07 200.07 MinPts • 17837.39 17835.82 17804.59 11335.45 243.35 243.35 MinPt-O-SF • 15922.84 1590039 15890.04 73562 3758.19 3203.06 MinP1-0SF 12877.06 12793.67 12753.76 161.30 4052.64 3399.64 TD 17836.49 17835.51 1780369 18120.88 000 0.00 Surface 1 17835.461 17833.561 17802661 9390.291 19974 199.74 MinPts Drilling Office 2.0.960.0 Nikaitchuq\Spy Island\SP23-N3\SP23-N3\SP23-N3(P3) 8/24/2011 2:33 PM Page 11 of 13 Offset Trajectory Separation Allow Sep. Reference Trajectory Separation Factor Alert Status Ct-Ct(ft)I EOU(ft) Dev.(ft) Fact. MD(ft) I TVD(ft) Alert I Minor I Major OP26.00P02(Def Survey) Pass 1 18067.0 18066.07 18034.24 18355.12 0.19 0.19 MinPts 18067.21 18065.56 18034.40 10958.06 20264 202.64 MinPI-0-EOU 18067.2 18065.57 1803440 11026.13 205.33 205.33 MinPts 18067.95 18066.38 18035.15 114840 242.99 24299 MinPt-0SF 16575.33 16559.94 16542.52 1123.1 3722.08 3177.91 MinPt-OSF 14019.63 13996.66 13986.82 678.6 3823.99 3248.41 MinP1-0-SF 1 12775.97 12747.98 12736.20 542.07 3934.60 3322.96 MinPt-CtCt 12775.97 12747.97 12736.18 541.60 3935.21 3323.37 MinPt-0-EOU 12776.00 12747.98 12736.18 541.13 3935.83 3323.78 MInP1-0-ADP 12859.76 12830.63 12818.08 511.981 3980.37 3353.08 MinPt-O-SF 12899.39 12870.41 12857.86 513.80 3990.08 3359.41 TD Nikattchuq 3(Def Survey) Pass MIME 7947.0.MEM 7874.25 5220 52.20 MinPts 7884.19 7870.77 7851.38 58824 2044.92 1970.16 MinPts 7884.19 7870.77 7851.38 587.86 2046.75 1971.79 MinPt-0-EOU 8514.16 8497.11 8481.35 499.48 2542.73 2368.15 MinPt-O-SF 8557.04 8539.91 852423 499.58 2555.81 2377.14 MinPt-0-SF 8621.40 860411 8588.59l8. 257421 238964 MinPt-0SF 8777.05 8759.54 874424 501.14 2613.69 2415.84 MinPt-OSF 9030.07 9010.79 899726 468.50 2784.43 252444 MinPt-0-SF 10611.85 10591.56 10579.04 522.97 3057.70 2706.07 MinPt-0-SF 10702.77 10682.31 10669.97 3061.40 2708.62 MinPt-0-SF 10971.38 10950.46 10938.57 3069.93 2714.52 MinPt-0-SF 11045.00 11023.93 11012.19' 524.06 3071.47 2715.59 MinP1-0SF 11059.78 11038.68 11026.97 52414 3071.54 2715.64 TD 11511.95 11489.75 11479.14 518.52 3055.65 2704.65 MinPl-0-SF 11238.13 11216.77 11205.32 526.14 3063.86 2710.32 MinPt-0-SF I11064.24 11043.13 1103143 524.16 3071.54 2715.84 MinPts 0120-07(P12)(Det Plan) Pass 17872.01 17870.44 17839.2 11357. 243.28 243.28 MinPt-0SF 16839.12 16825.10 16806 31 1239.2 3650.86 312782 MinPt-0SF 16820.09 16806.12 16787.28 1243.5 3659.95 3134.25 MinPI-0-SF 16807.6 16793.261 16774.85 1207.25 3686.77 3153.15 MinPts 168076 16793.2"'11 16774.87 1202.86 3888.11 3154.09 MinPt-0-E0U 16887.46 16865.09 16854.6 =mg 3797.80 3230.45 MinPt-0-SF 1 13147.52 12996.63 12922.48 88.64 4333.33 3566.51 MinPt-CtCt 13147.82 12996.27 12921.78 88.24 433662 3568.31 MinPt-0{0U 13148.29 12996.37 12921.69 88.02 4338.50 3569.34 MinP1-0-ADP 13720.0,,,,4,,,,ss 13524.22 13427.11 70.64, 4575.85 368845 MinPt-O-5F I13732.1 13534.55 13436.42 69.96 4634.28 3714.23 MinPl-CtCt 13732. 13534,51 13436.38 69.95 4634.78 371445 MinPt-0-EOU 13732.26 13534.5 13436.36 69.94 4635.29 3714.66 MinPt-0-ADP 13783.73 13582.58 13482.631 68.951 4675.14 3731.36 MinPt-0-SF 1 13526.27 1332414 13223.57 67.24 4992.34 3837.49 MinPt-CtCt 135262 13324.110 13223.51 67.22 4995.86 3838.39 MinPt-0-EOU 13526.33 1332411 13223.5 67.21 4997.62 3838.83 MinPt-0-ADP 13679.87 13459.70 13350.11 62.411 6114.19 3961.87 MinPt-0-SF OP22-W W01(P2)(Def Plan) Pass 17875.22 17873.65 178424 11359.6 243.27 243.27 MinPt-0-SF 16809.25 16794.86 16776.•• 1205.6• 3662.76 3138.23 MinPt-0-SF 1678456 16770.3: 16751.76 1224.23 3681.13 3149.17 MinPts 16784 5 16770.3: 16751.76 1223.61 3681.42 3149.38 MInP1-0-EOU 17039.08 17022.19 17006.2:=Dom 3748.99 3196.67 MinP1-0SF 16925.63 1690324 16892.8 MEE 3838.73 3258.48 MinPt-0-SF 15000.69 14898.49 14848.8 ®' 3836.19 3256.75 MinPt-0-SF I 14822.85 14707.19 14650.45 130.62 3868.95 3279.00 MinPt-CtCt 14824.97 14705.09 14646.15 125.75 3874.53 3282.77 MinPt-0-EOU 14827.73 14705.67 1464558 123.38 3877.44 3284.73 MinPt-0-ADP • 14893.12 14753.48 14684.15 107.401 3901.58 3300.95 MinPt-0SF OP03-P05P81(Def Survey) Pass 178382 17837.16 17805A 1588240 90.20 90.20 MinPts 1783846 17836.86 17805.65 11114.05 208.13 208.13 MinPt-0-EOU 17838.46 17836.86 178056 11177.98 210.86 210.86 MinPts 17839.23 17837.66 178064 11335.641 243.62 243.62 MinPt-0-SF 16457.31 16438.52 16424.50 905.98 3704.34 316548 TD 15682.10 15641.71 1562249 408.06 3647.31 3125.31 MinPI-0-SF ' 1645861 16436.24 16425.8.M" 3697.39 316061 MinPt-0SF 16442.931 16422.37 16410.12 824.46 3702.60 3164.27 MinPt-0-EOU 1 16442 92 16422.39 16410.111 825.99 370271 3164.34 MinPts 0P18-08PB1(Def Survey) Pass • I 17865.64 17862.85 17832.84 6402.851 200.09 200.09 MinPts 16397.27 16378.48 1636446 902.98 3711.12 3170.23 TO 1 17865.64 17862.84 17832.83 6405.11 199.66 199.86 MinPts • Oliktok Poll-111-1(Def Survey) Pass • 17835.80 17834.22 17802.9-N1=g 243.57 243.57 MinPt-0SF 16688.98 16669.83 16656.17 895.79 3680.95 3149.05 TD 17043.17 16956.18 16913.18 198.161 3475.09 300243 MinPt-0-SF 16653.80 16625.18 1661162 614.20 3670.77 3141.88 MinP1-0-ADP 16653.53 16625.13 16611.68 619.29 3671.20 3142.18 MinPt-0-EOU 1 16653.33 16625.32 16612.07 628.39 3671.95 3142.71 MinPt-CtCt 16681.39 16659.03 16648.5:wail 3679.31 3147.90 MinP1-0-SF 0P05-06PB2(Def Survey) Pass MIMEE ME=MICE 18125.75 0.14 0.14 MinPts 17841.4 17839.9 17808.64 12053.79 155.14 155.14 MinP1-0-EOU Drilling Office 2.0.960.0 Nikaitchuq\Spy Island\SP23-N3\SP23-N3\SP23-N3(P3) 8/24/2011 2:33 PM Page 12 of 13 Offset Trajectory Separation Allow Sep. Reference Trajectory Separation Factor Alert Status Ct-Ct(ft) EOU(ft) Dev.(ft) Fact. MD(ft) I TVD(ft) Alert I Minor I Major 17841.52 17839.88 17808.71 10834.02 212.24 21224 MinPt-O-EOU 1 17841.51 17839.89 17808.7110961.46 214.97 214.97 MinPts 17842.21 17840.64 178094 11339.161 243.63 243.63 MinPt-O-SF 16769.66 16751.04 16736 85 92407 3671.21 3142.19 MinPts 16770.79 1674969 16737.98 813.20 3675.68 3145.34 MinPt-O-EOU 16792.93 16771.29 16760.1.�" 'i', 3692.35 3157.07 MinPt-0SF 16826.90 16804.55 16794.0.mow 3703.81 3165.11 MinPt-0SF 16850.39 16826.83 16815.78 762.44 3705.21 3166.09 TD 12620.17 12565.04 12538.3,MIME, 3301.93 287821 MinPt-O-SF 12895.97 12838.65 12810.9 wEEE 3324.53 2894.38 MinPt-O-SF 13303.76 13243.87 1321486 MEM 3355.52 2916.60 MinPt-OSF 13559.43 13498.98 13469.6:map 3372.45 2928.74 MinPt-OSF 13820.75 13759.09 13729.1 IMIEEKE. 3387.37 2939.45 MinPt-O-SF 14165.56 14101.67 14070.5, 3404.04 2951.42 MInPt-OSF . 14828.85 14760.32 14726.81 NNW 3430.45 2970.39 M1nPt-OSF 15017.41 14948.27 14914.4 milLE. 3436.88 2975.01 MinPI-0-5F 15139.76 15070.44 150364,mow 3441.41 2978.26 MinPt-O-SF 15437.22 15367.08 15332.6:1111101M 3453.71 2987.09 MinPt-O-SF 15790.03 15717.84 15682.38 NEM. 3471.03 2999.52 MinPt-O-SF 16816.72 16739.03 1670067 MIME 3514.18 3030.47 MinPt-OSF 17397.63 17317.23 17277.52 man 3530.28 3041.99 MinPt-O-SF 16851.0 16827.46 6816 3, 761.11 3705.21 3166.09 MinPts OP05-06PB1(Def Survey) Paas I1784129 17840.31 17808.481 18125.75 0.14 0.14 MinPts 17841.45 17839.97 17808.64 12053.79 155.14 155.14 MinPt-O-EOU 17841.52 17839.88 17808.71 10834.02 212.24 212.24 M1nPt-O-EOU I 17841.51 17839.89 17808.71 10961.46 214.97 214.97 MinPts 17842.21 17840.64 1780940 11339.161 243.63 243.63 MinPt-O-SF 16769.66 16751.04 16736.85 924.07 3671.21 3142.19 MinPts 16770 79 16749.69 16737.98 813.20 3675.68 3145.34 MinPt-O-EOU 16792.93 16771.29 16760.1.�" . 3692.35 3157.07 MinPt-O-SF 16826.90 16804.55 1679409 769.81 3703.81 3165.11 MinPt-OSF 16850.39 16826.83 16815.78 76247 3705.21 3166.09 TD I 16851.07 16827.461 16816.391 761.14 3705.21 3166.09 MinPts Nikaitchuq 2(Def Survey) Paw I15987.03 15986.04 15954.22 16241.82 13.45 13.45 MinPts 15781.91 15765.67 15749.101 975.75 2300.69 2187,05 MinPts 15781.91 15765.67 15749.10 975.42 2301.11 2187.39 MinPt-O-EOU 15832.14 15809.99 15799.34 714.52 2358.16 2232.44 MinPt-OSF 15866.20 15841.55 15829.73 670.62 2369.86 2241.51 MinPt-O-SF 15938.32 15909.51 1589560 57283 2391.23 2257.92 M1nPt-O-SF 1599099 15962.00 15948.00 57098 2402.73 2266.66 MinPt-OSF 16051.30 16022.00 16007.84 566.90 2411.81 2273.53 MinPt-OSF 16254.88 1622476 16210.195 557.90 2435.20 2291.03 MinPt-0SF 16370,86 16339.94 16324.97 546.78 2442.87 2296.72 MinPt-O-SF 17103.00 17066.73 17049.0 484.60 2495.38 2334.89 MinPt-O-SF 17212.44 17175.92 17158.15 484.32 2504.00 2341.03 MinPt-0SE 17570.36 17532.36 17513 85 474.63 2526.79 2357.09 MinPt-0SF 17690.61 17652.29 17633.63 473.83 2535.23 2362.96 MinPt-OSF 17849.94 17811,26 1779241 473.54 2547.88 2371.70 MinPt-OSF 18011.97 17933.24 17894.44 231.82 2562.17 2381.48 MinPts Drilling Office 2.0.960.0 Nikaitchuq\Spy Island\SP23-N3\SP23-N3\SP23-N3(P3) 8/24/2011 2:33 PM Page 13 of 13 Schlumberger TRAVELING CYLINDER PLOT Client: Eni Petroleum NoGo Region EOU's based on: Well: SP23-N3 Oriented EOU Dimension N Field: Nikaitchuq Structure: Spy Island NoGo Region Anti-Collision rule41i Date: August 11,2011 used:Minor Risk-Separation Factor ' f®f North 350 10 0-800'md 340 S1191112 00 20 • 330 50 #,* 30 3P22-F 1(P2) - `" i 40 31047 4,4 _ K// :::,50 300 . d111 il*/A 0010r O 0 N 60 29frita&,,i4Wks,**,, �zerwiro- ���:�!` 1bir.„ iir 20 /%� / \ 1\ 70 iik. 15 7, r � .,• , 1 280 P ® \ , \ ' /A ►i ,, ittl,,,* 3',I'0, \, � 1.P18-N5(P3) 270 `IS._ � • �� ooo � o „on \ 90ilk °° 0,4 \SII. ������ O' 260tigo1 4-� ���0 ,00 $ '' .5°° nom, ` \\\ `o` `\,` .'`• 6 /�I O ti •�� `�' ;St li� . , ,N„,„\„..,,,,,_ �:��♦ � 250 �II \„., ` , 110 240 V ,> (,,/ illike120 1 230 41 i�,iir ---- 130 220 ,,�� 140 210 150 200 r 160 Well Ticks Type: MD on SP23-N3(P3) Calculation Method: Normal Plane Ring Interval: 5.00 ft Azimuth Interval: 10.00 deg Scale: 1 INCH= 15.00 ft Schlumberger TRAVELING CYLINDER PLOT Client: Eni Petroleum oGo Region EOU's based on: Well: SP23-N3 Oriented EOU Dimension N Field: Nikaitchuq Structure: Spy Island NoGo Region Anti-Collision rul: . = Date: August 11,2011 used:Minor Risk-Separation Factor *4 INorth 1 0-800'md 350 0 10 340 I' 20 330 � 40 C.-, � .�302) 320 ' "�/ . 40 /' 13-- to :: N6(P2) ..,'.-'q`y� �4,�.` , 1 87-SE4(P2) 310 , '� `��� . `` 50 4-SE1 �j1►' fib: � ,a 11,4 '� I Ativi 300 (P24'1611,461111' =��•1 ti/�`-,11411, ,, 4, ;• 60 All. 290Pit*Il `'�tii �`. 'AN►,, .�•_'_" Ai , - lihk iii -" '1/44.,..TF:-."-•.‘bit,..1110,. .. .. .5 • „„,,„.,-..-... ,•-_-,- ,:, ,..,. 4,„,,...,-_- _-. ,.--'•-..'"r/i/ .1,!' ' , .:I1 280 a ./,,./%;;:-.'.,....,40,1t , ' � . ao �t,k so 40111„.27-..-„,„----..t..,_ ,.� ' 'ikV��:,,1i. ,l` �l',l1,440;:.:*�1� / • 'Pz) .c� �� t� `.ems ' /�, �� ! . \ 1� , ,silick ..!„ .4. ......../.,,,,,„.. ..,_._.„.. ... .. ;;---•:-.:141A:',, ,•���7 ��,� ?-N - _ ;''�� nFL .►ISD-.v !I1: 270 % wzdir j ItrV A".1 ���t� ��� \ %1106 lififf' i , / 9° /a.tififiwtoi.s.. 260 \ 4,,`:,'; WAi it,,,1+��► •\, /= --,44Z. i;. . 100 x.,,,:,..,4 �1�;:if/'>'r '�,.;;:,'.-t---:',...;---,..---;:"30." „SI25-. .z) " °� 1. 250 , ..;_--.;• "4►� �' ° \ 110 10 moi %, � ,\' 4-1Wkilllidp7ra o., )4,- . iiallik 240 1.� 120 30 130 220 ainrilliA 140 210 150 200 160 190180 170 Well Ticks Type: MD on SP23-N3(P3) Calculation Method: Normal Plane Ring Interval: 20.00 ft Azimuth Interval: 10.0 deg • Scale: IN=%50.00 ft Schlumberger TRAVD.ING CYLINDER PLOT Client: Eni Petroleum NoGo Region EOU's based on: Well: 5P23-N3 Oriented EOU Dimension Field: Nikaitchuq Structure: Spy Island NoGo Region Anti-Collision rule Date: August 11,2011 used:Minor Risk-Separation Factor I4 , North 800'- 13-3/8" 350 0 10 340 _r�� 20 330 30 .� -.4•111 140 �. 320 1111", , . 40 120 air rill 4r+s ■.1* f,ri, fib . 5030 �� 60 29060 `� 70 OW\'� 40 zoo - 280tit All arp...._- A � 19:77 � 01111111111pzi,,,Aig: �.... A 80 2015 . � � IAV. •444\ .I:. i�� �tet11$0Ille \ .P11-N7(P2) :14, iii. 270Ill°1 il;%V i /� 'il';rP \�. , i •i i`'� ` ,,1j ' 1 .P4-N6(P2) Iff;Z:Ik'1. igloi \1644 4/1110001:4*4 260dilIi '4,fr ..,,Ss X11. ; \V%...,„1:14•14,...:7._,/,.1.040467 1 - s 100 • i, I la .__,,„Joiy, 250 ��iiille�//I���. � ��CC �''��.:' ��r1��/�I ik A�� r04-47 ' 110 A iii ,...2 40e rpick.:4„,,,1,: 4401144 240 A 'LIQ,.►ah /l, — \ril. 120 230 �ji'� 130 1 220'' 4rigto, 140 4 21� 150 200 125-WW2) 190 180 170 Well Ticks Type: MD on SP23-N3(P3) Calculation Method: Normal Plane Ring Interval: 20.00 ft Azimuth Interval: 10.0 deg Scale: IN=%50.00 ft Schlumberger TRAVELING CYLINDER PLOT Client: Eni Petroleum NoGo Region EOU's based on: Well: SP23-N3 Oriented EOU Dimension 9V Field: Nikait chug Structure: Spy Island NoGo Region Anti-Collision rule A-. Date: August 11,2011 used:Minor Risk-Separation Factor *4 North 13-3/8"-9-5/8" 350 0 10 401dio 32020 68 4f(64)(P1) 33.7---0111300 30 280 38• 320O. 2f0 � 40 40 '240 07 i 310 �, , 220 - ,® 50 /�� ;I� ._ I, 200Ad ,� ', 300 7 O180 A , , 60 i, 160 ��,♦�� 'Oar .0 4-N6(P2) *� 9^.• 41jok � 140 ' �i •� • 290 / . �� . 120 ���' 70 '-!� �� * ��aii 100 4� Al) �9. it. 280 � ' . l►isovval• -47. ��• 2�� ", A% 4 60 gIlL °, 80 nil 270 . 1111 ' 41_ o 20 .' „EE ,�114i 90 Ili .y a o � � r �� �1� •k o�' 'oma ��11111114 � �� o 260 ill MRS NI It o c \iti 4fro., 411111111P '‘ e - , -4 ,, 4 , . oo� 111EN"- , 100 so \ ,.... 250 o 1 o�c� r■. ° ooh � 110 o � o oti oo �c� 1 ' 11■, . o° �� 240 ,,0 co it ,®# o, tiw 120 230, 410„. S �� 130 22;1' * 23:N '-N2 P2 ,4 ' �� e N � �7 0 0 �� � � 111117.. � ` 140 210 7/ Ir g 50 200 '_��� 4`1` 160125-N2(P2) 190 1 R 170 I Well Ticks Type: MD on SP23-N3(P3) Calculation Method: Nominal Plane Ring Interval: 20.00 ft Azimuth Interval: 10.0 deg Scale: 1 INCH=100.00 ft Schlumberger TRAVIIdNG CYLINDIR PLOT Client: Eni Petroleum NoGo Region EOU's based on: Well: SP23-N3 Oriented EOU Dimension .7V Field: Nikaitchuq Structure: Spy Island NoGo Region Anti-Collision rule A ' = Date: August 11,2011 used:Minor Risk-Separation Factor '4 f�� North 1 9-5/8"-TD 350 0 10 340 101 450 20 33 450 30 �l 420 320 -_ g��ii 390 I 40 '4��..,r 360 � 310 ����•-���� . 330 Wit* 50 ,I•I♦� A•I . 30044 Sal i,,, ;��oi�` s 4 270 300f Opp' '`, ,," .� 240 f SN* so 40�A=_,•;;; 444, � OPP 210 �� 290,00.11h"- so i�ilyimm 4 ,, - 180 ' %1416 70 ,00.*4171p*S\� • 150 120280 \ ,� 90 .� *11 eat ' 80 3032 a i#Ak 60 .311111111111f 270 4 13237 O� 30 4.111111011111111/111111116114.111111011111111/1111111161111111� 701 . , 90 13338 O ik w MI�� . O tp 280 , O o oo" rf ' i - 100 o cc, o4 250 (P2) , o� c? w 110 o �co M Ow oil o (%4 O 4 Ifti0 240 o� 120 4 130 _r O 220 140 r 210111111111111 -- 150 200 4111.11111110 160 190 180 170 - Well Ticks Type: MD on SP23-N3(P3) Calculation Method: Normal Plane Ring Interval: 20.00 ft Azimuth Interval: 10.0 deg Scale: 1 INCH=150.00 ft Drilling Hazards Summary 16" Open Hole / 13-3/8" Casing Interval Hazard Risk Level Mitigation Strategy Broach of Conductor Low Monitor continuously during interval. Gas Hydrates Moderate Control drill, Reduced pump rates, Reduced drilling fluid temperatures, Additions of Lecithin. Running Sands and Low Maintain planned mud parameters, Increase Gravels mud weight, use weighted sweeps. Hole swabbing on trips Moderate Trip speeds,proper hole filling(use of trip sheets),pumping out 12-1/4" Open Hole / 9-5/8" Casing Interval Hazard Risk Level Mitigation Strategy Running Sands and Low Maintain planned mud parameters, Increase Gravels ' mud weight, use weighted sweeps. Gas Hydrates Low Control drill, reduced pump rates, reduced drilling fluid temperatures, additions of Lecithin. Stuck Pipe Low Good hole cleaning,pre-treatment with lost circulation material, stabilized BHA, decreased mud weight Abnormal Reservoir Low BOP training and drills, increased mud weight. Pressure Lost circulation Low Reduced pump rates, mud rheology, LCM Hole swabbing on trips Moderate Trip speeds,proper hole filling (use of trip sheets),pumping out 8-1/2" Open Hole / 5-1/2" Liner Interval Hazard Risk Level Mitigation Strategy Abnormal Reservoir Low / Stripping drills, shut-in drills, increased mud Pressure weight. Stuck Pipe Low Good hole cleaning, PWD tools, hole opener runs, decreased mud weight Lost Circulation Low Reduced pump rates, mud rheology, LCM Hole Swabbing on Trips Moderate Trip speeds,proper hole filling(use of trip sheets),pumping out, backreaming /1C J ` • O �O 7 N O _ N N� Z M N ¢ NV a Y W a =o.. ;.:; :o ; :o z� p.� oz N W 0 a S O o km mQ6 W a Y O m a �. _ a�� j m Y c-> m m ,_ Q a CJ '0 N co r-. Q <n P p . 2 m - B E- I i CC1 G O Q i oq w � LO Z Vi J - /vim Qa`.J \ o�N 2 � � oi. .-4 m,O _ \ W Z Le _IJ:D= Z O YNZ a a �� a.c, J V i aaa \ ill-'C' av _ \p -iz r- m / a m •._. L Z r.' l 1 i E Q u, 1 �� d j 3 5 WS -e = 3 i4i N i gg I - Z. a -t- —i Ti 1 ` 1 -I m - j —_—_ - A- 1 L I .1fJzr-- ...,w - H_____, Al 1 w'- ,...., i A 1 I >E I -o z I wkl I $ i 1 j i> I 0 . 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T. _ '£ 0 M NMa ONCOM ,-NM.EI. t0I,WM ,-NMN) tOI,NM E-NM V EM —NM ap ' p a V N M M M M M t+i M M M M a 7 V)V)V)N VV)V)V)V 4 4 4 4 4 4 4 Ul V) ) Up cO O 6 66 6 6 0 6,t r N N `p n of '33 X8 H j n •_m N N 0 m • T N r to-1 m O N OM Mi'-O V)V)N 1 O r O W 2 W to 0 0 O) M M g d V)23 ID 2 n 2 W M aO N 2 W tb M N 2:,NM P; •- p) 00 N m❑ - m 4 'd 4 d d d d e a 4 4 4 a a 7 a V v a V)to V)V)V)V)V)V)N )ui V)VV)V)V)V)N N v )t0 b t i V0 6 t0 t0 6 L a 3 N E a 1 C S N M a V)W N\OO M .-N M a O W n W M —Nn-4-661--.6 3 P ~ CO M M W COM p)M CD M M M M O)M M 0 0 0 0 0 0 0 0 0 N N N N N N N N '5 -44 8 a N N i e i 6 O ___________,,,,,,_____________„,,,,__ ,..7_A7____\._7__\_/___\\_/_________ I a / O i v J W Z W • S 7 < 0 N M 3 WD K O N W LL 3 S Q I41* Z O -J J- W CC N m Q 0 t a) W > C 1'4 S , ,, or ; Li V ink 4011 ' 1, 11 E LI liE o � o N &elf" ink cs cn (21 , IP 1.3. 1.-i; gh14. ' ' . r i_ cn „La Alb --w 1 mkt ip ..... ,.........._....saw_ f ilibkv-4-4 - , 411\ 0 IS , Ai. ', 19. (1D IP r IL i .47__ , (:) t CD w 0 t,, Q rill 1)a 0 ' i vab Orr d d a > ` C > Cl) C c is d d > > i dib. Via f>B > 'a T a� a� Ed �- z 2 ce CO U J 'tj 1 o A c W ca >, _ >, c — Nov < 2 - I c� _ N fC I t3 N 0W O C) O r x r r r= M N M 4 J 6 C"1 Q 1 Cr ED ti W e}T y- e- T d 1 T Schlumberger CemCAD E*well cementing recommendation for 13.375" Surface Casing Operator : Eni Petroleum Well : SP23-N3 Country : USA Field : Nikaitchuq State : Alaska Prepared for : Mr.Luca Borri Location : North Slope-Alaska Proposal No. : Draft v2(P3) Service Point : Prudhoe Bay,Alaska Date Prepared : 8/24/2011 Business Phone : 907-659-2434 FAX No. : 907-659-2538 Prepared by : Mark Roos Phone : 907-748-7555 E-Mail Address : mroos@slb.com 011 D c •04014 • • Disclaimer Notice: Schlumberger submits this document with the benefit of its judgment,experience,end good oilfield practices. This information is provided in accordance with generally accepted industry practice,relying on facts or information provided by others,limitations,computer models,measurements,assumptions and inferences that are not infallible. Calculations are estimates based on provided information.All proposals,recommendations,or predictions are opinions only. NO WARRANTY IS GIVEN CONCERNING ACCURACY OR COMPLETENESS OF DATA.INFORMATION PRESENTED,EFFECTIVENESS OF MATERIAL.PRODUCTS OR SUPPLIES,RECOMMENDATIONS MADE,OR RESULTS OF THE SERVICES RENDERED. Freedom from infringement of any intellectual property rghts of Schlumberger or others is not to be inferred and no intellectual property rights are granted hereby. • • *Mark of Schlumberger Client : Eni Petroleum Well : SP23-N3 Schlumberger String : 13.375 District : Prudhoe Bay,Alaska Country : USA Loadcase : Surface Casing Section 1 : well description Configuration : Casing Stage : Single Rig Type : Land Mud Line : 0.0 ft Total MD : 2284.0 ft BHST : 37 degF Bit Size : 16 in ft (x 1000)psi 0 0.3 0.6 0.9 1.2 1.5 I t- -t I — —Siltstone— -- Frac — — — — Fore .'.'.'Sandstone. . .' S i ltstone— Shale 0 NINININVAIVINNOIA 0 0 Shale 0 0 0 Well Lithology Formation Press. Page 2 sp23-n3 v2 8-24-11.cfw:08-24-2011; LoadCase Surface Casing;Version wcs-cem462_12 Client : Eni Petroleum Well : SP23-N3 Schlumberger String : 13.375 District : Prudhoe Bay,Alaska Country : USA Loadcase : Surface Casing Previous String MD OD Weight ID (ft) (in) (lb/ft) (in) 160.0 20 178.9 18.250 Landing Collar MD : 2244.0 ft Casing/liner Shoe MD : 2284.0 ft Casing/Liner MD OD Joint Weight ID Grade Collapse Burst Thread (ft) (in) (ft) (lb/ft) (in) (psi) (psi) 2284.0 13 3/8 40.0 68.0 12.415 L-80 2270 5020 BTC Mean OH Diameter : 16.000 in Mean Annular Excess : 205.8 Mean OH Equivalent Diameter: 20.363 in Total OH Volume : 855.6 bbl (including excess) Caliper and Hole Size Data MD Caliper Excess Equiv. Diam. (ft) (in) (%) (in) 1847.0 16.000 250.0 21.184 2284.0 16.000 35.0 16.822 Page 3 sp23-n3 v2 8-24-11.cfw,08-24-2011, LoadCase Surface Casing,Version wcs-cem462_12 Client : Eni Petroleum Well : SP23-N3 Schlumberger String : 13.375 District : Prudhoe Bay,Alaska Country : USA Loadcase : Surface Casing Max. Deviation Angle : 36 deg Max. DLS : 4.404 deg/100ft Directional Survey Data MD TVD Deviation Azimuth Dogleg Sev. (ft) (ft) (deg) (deg) (deg/100ft) 0.0 0.0 0.0 160.0 0.000 100.0 100.0 0.0 160.0 0.000 200.0 200.0 0.0 160.0 0.000 300.0 300.0 1.5 160.0 1.500 400.0 399.9 3.3 160.0 1.750 500.0 499.6 5.0 160.0 1.750 600.0 599.1 6.8 160.0 1.750 700.0 698.2 8.5 160.0 1.750 800.0 796.9 10.3 160.0 1.750 900.0 895.0 12.0 160.0 1.750 1000.0 992.5 13.8 160.0 1.750 1100.0 1089.2 15.5 160.0 1.750 1200.0 1185.2 17.3 160.0 1.750 1300.0 1280.2 19.0 160.0 1.750 1377.7 1353.4 20.4 160.0 1.750 1400.0 1374.3 20.5 160.0 0.494 1500.0 1467.8 21.0 160.0 0.500 1600.0 1561.0 21.5 160.0 0.500 1700.0 1653.9 22.0 160.0 0.500 1800.0 1746.5 22.5 160.0 0.500 1900.0 1838.7 23.0 160.0 0.500 1915.9 1853.4 23.0 160.0 0.502 2000.0 1930.0 25.7 166.2 4.404 2100.0 2018.7 29.2 172.1 4.396 2200.0 2104.3 32.9 176.8 4.398 2284.0 2173.6 36.1 180.0 4.389 Formation Data MD Frac. Pore Name Lithology (ft) (lb/gal) (lb/gal) 753.0 11.10 8.43 SV-4 Siltstone 1132.0 11.20 8.43 SV-3 Sandstone 1404.0 11.50 8.43 SV-2 Siltstone 1847.0 12.00 8.43 Permafrost Base Shale 1933.0 11.80 8.43 SV-1 Sandstone 2284.0 12.50 8.43 TD Shale Geothermal Temperature Profile MD TVD Temperature Gradient (ft) (ft) (degF) (degF/100ft) 0.0 0.0 60 0.0 1847.0 1789.9 32 -1.6 2284.0 2173.6 37 -1.1 Page 4 sp23-n3 v2 8-24-11.cfw,08-24-2011; LoadCase Surface Casing,Version wcs-cem462_12 Client : Eni Petroleum Well : SP23-N3 Schlumberger String : 13.375 District : Prudhoe Bay,Alaska Country : USA Loadcase : Surface Casing Section 2: fluid sequence Job Objectives: Cement to Surface in Permafrost and a competent shoe for drilling ahead. Original fluid Mud 9.50 lb/gal k : 8.28E-2 Ibf.s^n/ft2 n : 0.262 Ty: 0.48 lbf/100ft2 Displacement Volume 336.0 bbl Total Volume 952.4 bbl TOC 0.0 ft Fluid Sequence Name Volume Ann. Len Top Density Rheology (bbl) (ft) (ft) (lb/gal) MUDPUSH II 100.0 0.0 10.10 k:2.54E-2 Ibf.s^n/ft2 n:0.420 Ty:13.04 Ibf/100ft2 ASL Load 2 449.7 1784.0 0.0 10.70 k:5.10E-4 lbf.s^n/ft2 n:0.962 Ty:12.45 Ibf/100ft2 LiteCRETE Load 4 66.7 500.0 1784.0 12.50 k:1.40E-3 Ibf.s^n/ft2 n:0.993 Ty:21.43 Ibf/100ft2 Mud 336.0 0.0 9.50 k:8.28E-2 lbf.s^n/ft2 n:0.262 Ty:0.48 lbf/100ft2 Static Security Checks: Frac 3 psi at 160.0 ft Pore 19 psi at 160.0 ft Collapse 2023 psi at 2244.0 ft Burst 5020 psi at 0.0 ft Csg.Pump out 51 ton Check Valve Diff Press 172 psi Page 5 sp23-n3 v2 8-24-11.cfw;08-24-2011; LoadCase Surface Casing,Version wcs-cem462_12 Client : Eni Petroleum Well : SP23-N3 Schlumberger String : 13.375 District : Prudhoe Bay,Alaska Country : USA Loadcase : Surface Casing CemCADE Client : Eni Petroleum Well : SP23-N3 String : 13.375"Surface Casing District : Prudhoe Bay,Alaska Country : USA ft lb/gal 8 9 10 11 12 13 I-Iydrostatic Mn.Hydrostatic -Max.Dynarric Mn.Dynarric - Frac - Pore S io 3 - C c> N U ' o O' O O M 06 Fluid Sequence Dynamic Well Security ■MUDPUSH II 100.0 bbl 10.10 lb/gal Herschel:k=2.54E-2 Ibf.s^n/ft2 n=0.420 Ty=13.04 Ibf/100ft2 3 ASL Load 2 449.7 bbl 10.70 lb/gal Herschel:k=5.10E-4 Ibf.s^n/ft2 n=0.962 Ty=12.45 Ibf/100ft2 LiteCRETE Load 4 66.7 bbl 12.50 lb/gal Herschel:k=1.40E-3 Ibf.s^n/ft2 n=0.993 Ty=21.43 Ibf/100ft2 ■Med 336.0 bbl 9.50 lb/gal Herschel:k=8.28E-2 Ibf.s^n/ft2 n=0.262 Ty=0.48 Ibf/100ft2 Total Depth = 2284.0 ft Top of Cement= 0.0 ft 'Mark of Schlumberger Schlunierger Page 6 sp23-n3 v2 8-24-11.cfw;08-24-2011; LoadCase Surface Casing;Version wcs-cem482_12 Client : Eni Petroleum Well : SP23-N3 Schlumberger String : 13.375 District : Prudhoe Bay,Alaska Country : USA Loadcase : Surface Casing Section 3: pumping schedule Start Job: Circulate Two Hole Volumes, Safety Meeting, Test Surface Equipment Pumping Schedule Name Flow Volume Stage Time Cum.Vol Inj. Comments Rate (bbl) (min) (bbl). Temp. (bbl/mi (degF) n) MUDPUSH II 5.0 100.0 20.0 100.0 80 Start Pumping Spacer Pause 0.0 0.0 5.0 0.0 80 Drop Bottom Plug ASL Load 2 5.0 449.7 89.9 449.7 80 Start Mixing Lead Slurry LiteCRETE Load 4 4.0 66.7 16.7 66.7 80 Start Mixing Tail Slurry Pause 0.0 0.0 5.0 0.0 80 Drop Top Plug Mud 8.5 306.0 36.0 306.0 80 Rig Pumps To Displace Mud 4.0 20.0 5.0 326.0 80 Slow down Mud 2.0 10.0 5.0 336.0 80 Slow down till plug lands Shut-In 0.0 0.0 5.0 0.0 80 Static period after Placement Total 03:02 952.4 bbl hr:mn End Job: Bump Top Plug, Bleed-off PSI, Check floats Dynamic Security Checks: Frac 2 psi at 160.0 ft Pore 9 psi at 160.0 ft Collapse 2022 psi at 2244.0 ft Burst 4818 psi at 0.0 ft Temperature Results BHCT 58 degF Simulated Max HCT 77 degF Simulated BHCT 77 degF Max HCT Depth 2284.0 ft CT at TOC 71 degF Max HCT Time 03:02:36 hr:mn:sc Static temperatures : At Time 00:02 hr:mn 00:05 hr:mn Geo.Temp. Top of Cement 71 degF 71 degF 60 degF Bottom Hole 76 degF 76 degF 37 degF Page 7 sp23-n3 v2 8-24-11.cfw;08-24-2011; LoadCase Surface Casing;Version wcs-cem462_12 Client : Eni Petroleum Well : SP23-N3 ScI�mM�rg String : 13.375 District : Prudhoe Bay,Alaska Country : USA Loadcase : Surface Casing ECD at the shoe: Depth= 2284 ft 0 Frac N_ Fore Hydrostatic - Dynamic tq 6 r � I CO 0Ca1 O 20 40 60 80 100 120 140 160 180 200 Time(min) ECD at the Conductor Shoe: Depth= 160 ft Fluids at 2284 ft CO cS- -Frac -Fbre Hydrostatic Dynamic O O5 ob Cai ^' 20 I O 40 60 80 100 120 140 160 180 200 Time (min) Page 8 sp23-n3 v2 8-24-11.cfw:08-24-2011; LoadCase Surface Casing,Version wcs-cem462_12 Client : Eni Petroleum Well : SP23-N3 Schlumberger String : 13.375 District : Prudhoe Bay,Alaska Country : USA Loadcase : Surface Casing BHCT Model: iii __ _ o Last Sack Depth N First Sack Depth -d Last Sack Terry. o First Sack Temp. .7 W O CD qp —O ilf 'Ei: vr k 1 n_ rtD Ir N IN N 0 20 40 60 80 100 120 140 160 180 200 Time (min) Surface Pressure: III Calc.CeHP �- m Calc.Pump Press. 1 1 q 1 N �--- 8- 1 1 - - C 0 20 40 60 80 100 120 140 160 180 200 Time (min) Page 9 sp23-n3 v2 8-24-11.cfw,08-24-2011, LoadCase Surface Casing,Version wcs-cem462_12 Client : Eni Petroleum Well : SP23-N3 Scrlimerger String : 13.375 District : Prudhoe Bay,Alaska Country : USA Loadcase : Surface Casing Returns Rate: Fluids at 2284 ft co- Q Out Qh f�- t0 i N 0 20 40 60 80 100 120 140 160 180 200 Time (min) Anullar Velocity: Depth= 2284 ft Annular Velocity 3 � I 0 20 40 60 80 100 120 140 160 180 200 Time (min) Page 10 sp23-n3 v2 8-24-11.cfw;08-24-2011; LoadCa se Surface Casing;Version wcs-cem462_12 Client : Eni Petroleum Well : SP23-N3 Schlumberger String : 13.375 District : Prudhoe Bay,Alaska Country : USA Loadcase : Surface Casing Section 4: fluid description Mud DESIGN Fluid No: 1 Density : 9.50 lb/gal Rheo. Model : HERSCHEL B. k : 8.28E-2 Ibf.s^n/ft2 At temp. : 65 degF n : 0.262 Ty : 0.481bf/100ft2 Gel Strength : 6.40 lbf/100ft2 MUD Mud Type :WBM Job volume : 336.0 bbl Water Type : Fresh VOLUME FRACTION Solids :4.0% Oil : 0.0% Water : 96.0% MUDPUSH II DESIGN Fluid No:2 Density : 10.10 lb/gal Rheo. Model : HERSCHEL_B. k : 2.54E-2 Ibf.s^n/ft2 At temp. : 65 degF n : 0.420 Ty : 13.04 lbf/100ft2 Gel Strength : (lbf/100ft2) Job volume : 100.0 bbl ASL Load 2 DESIGN Fluid No: 3 Density : 10.70 lb/gal Rheo. Model : HERSCHEL_B. k : 5.10E-4 Ibf.s^n/ft2 At temp. : 80 degF n :0.962 Ty : 12.45 lbf/100ft2 Gel Strength :82.66 lbf/100ft2 DESIGN BLEND SLURRY Name : B809 (100 lb Mix Fluid : 11.513 gal/sk Job volume :449.7 bbl Dry Density : 110.25 lb/ft3 Yield : 2.45 ft3/sk Quantity : 1032.29 sk Sack Weight : 100 lb Solid Fraction : 37.1 % BASE FLUID Type : Fresh water Density : 8.32 lb/gal Base Fluid : 11.513 gal/sk Page 11 sp23-n3 v2 8-24-11.cfw,08-24-2011, LoadCase Surface Casing,Version wcs-cem482_12 Client : Eni Petroleum Well : SP23-N3 Schlumberger String : 13.375 District : Prudhoe Bay,Alaska Country : USA Loadcase : Surface Casing LiteCRETE Load 4 DESIGN Fluid No:6 Density : 12.50 lb/gal Rheo. Model : HERSCHEL B. k : 1.40E-3 Ibf.s^n/ft2 At temp. : 70 degF n : 0.993 Ty :21.43 lbf/100ft2 Gel Strength :40.56 Ibf/100ft2 DESIGN BLEND SLURRY Name : D972 Mix Fluid : 5.472 gal/sk / Job volume :66.7 bbl Dry Density : 121.24 lb/ft3 Yield : 1.56 ft3/sk I Quantity :239.31 sk Sack Weight : 100 lb Solid Fraction : 53.3% BASE FLUID Type : Fresh water Density : 8.32 lb/gal Base Fluid : 5.472 gal/sk Additives Code Conc. Function D046 0.200%BWOB Antifoam D065 0.250%BWOB Dispersant D167 0.250%BWOB Fluid loss D153 0.100%BWOB Antisettling Annulus ID : 13.375 in-OD : 19.500 in CD to, • O M- a N `- z LiteCRETE Load 4 0 ASL Load 2 — MUDPUSHII LL — Mud D) 4.8 5.2 5.6 6.0 6.4 6.8 7.2 7.6 8.0 8.4 8.8 9.2 Flow Rate (bbl/min) Page 12 sp23-n3 v2 8-24-11.cfw,08-24-2011, LoadCase Surface Casing,Version wcs-cem462_12 Client : Eni Petroleum Well : SP23-N3 Schlumberger String : 13.375 District : Prudhoe Bay,Alaska Country : USA Loadcase : Surface Casing Section 5: centralizer placement Top of centralization :0.0 ft Bottom Cent. MD :2264.0 ft Casing Shoe :2284.0 ft NB of Cent. Used :34 NB of Floating Cent. :34 Centralizer Placement Bottom MD Nbr. Cent./ Cent. Name Code Min.STO @ Depth (ft) Joint (%) (ft) 1844.0 23 1/2 NW-TR-13 3/8-8-TR 3 W304 21.2 344.0 2284.0 11 1/1 NW-TR-13 3/8-8-TR 3 W304 65.1 1844.0 Centralizer Description Centralizer Tests Cent. Name Code Casing Max. Min.OD Rigid Origin Hole Size Running Restoring OD OD (in) (in) Force Force (in) (in) (lbf) (lbf) NW-TR-13 3/8-8-TR 3 W304 13 3/8 16.654 15.394 No Hannover 16.000 283.26 2832.59 (1)-Centralizer performance data is based on tests by WEATHERFORD as per the current API 10D specifications Running Force Calculations: Travelling Block Weight :33.0 ton Friction Factor Centralizer/Formation :0.40 Total Drag Force :8.4 ton Hook load Down Stroke :88.1 ton Hook load Up Stroke :104.9 ton ft 20 40 60 80 100 0 f — i 1-r tt tr- Betw een Cent. • •At Cent. 8 t: O tt iF Q � N J r Well Pipe Standoff Page 13 sp23-n3 v2 8-24-11.cfw;08-24-2011; LoadCase Surface Casing;Version wcs-cem462_12 Client : Eni Petroleum Well : SP23-N3 Schlumberger String : 13.375 District : Prudhoe Bay,Alaska Country : USA Loadcase : Surface Casing Section 6: WELLCLEAN II Simulator % % ft o 1 0 50 100 0 25 50 75 100 1 r li --c...., u_ —Std Betw.Cent. �j -Cement Coverage Mud Contarrination j A R Uncontarrinated Slurry N Fluid Sequence Cement Coverage Uncontaminated Slurry Fluids Concentrations Risk Mud on the Wall x° 1 i so - 4- r 0 0 El 0 200- _. -200 200 200 400- -400 400 400 600- -600 600 600 B00- -800 800 840 ^• ^ t C .• 1000- -1000 -. .. 1000 . 1000 n 1200- -1200 a c 1200 1200 a 0 1400- -1400 A a 1400 1400 A 1600- t -1600 1600 - 1600 1600- -1800 1800 1800 2000 2000 2000 2000 2200 zzoo zzo0 2200 r e g e g e es O Z 2 = Mud 1-1 ASL Load 2 III High 110 Loic I-I LiteCRETE Load 4 ii= MUDPUSH II Medium = None Page 14 sp23-n3 v2 8-24-11.cfw:08-24-2011, LoadCase Surface Casing:Version wcs-cem462_12 Client : Eni Petroleum Well : SP23-N3 Schlumberger String : 13.375 District : Prudhoe Bay,Alaska Country : USA Loadcase : Surface Casing Section 7: operator summary TOTAL MATERIAL REQUIREMENTS Additives Total Item Pack. Packaging Comments Quantity Quantity Name B809 103229 lb 1033 sack 100 lb D972 26078 lb 261 sack 100 lb D182 552 lb 23 sack 25 lb D047 20.0 gal 5 can 5.0 gal D031 9537 lb 87 sack 110 lb D046 53 lb 8 sack 50 lb D065 66 lb 2 sack 50 lb D167 66 lb 3 sack 251b D153 261b 2 sack 25 Ib Mix Water Requirements : Fresh water 17177 gal MIXING PREPARATION MUDPUSH II Volume : 100.0 bbl Density: 10.10 lb/gal Code Quantity Design Fresh water 92.046 bbl D182 552.278 lb 6.000 lb/bbl of base fluid D047 20.000 gal 0.200 gal/bbl of spacer D031 9536.741 lb 95.37 lb/bbl of spacer ASL Load 2 Volume :449.7 bbl Density : 10.70 lb/gal Yield :2.45 ft3/sk Dry Phase Liquid Phase Blend: 103229 lb Design Mix Water 283.0 bbl 10.0 bbl LAS Design B809(100 lb 103228.891 Fresh water 282.964 bbl 10.001 bbl lb LiteCRETE Load 4 Volume :72.7 bbl Density : 12.50 lb/gal Yield : 1.56 ft3/sk Dry Phase Liquid Phase Blend: (Ib) Design Mix Water 34.0 bbl 10.0 bbl LAS Design D972 26077.721 lb Fresh water 33.977 bbl 10.001 bbl D046 52.155 lb 0.200%BWOB D065 65.194 lb 0.250%BWOB D167 65.194 lb 0.250%BWOB D153 26.078 lb 0.100%BWOB Page 15 sp23-n3 v2 8-24-11.cfw,08-25-2011, LoadCase Surface Casing,Version wcs-cem462_12 Schlumberger CemCAD E*well cementing recommendation for 9-5/811 Intermediate Casing Operator : Eni Petroleum Well : SP23-N3 Country : USA Field : Nikaitchuq State : Alaska Prepared for : Mr.Luca Borri Location : Nabors 245E Proposal No. : Draft v2(P3) Service Point : Prudhoe Bay,Alaska Date Prepared : 8/24/2011 Business Phone : 907-659-2434 FAX No. : 907-659-2538 Prepared by : Mark Roos Phone : 907-748-7555 E-Mail Address : mroos@slb.com 4 • fiL 94URT E Disclaimer Notice: Schlumberger submits this document with the benefit of its judgment.experience,and good oilfield practices. This information is provided in accordance with generally accepted industry practice,relying on facts or information provided by others,limitations,computer models,measurements.assumptions and inferences that are not infallible. Calculations are estimates based on provided information.All proposals,recommendations,or predictions are opinions only. NO WARRANTY IS GIVEN CONCERNING ACCURACY OR COMPLETENESS OF DATA,INFORMATION PRESENTED.EFFECTIVENESS OF MATERIAL,PRODUCTS OR SUPPLIES,RECOMMENDATIONS MADE,OR RESULTS OF THE SERVICES RENDERED. Freedom from infringement of any intellectual property rights of Schlumberger or others is not to be inferred and no intellectual property rights are granted hereby. *Mark of Schlumberger Client : Eni Petroleum Well : SP23-N3 Schlumberger String : 9-5/8 District : Prudhoe Bay,Alaska Country : USA Loadcase : 9-5/8 Intermediate Casing(a) Section 1 : well description Configuration : Casing Stage : Single Rig Type : Land Mud Line : 0.0 ft Total MD : 6058.0 ft BHST : 70 degF Bit Size : 12 1/4 in ft (x 1000) psi G 0 1 2 3 =Silt stone_— , o Mil0 Sandstone r Frac ME III —Pore 0 o 0 cv o Coal 0 0 M .'. ••.-.Sandstone;;. 0 o II0 v wiermwmareo o o u� " " ■Sandstone t + o ■ o 0 CO 0 0 0 r-- Well Lithology Formation Press. Page 2 sp23-n3 v2 8-24-11.cfw,08-24-2011, LoadCase 9-5/8 Intermediate Casing(a) Version wcs-cem462_12 Client : Eni Petroleum Well : SP23-N3 Schlmohrger String : 9-5/8 District : Prudhoe Bay,Alaska Country : USA Loadcase : 9-5/8 Intermediate Casing(a) Previous String MD OD Weight ID (ft) (in) (lb/ft) (in) 2284.0 13 3/8 68.0 12.415 Landing Collar MD : 5978.0 ft Casing/liner Shoe MD : 6058.0 ft Casing/Liner MD OD Joint Weight ID Grade Collapse Burst Thread (ft) (in) (ft) (lb/ft) (in) (psi) (psi) 6058.0 9 5/8 40.0 40.0 8.835 L-80 2780 4920 HYD 563 Page 3 sp23-n3 v2 8-24-11.cfw,08-24-2011: LoadCase 9-5/8 Intermediate Casing(a),Version wcs-cem462_12 Client : Eni Petroleum Well : SP23-N3 SckIhrgcr String : 9-5/8 District : Prudhoe Bay,Alaska Country : USA Loadcase : 9-5/8 Intermediate Casing(a) Mean OH Diameter : 12.250 in Mean Annular Excess : 50.0 Mean OH Equivalent Diameter: 13.371 in Total OH Volume : 655.4 bbl (including excess) Max. Deviation Angle : 85 deg Max. DLS : 4.412 deg/100ft Directional Survey Data MD TVD Deviation Azimuth Dogleg Sev. (ft) (ft) (deg) (deg) (deg/100ft) 0.0 0.0 0.0 160.0 0.000 100.0 100.0 0.0 160.0 0.000 200.0 200.0 0.0 160.0 0.000 300.0 300.0 1.5 160.0 1.500 400.0 399.9 3.3 160.0 1.750 500.0 499.6 5.0 160.0 1.750 600.0 599.1 6.8 160.0 1.750 700.0 698.2 8.5 160.0 1.750 800.0 796.9 10.3 160.0 1.750 900.0 895.0 12.0 160.0 1.750 1000.0 992.5 13.8 160.0 1.750 1100.0 1089.2 15.5 160.0 1.750 1200.0 1185.2 17.3 160.0 1.750 1300.0 1280.2 19.0 160.0 1.750 1377.7 1353.4 20.4 160.0 1.750 1400.0 1374.3 20.5 160.0 0.494 1500.0 1467.8 21.0 160.0 0.500 1600.0 1561.0 21.5 160.0 0.500 1700.0 1653.9 22.0 160.0 0.500 1800.0 1746.5 22.5 160.0 0.500 1900.0 1838.7 23.0 160.0 0.500 1915.9 1853.4 23.0 160.0 0.502 2000.0 1930.0 25.7 166.2 4.404 2100.0 2018.7 29.2 172.1 4.396 2200.0 2104.3 32.9 176.8 4.398 2283.7 2173.4 36.1 180.0 4.403 2300.0 2186.5 36.7 180.6 4.412 2400.0 2264.5 40.6 183.8 4.399 2500.0 2338.1 44.6 186.6 4.396 2600.0 2406.8 48.7 188.9 4.401 2648.9 2438.5 50.7 190.0 4.403 2700.0 2470.9 50.7 190.0 0.000 2784.4 2524.4 50.7 190.0 0.000 2800.0 2534.3 50.4 190.8 -4.375 2900.0 2599.3 48.6 196.1 -4.399 3000.0 2666.4 47.1 201.6 -4.402 3100.0 2735.3 45.9 207.5 -4.398 3200.0 2805.5 44.9 213.5 -4.404 3300.0 2876.6 44.3 219.7 -4.395 3400.0 2948.3 44.1 226.0 -4.400 3500.0 3020.0 44.2 232.4 4.403 3600.0 3091.4 44.7 238.6 4.396 3700.0 3162.1 45.4 244.7 4.399 3800.0 3231.6 46.5 250.6 4.403 3900.0 3299.5 47.9 256.3 4.401 4000.0 3365.4 49.6 261.8 4.399 4100.0 3429.0 51.5 266.9 4.398 4200.0 3489.8 53.6 271.8 4.401 Page 4 sp23-n3 v2 8-24-11 cfw,08-24-2011, LoadCase 9-5/8 Intermediate Casing(a),Version wcs-cem462_12 Client : Eni Petroleum Well : SP23-N3 Schlumberger String : 9-5/8 District : Prudhoe Bay,Alaska Country : USA Loadcase : 9-5/8 Intermediate Casing(a) Directional Survey Data MD TVD Deviation Azimuth Dogleg Sev. (ft) (ft) (deg) (deg) (deg/100ft) 4300.0 3547.5 55.9 276.4 4.404 4400.0 3601.8 58.4 280.7 4.397 4500.0 3652.3 61.0 284.8 4.404 4600.0 3698.7 63.7 288.7 4.396 4700.0 3740.9 66.5 292.5 4.404 4800.0 3778.4 69.4 296.0 4.399 4900.0 3811.1 72.4 299.4 4.396 5000.0 3838.8 75.4 302.8 4.406 5100.0 3861.4 78.5 306.0 4.396 5200.0 3878.7 81.6 309.1 4.400 5300.0 3890.6 84.8 312.3 4.404 5308.1 3891.3 85.0 312.5 4.367 5400.0 3899.3 85.0 312.5 0.000 5500.0 3908.0 85.0 312.5 0.000 5600.0 3916.7 85.0 312.5 0.000 5700.0 3925.4 85.0 312.5 0.000 5800.0 3934.2 85.0 312.5 0.000 5900.0 3942.9 85.0 312.5 0.000 6000.0 3951.6 85.0 312.5 0.000 6008.1 3952.3 85.0 312.5 0.000 6058.0 3956.6 85.0 312.5 0.000 Formation Data MD Frac. Pore Name Lithology (ft) (lb/gal) (lb/gal) 753.0 11.00 8.43 SV-4 Siltstone 1132.0 11.20 8.43 SV-3 Sandstone 1404.0 11.50 8.43 SV-2 Siltstone 1847.0 12.00 8.43 Permafrost Base Shale 1933.0 11.80 8.43 SV-1 Sandstone 2284.0 12.50 8.43 Surf. Csg Shoe Shale 2285.0 12.30 8.43 Ugnu Top(UG4) Coal 3116.0 12.30 8.43 UG-2 Coal Bed Coal Marke 3979.0 12.50 8.43 Lower Ugnu Sandstone 4647.0 12.50 8.43 Schrader Bluff Shale 4779.0 12.50 8.43 N Seq Top Sandstone 4917.0 12.50 8.43 N Sand Top Sandstone 5061.0 12.50 8.43 N Sand Bottom Sandstone 5512.0 12.50 8.43 N Seq Base Sandstone 5941.0 12.50 8.43 OA Sand Top Shale 5941.0 12.50 8.43 OA sbl 2 Sandstone 6058.0 12.50 8.43 TD Sandstone Page 5 sp23-n3 v2 8-24-11.cfw,08-24-2011, LoadCase 9-5/B Intermediate Casing(a),Version wcs-cem462_12 Client : Eni Petroleum Well : SP23-N3 Schlumberger String : 9-5/8 District : Prudhoe Bay,Alaska Country : USA Loadcase : 9-5/8 Intermediate Casing(a) Geothermal Temperature Profile MD TVD Temperature Gradient (ft) (ft) (degF) (degF/100ft) 0.0 0.0 60 0.0 1847.0 1789.9 32 -1.6 2285.0 2174.4 37 -1.1 6058.0 3956.6 70 0.3 degF 30 35 40 45 50 55 60 65 70 75 80 85 I I mi Annulus -Tubular Fluids - Geoth.Profile Temp. Profile At 130 min Page 6 sp23-n3 v2 8-24-11,cfw,08-24-2011, LoadCase 9-5/8 Intermediate Casing Ca),Version wcs-cem462_12 Client : Eni Petroleum Well : SP23-N3 Schlumhergur String : 9-5/8 District : Prudhoe Bay,Alaska Country : USA Loadcase : 9-5/8 Intermediate Casing(a) Section 2: fluid sequence Job Objectives: Zonal Isolation,TOC @ 10,497'(1,000'above the"N"Top) Original fluid Mud 9.40 lb/gal k : 5.97E-3 Ibf.s^n/ft2 n : 0.616 Tv : 8.86 Ibf/100ft2 Displacement Volume 453.3 bbl Total Volume 708.5 bbl TOC 3917.0 ft Fluid Sequence Name Volume Ann. Len Top Density Rheology (bbl) (ft) (ft) (lb/gal) MUDPUSH II 70.0 836.6 3080.4 10.50 k:5.23E-2 Ibf.s^n/ft2 n:0.324 Ty:12.92 Ibf/100ft2 LiteCRETE Load 4 185.2 2141.0 3917.0 12.50 Pv:168.266 cP Ty:26.14 Ibf/100ft2 Mud 453.3 0.0 9.40 k:5.97E-3 lbf.s^n/ft2 n:0.616 Tv:8.86Ibf/100ft2 Static Security Checks: Frac 328 psi at 2285.0 ft Pore 110 psi at 2284.0 ft Collapse 2485 psi at 5978.0 ft Burst 4920 psi at 0.0 ft Csg.Pump out 63 ton Check Valve Diff Press 137 psi Page 7 sp23-n3 v2 8-24-11.cfw,08-24-2011, LoadCase 9-5/8 Intermediate Casing la),Version wcs-cem482_12 Client : Eni Petroleum Well : SP23-N3 Schlumherger String : 9-5/8 District : Prudhoe Bay,Alaska Country : USA Loadcase : 9-5/8 Intermediate Casing(a) * CemCADE Client : Eni Petroleum Well : SP23-N3 String :9-5/8"Intermediate Casing District : Prudhoe Bay,Alaska Country : USA ft lb/gal 8 9 10 11 12 13 o- I I I I —Hydrostatic -Mn.Hydrostatic o - Max.Dynamc $- —Mn.Dynamic — Frac p - Fore —, tV E 3 0— p � 1 O U 1 / \ O_ U g O a - N o 0 3 Fluid Sequence Dynamic Well Security • ■MUDPUSH II 70.0 bbl 10.50 lb/gal Herschel:k =5.23E-2 lbf.s^n/ft2 n =0.324 Ty=12.92 Ibf/100ft2 Ft r LitecRETE Load 4 185.2 bbl 12.50 lb/gal Bingham P/=168.266 cP Ty=26.14 Ibf/100ft2 ■Mud 453.3 bbl 9.40 lb/gal Herschel:k =5.97E-3 bf.s^n/ft2 n =0.616 Ty=8.86 Ibf/100ft2 Total Depth = 6058.0 ft Top of Cement= 3917.0 ft *Mark of Schlumberger SChdi QPM Page 8 sp23-n3 v2 8-24-11.cfw,08-24-2011; LoadCase 9-5/8 Intermediate Casing lal;Version wcs-cem462_12 Client : Eni Petroleum Well : SP23-N3 Schlmn rgcr String : 9-5/8 District : Prudhoe Bay,Alaska Country : USA Loadcase : 9-5/8 Intermediate Casing(a) Section 3: pumping schedule Start Job: Circulate Two Hole Volumes, Safety Meeting, Test Surface Equipment Pumping Schedule Name Flow Volume Stage Time Cum.Vol In). Comments Rate (bbl) (min) (bbl). Temp. (bbl/min) (degF) MUDPUSH II 5.0 70.0 14.0 70.0 80 Spacer Ahead Pause 0.0 0.0 3.0 0.0 80 Drop Bottom Plug Pause 0.0 0.0 3.0 0.0 80 Begin Mixing Slurry LiteCRETE Load 4 5.0 185.2 37.0 185.2 80 Mix&Pump Cement Slurry(3 to 7 BPM) Pause 0.0 0.0 5.0 0.0 80 Drop Top Plug Mud 8.0 453.3 56.7 453.3 80 Kick-Out Plug Pause 0.0 0.0 5.0 0.0 80 Swap to Rig Pumps Pause 0.0 0.0 5.0 0.0 80 Pressure Test Casing Shut-In 0.0 0.0 1.0 0.0 80 Bleed off/Check Floats Total 02:08 708.5 bbl hr:mn End Job: Bump Top Plug, Bleed-off PSI, Check floats Dynamic Security Checks: Frac 260 psi at 2285.0 ft Pore 110 psi at 2284.0 ft Collapse 2411 psi at 443.8 ft Burst 4530 psi at 0.0 ft Temperature Results BHCT 75 degF Simulated Max HCT 72 degF Simulated BHCT 64 degF Max HCT Depth 0.0 ft CT at TOC 64 degF Max HCT Time 01:58:42 hr:mn:sc Static temperatures: At Time (hr:mn) 00:01 hr:mn Geo.Temp. I Top of Cement (degF) 64 degF 158 degF Bottom Hole (degF) 64 degF 70 degF Page 9 sp23-n3 v2 8-24-11.cfw,08-24-2011, LoadCase 9-5/8 Intermediate Casing Cal:Version wcs-cem462_12 Client : Eni Petroleum Well : SP23-N3 Schlumberger String : 9-5/8 District : Prudhoe Bay,Alaska Country : USA Loadcase : 9-5/8 Intermediate Casing(a) ECD simulation at casing shoe: O Depth= 6058 ft '- � U) I O I Frac Pore Hydrostatic Dynamic � I O_ 1:5 ; � III OII ‘c-5 � I OTOi I i Lg� O co E 0 20 40 60 80 100 120 140 Time (min) ECD simulation at previous casing shoe: o Depth= 2284 ft Fluids at 6058 ft cif Frac Fore Hydrostatic Dynamic O O O O od- 1 O 0 20 40 60 80 100 120 140 Time (min) Page 10 sp23-n3 v28-24-11.ctw;08-24-2011; LoadCase 9-5/8 Intermediate Casing(a);Version wcs-cem462_12 Client : Eni Petroleum Well : SP23-N3 Schlumberger String : 9-5/8 District : Prudhoe Bay,Alaska Country : USA Loadcase : 9-5/8 Intermediate Casing(a) Temperature model: ES o Last Sack Depth Ea- First Sack Depth Last Sack Temp. �p First Sack Temp. - fc- Rp_ -N W n C R obi kin �y8, 0 20 40 60 80 100 120 140 Time(min) Surface pressure: Calc.CemHP -Calc.Pump Press. i Q O \... N 8_1411%*%•-• /_. _\O , 0 20 40 60 80 100 120 140 Time (min) Page 11 sp23-n3 v2 8-24-11.cfw:08-24-2011; LoadCase 9-5/8 Intermediate Casing(a):Version wcs-cem462_12 Client : Eni Petroleum Well : SP23-N3 Sekierger String : 9-5/8 District : Prudhoe Bay,Alaska Country : USA Loadcase : 9-5/8 Intermediate Casing(a) Returns rate: Flcs) uids at 6058 ft_ _ co- 0 Out Oh • r`- r...*.%%....-----N.. t0- 1" 8 IL -----r---....\, M- N- 0 20 40 60 80 100 120 140 Time (min) Anullar velocity: 8 Depth= 6058 ft 8- Annular Velocity 8- r.. ."---- \%. I R- .E8 1 t 8- ; I R- Oi , T n 0 20 40 60 80 100 120 140 Time (min) Page 12 sp23-n3 v2 8-24-11.cfw;08-24-2011; LoadCase 9-5/8 Intermediate Casing(a(;Version wcs-cern462_12 Client : Eni Petroleum Well : SP23-N3 Schlumberger String : 9-5/8 District : Prudhoe Bay,Alaska Country : USA Loadcase : 9-5/8 Intermediate Casing(a) Section 4: fluid description Mud DESIGN Fluid No: 1 Density :9.40 lb/gal Rheo. Model : HERSCHEL_B. k : 5.97E-3 Ibf.s^n/ft2 At temp. : 80 degF n :0.616 Ty :8.86lbf/100ft2 Gel Strength : 32.02 lbf/100ft2 MUD Mud Type :WBM Job volume :453.3 bbl Water Type : Fresh VOLUME FRACTION Solids : 6.0% Oil : 1.0% Water : 93.0% MUDPUSH II DESIGN Fluid No:2 Density : 10.50 lb/gal Rheo. Model : HERSCHEL_B. k : 5.23E-2 Ibf.s^n/ft2 At temp. : 65 degF n :0.324 Ty : 12.92 lbf/100ft2 Gel Strength :40.56 Ibf/100ft2 Job volume :70.0 bbl LiteCRETE Load 4 DESIGN Fluid No: 7 Density : 12.50 lb/gal Rheo. Model : BINGHAM Pv : 168.266 cP At temp. : 50 degF Ty :26.14 Ibf/100ft2 Gel Strength : 57.01 Ibf/100ft2 DESIGN BLEND SLURRY Name : D972 Mix Fluid : 5.471 gal/sk Job volume : 185.2 bbl Dry Density : 121.24 Ib/ft3 Yield : 1.56 ft3/sk Quantity :664.51 sk Sack Weight : 100 lb Solid Fraction : 53.3% BASE FLUID Type : Fresh water Density : 8.32 lb/gal Base Fluid : 5.471 gal/sk Additives Code Conc. Function D167 0.250%BWOB Fluid loss D046 0.200%BWOB Antifoam D065 0.250%BWOB Dispersant D153 0.100%BWOB Antisettling Page 13 sp23-n3 v2 8-24-11.cfw,08-24-2011, LoadCase 9-5/8 Intermediate Casing(a),Version wcs-cem462_12 Client : Eni Petroleum Well : SP23-N3 Schlumberger String : 9-5/8 District : Prudhoe Bay,Alaska Country : USA Loadcase : 9-5/8 Intermediate Casing(a) Section 5: centralizer placement Top of centralization :3000.0 ft Bottom Cent. MD :5958.0 ft Casing Shoe :6058.0 ft NB of Cent. Used :23 NB of Floating Cent. :23 Centralizer Placement Bottom MD Nbr. Cent./ Cent. Name Code Min.STO @ Depth (ft) Joint (%) (ft) 4417.0 0 0/0 0.0 4412.7 5217.0 20 1/1 HYDROFORM HFD 0.0 5199.3 5858.0 0 0/0 0.0 5217.0 6058.0 5 1/1 HYDROFORM HFD 0.0 6058.0 Centralizer Description Centralizer Tests Cent.Name Code Casing Max. Min.OD Rigid Origin Hole Size Running Restoring OD OD (in) (in) Force Force (in) (in) (lbf) (lbf) HYDROFORM HFD 9 5/8 12.252 12.252 Yes Weatherford(u N.A. N.A. N.A. (1)-Centralizer performance data is based on tests by WEATHERFORD as per the current API 10D specifications % ft 0 20 40 60 80 100 ---> -- - I -_.. i - I } J M Betty een Cent. - • sAt Cent. V 1:- I iI l 11 0 I Well Pipe Standoff Page 14 sp23-n3 v2 8-24-11.ctw;08-24-2011; LoadCase 9-5/8 Intermediate Casing(al,Version wcs-cem462_12 Client : Eni Petroleum Well : SP23-N3 Schlumberger String : 9-5/8 District : Prudhoe Bay,Alaska Country : USA Loadcase : 9-5/8 Intermediate Casing(a) Section 5: WELLCLEAN II Simulator °i° °r° ft 025 50 75 100 0 25 50 75 100 I I - + L."''''''''7 . . Iii Std Betw.Cent. Mud Contamination i _ Cement Coverage Uncontarrinated Slurry Fluid Sequence Cement Coverage Uncontaminated Slurry Fluids Concentrations Risk Mud on the Wall z° 4. 1 z° 4. 3000 4 1 -3000 3000J 1 -3000 3500- -3500 3500- -3500 r` i 't i,...,- 4000- -4000 40001 1 t_-4000 s 4500- -4500 -r s 4500- - -4500 -t o a n o r o r 0 O U 0 5000- -5000 5000- -5000 5500- II -5500 5500- -5500 6000-I t -6000 6000-I 1÷ i-z-2 -6000 • • • ; • z z = Mud = High Lov, I I LiteCRETE Load 4 1-7 Medium I I None 1----1 MUDPLISH II r :Ir i5 sp23-n3 v2 0-24-11.cfw;08-24-2011; LoadCase 9-5/8 Intermediate Casing(a).Version wcs-cem462_t2 Client : Eni Petroleum Well : SP23-N3 Scbibrgcr String : 9-5/8 District : Prudhoe Bay,Alaska Country : USA Loadcase : 9-5/8 Intermediate Casing(a) Section 7: operator summary TOTAL MATERIAL REQUIREMENTS Additives Total Item Pack. Packaging Comments Quantity Quantity Name D972 66451 lb 665 sack 100 lb D182 382 lb 16 sack 251b D046 146 lb 3 sack 50 lb D031 8199 Ib 75 sack 110 lb D167 1661b 7 sack 25lb D065 1661b 4 sack 501b D153 661b 3 sack 251b Mix Water Requirements : Fresh water 6313 gal MIXING PREPARATION MUDPUSH II Volume :70.0 bbl Density: 10.50 lb/gal Code Quantity Design Fresh water 63.747 bbl D182 382.481 lb 6.000 lb/bbl of base fluid D046 12.749 lb 0.200 Ib/bbl of base fluid D031 8198.954 lb 117.13 lb/bbl of spacer LiteCRETE Load 4 Volume : 185.2 bbl Density : 12.50 lb/gal Yield : 1.56 ft3/sk Dry Phase Liquid Phase Blend: 66983 lb Design Mix Water 86.6 bbl 10.0 bbl LAS Design D972 66451.305 lb Fresh water 86.569 bbl 10.001 bbl D167 166.128 lb 0.250%BWOB D046 132.903 lb 0.200%BWOB D065 166.128 lb 0.250%BWOB D153 66.451 lb 0.100%BWOB Page 16 sp23-n3 v2 8-24-11 cfw,08-25-2011 LoadCase 9-5/8 Intermediate Casing(a):Version wcs-cem462_12 410* ENI S.p.A. SPEO IDENTIFICATION CODE PAG 206 OF 338 Eni E&P Division REVISION STAP-P-1-M-6140 0 1 15. LEAK OFF TEST PROCEDURE A Leak-Off Test (LOT) will be performed On Wild-Cat wells at each casing shoe after setting the surface casing. LOTs are also recommended to be carried out on both appraisal and development wells. Leak Off Test and Formation Integrity Test (FIT), also termed the Limit Test, are for formation strength pressure tests made just below the casing seat prior to drilling ahead. These tests are carried out to: • Investigate the cement seal around the casing shoe which should be at least as high as the predicted fracture pressure for the area. • Investigate the wellbore capability to withstand pressures below the casing shoe in order to allow proper well planning with regard to the setting depth of the next casing, mud weights and alternatives during well control operations. • Collect regional information on formation strengths and stress magnitude for different applications including optimisation of future well planning, hole stability analysis and modelling, reservoir application. Prior to a test, a decision should be made to either increase the pressure until leak off occurs (as in the LOT) or to stop at a predetermined pressure for a (FIT). It should be noted that: • FIT does not obtain information on stress magnitude. • A LOT is designed and should be performed to determine, in a better way, the desired data without breaking down the formation. When a Formation Integrity Test is required, the maximum pumping pressure is often expressed in terms of'Equivalent Mud Weight' (EMW): Imperial units EMW= - +MW 0.052 x TVD where: P = Pumping Pressure (psi) TVD = True Vertical Depth (ft) MW = Actual Mud Weight (PPG) Metric units EMW — Px10 + MW TVD where: P = Pumping Pressure (kg/cm2) TVD = True Vertical Depth (m) MW = Actual Mud Weight (kg/I). ENI S.p.A. SPEO IDENTIFICATION CODE PAG 207 OF 338 En11 E&P Division REVISION STAP-P-1-M-6140 0 1 LOTts or FITs can be carried out in any open hole section and at any time while drilling the hole, even if it is customary to have it performed some metres (6-15 metres) below the casing. For instance, the casing seat can be in a shale and the first sand formation may be encountered several hundred feet deeper. This will certainly be more permeable than the shale, and a test can be performed to ascertain the maximum pressure this sand can hold. If it is lower than the shale just below the casing seat, this sand becomes the limiting factor. Note Information obtained from leak-off tests in straight holes is not applicable to deviated holes in the same field and vice versa. 15.1 TEST PROCEDURE Prior to performing a formation strength test, prepare a sheet of graph paper to record pressure, versus cumulative mud volume. 1) Drill out the float equipment, clean the rat hole and drill 5m of new hole. 2) Circulate a mud quantity equal to the internal string volume plus the new hole plus 50m internal casing volumes. This mud shall be cleaned and conditioned to the density and filtrate as indicated in the Mud Programme to be used for the next drilling phase. 3) Pull the bit back into the casing shoe. 4) Rig up the cementing unit to the drill pipe. The unit shall be equipped with high precision, low pressure gauges. The range of the pressure gauge shall be selected based on the actual mud weight and the estimated (LOT) or predetermined (FIT) pressure. A pressure recorder should be used during the test. The use of the rig pumps for making these tests is unsuitable. 5) Fill and test the lines with mud. 6) Break circulation with the cementing unit to make sure that the bit nozzles are clear. Stop pumping when circulation is established. 7) Close the top pipe rams or the annular. 8) In surface well head both flanged and multistage wellheads, open the annulus of the previous casings. In sub sea well head pay attention to not excide the burst pressure of the previous casing. 9) Pump slowly and in continuous way, until pressure builds up to approximately half the anticipated maximum surface pressure. 10) Once pressure is established, pump uniform volumes of mud and wait for the time required for the pressure to stabilise. The flow rate range is from 1/8 bbl/min (20 1/min) up to a maximum of 1 bbl/min (160 I/min), however values of 0.25 bbl (121/4" and smaller holes) or 0.50 bbl (171/2" hole) are commonly used. 11) Note the cumulative mud volume pumped, the final pumping and final static pressure. 12) Repeat steps (9) and (10) above and plot pressure versus cumulative mud volume for each increment of pumped volume. ENI S.p.A. SPEO IDENTIFICATION CODE PAG 208 OF 338 Eni E&P Division REVISION STAP-P-1-M-6140 0 1 13) Continue this procedure until: • Two or three points on the plot are reached where the pressure deviates and falls below the approximate straight line (or if the pressure does not increase with the injected volume). The point on the plot where the curve begins to bend away from the straight line is called Leak Off Point (Refer to t-figure 15-1) • Or the predetermined test pressure is reached. 14) Stop pumping, shut in the well, record and plot pressure versus time until stabilisation (usually it takes 15-20min). In the early stage (2-3min) one value every 15-30sec should be collected while for the remaining a value of pressure every 30- 60sec may be sufficient. The use of PACR or an equivalent device, if available, is preferred. 15) Bleed off the pressure and record the quantity of fluid returned into the cementing unit. Compare it to the volume used for the test to obtain the amount of fluid lost to the formation. 16) Open the BOP and calculate the formation strength in terms of 'Equivalent Mud Weight' using the lowest between leak off point pressure and stabilised pressure. 17) Collect the data recorded during the test in a data sheet together with the following information: borehole diameter, depth of test, depth and type of the last casing, mud density, plastic viscosity, filtrate and gels (refer to the example on the next page). Note: The LOT pressure doesn't exceed the pressure which the casing was tested. Note: When a good zonal isolation behind the casing is imperative, the Leak- off test should be carried out with a retrievable packer to avoid pressurising the casing which may cause possible permanent damage to the cement bond by the creation of micro annuli in the cement. Note: The pumping rate should be kept within the limits described in step 9). If the rate is too low, filtration losses will mask any leakage loss, or, if the rate is too high the formation may suddenly break and the leak off pressure will not be determined. Also, the longer the open hole section, the higher should be the injection rate. If the initial pumping rate is not sufficient, the well should be depressurized and the test restarted with a higher rate. Note: If a float valve is used in the drilling string, the test can not be carried out by pumping down the drill pipe. In this case rig up the cementing unit to the choke or kill line, fill and test the lines against the fail-safe and establish circulation through the riser. Close the BOP and perform the formation strength test pumping down the annulus. ENI S.p.A. SPEO IDENTIFICATION CODE PAG 209 OF 338 End E&P Division REVISION STAP-P-1-M-6140 0 1 [bill% LEAK-OFF TEST REPORT Reportkr Date: WELL NAME: WELL CODE: CONTRACTOR: RIG NAME: RIG CODE: Open hole depth(m). 825 Mud Type: FWGELS RigtWe: J.UPs Hole CI amete r(in): 12 114 Weight(KgA): 1.3 R.K.B.elevation(m): 26 Last Csg.Shoe(m): 797 Marsh Vscosity(sec/Ot): 44 Water Depth(m): 24 Csg.diameter 0n): 131/8 P.V.(cps): 19 Pumps: 12-P-160 Grade: J.55 Y.P.Qb/100 ft'): 6 Liners(in): 6.5 Weight Obit): 61 GelsQb/100 e): 218 Flow Rate(bpi): 0.25 Max.Burst pres(psi): 3103 W.L(oc 30 min): 10.5 Litholog y Shale Expected EMW 1.68 Kg/cm2/10 m Time Volume Pressure Time Volume Pressure Time Volume Pressure (min) (bbl) (Psi) (min) (bbl) (Psi) (min) (bbl) (Psi) 1 025 50 9 2 490 16 2 435 2 D50 100 95 2 480 3 0.75 200 10 2 470 4 100 300 10.6 2 463 5 125 400 11 2 465 6 150 500 11.5 2 460 7 1.75 570 12 2 446 8 200 600 13 2 440 8 2.00 550 14 2 437 8.5 2D0 505 15 2 435 Nde• Pumped with a constant low rate of(bbl): \flume pumped(bbl): Volume retuned(bbl): (pw) 1000 900 • 800 stop pump r 700 ` e 600 - shut in curve S 500 , U 400 - r 8 minutes e 300 - 200 • 100 • 0 . . . . . 0 0,25 0,5 0,75 1 1,25 1,5 1,75 / 1 2 3 4 5 6 7 8 9 10 11 12 Cumulative Volume(bbl) 4 Ir. Time mins RESULTS:(Press..,.+Press.is,)x1 DmDepth=[(1.3 x 797 110)+(430 x 0.07)]x 10/797=1.68(Kg/cm2/10 m) Note: . I Company Re presentathe Figure 15-1 - Leak-Off Test Report REv DATE BY CX APP PEgRIPTION REVI DA1E BY CK APP DESCRIPTION 10:1'C DHS CC CC Pit,c1 Drcwi.r I VICINITY MAP SCALE: 1'° = 2 Miles o N 4.. 57 I sl 21 22 23 _4 'q c' I 23 '4 19 20 2' . THIS . - - - 26 Ir6 L, 30 P SURVEY 2s 30 29 PE 2; .: 1 Y tl A:S.P. NADAS, rd 3'3 3E 31 32 33 iti tib 'Alacc 31 3: 5i lT14.4 # 114N T13N I T13N 3 2 WJKTI71t Pd r PARK 3 t 7 1 3 1 iAj e it .4 • t, Ip-k CI ��nw ,,, to N\ 14 , Ili Co ilib l' 1 `J '�, D 30 \wit Ct'3 a , if 21) 28 27 a 05-3M OS-�3M.i I, :. 14' 6 . U »1-1 1 1 rMP c\....77 IAN 14 'gill' .. i - rij 'ilk 3 %, 36 14 ,, . 3n r= TNI :' 1 5._.. ,< , 'y rlD y�'S . DRAWING NOTES: YY Y 1 / 1. GRID COORDINATES SHOWN ARE ALAKA STATE PLANE, ZONE 4, NAD83. DISTANCES SHOWN ARE TRUE HORIZONTAL DISTANCES. 2. GEODETIC COORDINATES SHOWN ARE NAD83. 3. BASIS OF LOCATION DERIVED FROM CPS STATIC OBS. PROCESSED INTO OPUS SOLUTIONS. 4. CONDUCTORS ARE LOCATED WITHIN PROTRACTED SECTION 19, TO'MdSHIP 14 NORTH. RANGE 9 EAST. UMIAT MERIDIAN. S. ELEVATIONS SHOWN ARE B.P.M.S.L. DATUM. 6. ALL SECTIONS SHOWN AND/OR REFERENCED IN THIS DRAWING ARE 'PROTRACTED SECTIONS'. 7. REFERENCE LOUNSBURY DOCUMENT E-087 OR COORDINATE VALUES IN NA027. • SURVEYOR'S CERTIFICATE • 4, % ,'� 14 49th f HEREBY CERTIFY THAT I AM PROPERLY REGISTERED AND 0 7�"--- ,� t e/ LICENSED TO PRACTICE LAND SURVEYING IN THE STATE OF /` l::i'�Ofs:: r'" n.:4�..i► ALASKA AND THAT THIS PLAT REPRESENTS A SURVEY r r"01 101 J. CORNING DONE BY ME OR UNDER MY DIRECT SUPER WSION AND 00 's LS-10685 i THAT ALL DIMENSIONS AND OTHER DETAILS ARE CORRECT ‘1411; �� • AS OF OCTOBER 01, 2010$71/14/ .411"&s..1. . " �•••.►a/rL-f7plf '' *� &s0 ➢ SPY ISLAND DRILL SITE g, `'� WELL CONDUCTORS •� Y AS—BUILT LOCATIONS 211 1111n `k.�ti� ' CAD FILE:ENI3M3D9 us ®peI� i�ng DA DRAWING NO:o/o,,2D,D Eni-3543--d9 IPAR1'OF 31RE0 REV DATE BY CK PPP DESCRIPTION REV DATE BY CK _ APP DESCRIPTION rl 'IC/( /'L' ).'S CC: CC ^i: c :,,cw r,c NI + r- see-f- e a 4 p��C` pec 18 Set 1 1 S , y SW. 3p `D W`'„_ A NnD63, t<. f o _°° 0) 4- N --I 000000 03 DETAIL A. SCALE: 1"=80' SpµDBAGf (7 G,gpytEl SNO)u) 1 L` ` + Y ��� C3" Y r 'as DETA'L A ( S�I.G L SPY ISLAND DRILL SITE (SID) 1 Gf�A'IE► 54h011L0E" , i / ...---__ _---— \Ns"— i.No$P ct LEGENC SCALE 20C C 'DO 200 0 = W'EL_ CONDUCTOR AS-BUILT THIS SURVEY 1 1" = 200' { fj* f�"��6q c SPY ISLAND DRILL SITE WELL CONDUCTORS q ' AS—BUILT LOCATIONS @Cll 11 '1t. CPD FILE FN:1543L 3 us op iratOrnl� DATE1C/01/2010 DRAWING NO: Eni-3543—d9 1PA2:OF 310 i<%Y, JAR HY CK AP? -.__.._..gS01,pPTION Rpt' PATE i. BY CK AND rv.s 21PT1oV l L,, ., 5 t.._ [[2_,,,.. w Drcng 1 , - Protracted Section 19, T. 14 N., R. 9 E., Umiat Meridian Alaska State Plane,NAD83 GRID NAD83 Geographic I Section Line Off set Pad Well No. 'Y' 'X' _atitude (N) longitude (WJ _ F.N.L F.E I Flev I (US ft.) (US ft.) -1- 6053423.20 1651769.82 70°33'27.209" 149"5.4'74.765" 797 1171 12.4 i 2 6053421.65 1651761.87 70033'27,194" 149054'25.000" 798 1179 i 12.4 i3 6053420.07 1651754.10 70°33'27.179" 149°54'25.229" 800 1186 I 12.4 I I 4 6053418.56 1651746.17. 70°33'27.164" 149°54'25.463" 801 1194 12.4 5 6053417.03 1651738.44 70033'27.149" '149°54'25.692" 803 1202 12.4 6 6053415.54 1651730.54 70033127.134" 149°54'25.925" 804 121012.4 7 6053412.44 1651714.77 70°33'27.104" 149°54'26.391" 80/ 1226 12.4 8 6053410.91 1651706.96 70°33'27.089" 149°54'26.622" 809 1234 12.4 9 6053409.39 1651699.11 70033127.074" 149054'26.853" 810 1241 12.4 10 6053407.94 1651691.31 10033'27.060" 149"54'27.084" 812 1249 12.4 11 6053406.32 1651683.39 70033'27.044" 149054'27.318" 813 1257 12.4 12 6053404.80 1651675.51 70033'27.029" 149054'27.551" 815 1265 12.4 13 6053400.38 1651652.80 70033'26 986" 149'54'28.221" 819 1288 17.4 14 6053398.83 1651644.95 70033'26 971" 149°54'28.453" 821 1296 12.4 15 6053397.31 1651637.12 70°33'26.956" 149°54'28 685" 822 1304 12.4 16 6053395.82 1651629.26 70°33'26.942" 149054'28.917" 824 1311 12.4 17 6053394.32 1651621.47 70033'26.927" 149054'29.147" 825 1319 12.4 18 6053392.78 1651613.58 /0033'26.912° 149054'29.380" 827 1327 12.4 19 6053389.63 1651597.90 70°33'26.881" 149054'29.843" 830 1343 12.4 20 6053388.17 I 1651590.00 70'33'26.867" 149054'30.076" 831 1351 12.4 21 6053386.60 1651582.24 70033'26.852" 149054'30.306" 833 1358 12.4 22 6053385.19 1651574.35 70'33'26.838" 149054'30.538" 834 1366 12.4 C 23) 6053383.64 1651566.41 70033'26.823" 149054'30.773" 836 1374 12.4 24 6053382.12 1651558.61 _ 70033'26.808" 149054'31.003" ; 837 1382 12.4 25 6053377.65 1651535.94 70033'26.764" 149054'31.673" 842 1405 12.4 26 6053376.14 1651528.13 70033'26.750" 149'54'31.904" 843 1413 12.4 27 6053374.53 1651520.23 70033'26.734" 149054'32.137" 845 1421 12.4 i 28 6053373.11 1651512.46 70033'26.720" 149°54'32.366" 846 1428 12.4 29 6053371.56 1651504.49 70033'26.705' 149°5432.602" 848 1436 12.4 30 6053370.06 1651496.66 70033'26.690" 149°54'32.833' 849 1444 12.1 31 6053367.05 1651480.97 70033'26.661" 149054'33.296" 852 1460 12.4 32 6053365.47 1651473.16 70°33'26.646" 149054'33.527" 854 1468 12.4 33 6053363.93 1651465.22 70033'26.631" 149054'33.762" 855 1476 12.4 34 6053362.44 1651457.37 70°33'26.616" 149054'33.993" 857 1483 12.4 35 6053360.91 1651449.52 70°33'26.601" 149054'34.225" 858 1491 12.4 36 6053359.33 1651441.62 70033'26.586" 149054'34.459" 860 1499 12.4 37 6053356.19 1651425.30 70033'26.555" 149054'34.941" 863 1516 12.4 38 6053354.74 1651417.32 70033'26.541" 1 149°54'35.177" 864 1524 12.4 ffoil* ektsi& oe, SPY ISLAND DRILL SITE , WELL CONDUCTORS AS-BUILT LOCATIONS 21111 ,.rr �, CA; rIlC:E1a3543G9 LIS OPe(aring °AT�'o/o,/so,o DRAWING NO: Eni-3543-d9 PA3:� 3 REO an Cr I\ 0 - - --. .._..- -- - - ---.___ ` - - 1 o i' 7 O N O fa ' NI o !_' LI-I ix -p j et et et et et et of et et a el; v, a v, a er a a a et a a a a v 0 et a NI yl Y U 03 01 N N N N N N N N N N N N N N N N N N N N N N N N N N N N VI 0 0- w el el el .-+ N el el .1 ri el eel N N .-I N el el 1 N el el N N el el vi e 1 el N Q Z 0 ,1 a 'c W 7 .0 c ai H e-1 01 tO a N 0 tD e} ,-1 01 N Vl 00 tO a ci Ol N m e-I CO 10 a N in m e-I co Ctn N N CO 01 0 N N M a a In ID CO al O ei ei N a in in tO N CO 0 e1 N N 7 4- �'"� 0 e-I el el ei N N N N N N N N N N M M M M M M M M M M a a a a JO O W n -1 N ei N ,-i .-1 .-i .-11i - N ei eel el el ei N N N N N N N N N el el 4-I a C C O --.• QO a .n z tn N N 00 000 000 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 0000 00 oto - COM co el 01 CO 01 -I na 00 0 0 0 M N 0 1.11 l(0 M N O M tO 01 (0O Oat N IIn Ct N 01 N lin ou M t0 00 0 M 0 O N 1• N 01 N CO O M in N 01 a tO 01 e1 M t0 N V1 N 01 -o el -ii ,-i eel .-1 eel r0i t--1eui 0-I e0-I epi eel .ui 4-1 ell eo 1 o- .^-I .^-I co elele 1 o 1 el c4 6 -i eel N N N N 7 Y a a Cr Cr Cr Cr Cr Cr Cr Cr a a a Cr Cr Cr Cr Cr Cr a a a Cr Cr a Cr Cr a L 00 0 0 N eA V1 Vf in 111 V1 Vf Vl t!1 In fell e 1 toll ill V1 V1 in IA in 1A V1 Vf teff 1A V1 t1 O o 0 0 0 0 0 iiio e e ra O 01 M 0 01 01 O) O) 41 01 01 Ol O1 cm 01 01 Ol 01 O) Ol 01 cm Qt 01 01 O1 Q1 01 01 a a a a a a a a a a a a a a a a a a a a a a a a a a a a CO el a-4 el ei ei ei I-I el el el ei e-1 N e-1 el el e-1 ei e1 el e-1 ei ei ei 1-1 ei ei el 0 v — . 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W U• o U 0 i 0 OVERSIZED DOCUMENT INSERT This file contains one or more oversized documents. These materials may be found in the original hard file or check the parent folder to view it in digital format. TRANSMITTAL/LETTER CHECKLIST WELL NAME A riell ICL c% �f 2 /A % 3 PTD# 2--1 I /2 Development Service Exploratory Stratigraphic Test Non-Conventional Well FIELD: ��� //. POOL: /1%--414--/ c�tcc --7-7.444-,1-e-4'-(7/1 /� (k. 7-C c 1 Circle Appropriate etter/Paragraphs to be Included in Transmittal Letter CHECK ADD-ONS WHAT (OPTIONS) TEXT FOR APPROVAL LETTER APPLIES MULTI LATERAL The permit is for a new wellbore segment of existing well (If last two digits in Permit No. , API No. 50- - - API number are between 60-69) Production should continue to be reported as a function of the original API number stated above. PILOT HOLE In accordance with 20 AAC 25.005(f), all records, data and logs acquired for the pilot hole must be clearly differentiated in both well name ( PH) and API number (50- - - ) from records, data and logs acquired for well . SPACING The permit is approved subject to full compliance with 20 AAC EXCEPTION 25.055. Approval to produce/inject is contingent upon issuance of a conservation order approving a spacing exception. assumes the liability of any protest to the spacing exception that may occur. DRY DITCH All dry ditch sample sets submitted to the Commission must be in SAMPLE no greater than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals through target zones. Non-Conventional Please note the following special condition of this permit: Well production or production testing of coal bed methane is not allowed for (name of well) until after (Company Name) has designed and implemented a water well testing program to provide baseline data on water quality and quantity. (Company Name) must contact the Commission to obtain advance approval of such water well testing program. 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To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. Technical Report Title Date Client: ENI Petroleum Field: Nikaitchuq Rig: Doyon 15 Date: February 4, 2012 Surface Data Logging End of Well Report SP23-N3 TABLE OF CONTENTS 1. General Information 2. Daily Summary 3. Morning Reports 4. Bit Record 5. Mud Record 6. Formation Tops 7. Show Reports 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 Files ASCII / LAS Files GENERAL WELL INFORMATION Company: Eni Petroleum Rig: Doyon 15 Well: SP23-N3 Field: Nikaitchuq Borough: North Slope Borough State: Alaska Country: United States API Number: 50-629-23456-00-00 Sperry Job Number: AK-AM-0009110185 Job Start Date: 02 Jan 2012 Spud Date: 06 Jan 2012 Total Depth: 14021’ MD, 3806’ TVD North Reference: True Declination: 20.812 Dip Angle: 81.062 Total Field Strength: 57651 nT Date Of Magnetic Data: 25 Nov 2011 Wellhead Coordinates N: North 70° 33’ 27.85” Wellhead Coordinates W: West 149° 54’ 19.38“ Drill Floor Elevation 54.1’ Ground Elevation: 13.1’ Permanent Datum: Mean Sea Level SDL Engineers: Zachary Beekman,Dave Mckechnie, Emil Optiz Company Geologist: Andrew Buchanan Company Representatives: Jack Keener, Mike Ross, Russ Wimmer SSDS Unit Number: 110 DAILY SUMMARY 01/02/2012 Begin SP23-N3. Mudloggers and loader operator got the mudlogging unit spotted. Mudloggers got with the rig electrician to get the unit plugged in and powered up so the heat and lights could be turned on. 01/03/2012 Mudloggers were rigging up the unit and getting all computers unpacked and set up back in the rack along with the gas equipment. All equipment needs to warm up before any of it can be started. 01/04/2012 Mudloggers were rigging up the unit and setting up the computers on the network. Set up WITS with Canrig and Schlumberger. 01/05/2012 Load pipe into the pipe shed. Strap all joints for measurement. Single in joints and rack back the stands into the derrick. Take on mud into the pits. Halliburton mudloggers are now completely rigged up and operational. The gas equipment is up and running and is currently reading 0 units. 01/06/2012 Continued to rig up for drilling. Rig up the Gyro unit. Make 13 3/8” landing joint dummy run. Pick up the 16” bit. Tag ice at 67 feet in the conductor and another obstruction at 132 feet. Rotate and clean out to 160 feet. Circulate. Held a Pre-spud meeting in the doghouse. Pull out of the hole and pick up bottom hole assembly number two. Drill to 273 feet and Gyro survey. Rack back the heavy weight drill pipe. Noticed 10-20 thousand pounds overpull and the hole was not taking the proper fill. Make up drilling bottom hole assembly. Drill to 374 feet MD. Prepare to Gyro survey at midnight. 01/07/2012 Drill ahead from 374 feet MD to 829 feet MD / 822 feet TVD. Change out saver sub Gyro and rig down. Directional drill from 829 feet MD to 1394 feet MD / 1365 feet TVD as of midnight. We observed a max gas of 240 units at a depth of 1478 feet MD. The average background for the day was 15 units. 01/08/2012 Continue drilling ahead with the 16” bit from 1394 feet MD to TD at 2762 feet MD / 2490 feet TVD. Performed two carbide tests. First test came back with no resulting gas so a second test was performed after double checking the gas equipment. The second test resulted in a gas peak of 52 units that came in almost 1600 strokes early. Backreaming out of the hole to clean out before running in with casing. Circulate for four complete bottoms up and one bottoms up per each stand racked back for a total of five bottoms up to 2346 feet MD as of midnight. Max gas for the day was 464 units at a depth of 1992 feet MD. Average background gas was observed throughout the day to be 90 units. 01/09/2012 Continue to backream out of the hole from 2346 feet MD performing one bottoms up per stand to 2234 feet MD. Backream out of the hole to 830 feet MD. Circulate per K&M rep. Pull out of the hole. Rig up and run 13 3/8” casing. Make up shoe track and check floats. Floats are good. Run in the hole with 13 3/8” casing to 628 feet MD as of midnight.. 01/10/2012 Run in the hole with 13 3/8” casing from 628’ MD to 2748’ MD. Circulate and condition the mud for cement job. Pressure test the cement lines to 1000 psi low and 3500 psi high. Pump cement as per details. Displace cement with 9.4 ppg mud. Bump the plug at 388 bbls/3876 strokes. The total amount of cement that came to the surface was 180 bbls. Flush the diverter equipment of contaminated cement returns. Clean the pits and rig down the casing equipment as of midnight. 01/11/2012 Rig down the casing equipment from casing and cement job. Clean the pits and ship all unused mud to the WIF. Pull the 20” riser to the rig floor. Function and wash the cement and contaminated mud from the 20” Hydril. Nipple down the 20” Hydril. Install well head on SP23 and test multi bowl. Nipple up the BOP. Energize Koomey and function tested all rams and HCR valves. Rig up to test BOPE. Test annular bag, kill line valve, upper IBOP, and choke valves as of midnight. 01/12/2012 Pulled the test plug and pumped out the stack. Blew down the choke manifold, kill line, choke line, and rinsed. Installed the wear bushing. Picked up BHA #3 and shallow tested tools as per Schlumberger representative. Slip and cut drill line. Circulate and condition mud for casing pressure test. Drill 25 feet of new formation to 2787’ MD. Displace mud and prepare for LOT as of midnight. 01/13/2012 Displace to LSND and perform LOT to 12.1 ppg EMW. Drill ahead. Max gas observed was 104 units. 01/14/2012 Continue drilling ahead, primarily sliding. ECD 9.66. Slow drilling as expected through the hard spots in the Lower Ugnu. Max gas observed was 17 units. 01/15/2012 Continue drilling ahead to 4573’ MD. Backream out of the hole to 4194’ MD. Monitor well and observe it being static. Run in the hole and resume drilling. Drill to 4602’ MD. Continued with slow ROP. The decision was made to pull out of the hole. Backreamed out of the hole. 01/16/2012 Finished backreaming out of the hole to surface casing shoe. Check well and observe it being static. Pull out of hole on elevators. Lay down BHA #3 and pick up BHA #4 and run in the hole. Resumed drilling once back on bottom. 01/17/2012 Continued drilling ahead from 4685’ MD to 5940’ MD as of midnight. Max gas observed during the last 24 hours was 299 units. The current average background gas is 75 units. 01/18/2012 Continued drilling ahead from 5940’ MD to TD of the intermediate section at 6390’ MD. Backreamed out of hole while circulating 1 bottoms up per stand for the first six. The hole cleanliness will continue to determine backreaming speed. Currently at 3800’ MD as of 0230 hrs. Max gas observed during the last 24 hours was 2072 units. 01/19/2012 Continue to backream out of the hole to inside the casing shoe at 2595’ MD. Circulated 2 bottoms up. Pulled out of hole on the elevators. Laid down BHA #4. Began rigging up the casing equipment and started running in the hole with 9 5/8” casing. 01/20/2012 Finished running in the hole with 9 5/8” casing. Rigged down casing equipment and began to make up the cement head. Circulated 3.5 bottoms up. Pumped cement to cement casing string in place. Rigged down cementing equipment and prepared to nipple down the stack. 01/21/2012 Nipple up the stack. Set the test plug and change out the top rams. Rig up and test BOPs. Rig down testing equipment. Install the wear bushing the freeze protect. 01/22/2012 Inspect and service the top drive. Make up BHA #5 then shallow test MWD tools and observe them as OK. Trip in the hole to 6170’ MD while filling every ten stands. Circulate and condition the mud. Perform casing pressure test to 3000psi and observe it as OK. Cut and slip drill line then calibrate the blocks. Displace from LSND to OBM. Tag cement at 6370’ MD. Drill out the cement and 25’ of new formation. Prepare to conduct the LOT as of midnight. 01/23/2012 Perform the LOT to 12.1 ppg EMW. Rotary drill ahead from 6370’ MD to 8490’ MD. Max gas observed during the last 24 hours was 2684 units. Current background gas observed is 161 units. 01/24/2012 Drill ahead to 10187’ MD. Crossed a fault that put us out of zone. Backreamed out of hole to 9815’ MD and began to perform an open hole sidetrack. The open hole sidetrack was successful at 9845’ MD. Continued drilling ahead to the current depth of 9971’ MD as of midnight. Max gas observed was 3635 units. Average gas throughout the day was 1305 units. 01/25/2012 Continued drilling ahead from 9971’ MD to the current depth of 11825’ MD. Max gas observed during the last 24 hours was 3386 units. The current background is 94 units. 01/26/2012 Continued drilling ahead from 11825’ MD to 13829’ MD as of midnight. Max gas for the past 24 hours was 1172 units. Current background is 71 units. 01/27/2012 Continued drilling ahead from 13829’ MD to TD of the production section at 14021’ MD. Circulated a bottoms up. Hole began taking losses at 13994’ MD while backreaming out of the hole. Losses were 160 bbls/hr. Run in the hole to 14014’ MD and establish the loss rate. Pumped a safe carb pill. 40 bph loss rate. Backreamed out of the hole and flow check at connections – static. Daily loss of 341 bbls. The max gas observed for the day was 1042 units. 01/28/2012 Continued backreaming out of the hole from 12047’ MD per K&M representative. Flow check between connections from 12047’ MD to 9687’ MD. 173 bbls lost. At 9687’ MD, 8 bbls lost. Stop pump. Observed flow but dropping. Monitor for an additional 15 minutes and found to be static. Continue backreaming out of the hole to 9065’ MD. Daily loss was 263 bbls. Total loss was 604 bbls. 01/29/2012 Continue backreaming out of the hole from 9065’ MD to 5500’ MD per K&M representative. Reamed slowly from 6547’ to 6366’. No excessive torque or over noted. At 5500’ MD, circulated two annular volumes at 500 gpm until shakers were clean. There was an 8 bbls loss while circulating. Monitor well, static. Pump a 20 bbls safe carb dry job. Pull out of the hole per K&M representative to 72’ as of midnight. 01/30/2012 Laid down the 8 ¾” BHA. Rigged up the GBR 5 ½: casing equipment. Run 5 ½” slotted liner per details. 185 joints run into 7760’ MD. Pick up crossover, seal bore, crossover and liner packer to 7804’ MD. Run in the hole with 66 stands of 5” drill pipe to 13966’ MD as of midnight. 01/31/2012 At 13966’ MD, dropped setting ball. Observed the ball on the seat. Set the packer per Baker representative and tested. Released from the packer. 5 ½” liner top at 6175’ MD. Displaced from FazePro OBM to 3% KCl/NaCl Brine. Laid down 5” drill pipe from 6100’ MD as of midnight. 02/01/2012 Laid down 57 joints to 2418’ MD. Racked back 26 stands of 5” drill pipe. Flushed the BOP stack with 5 bbls of fresh water and 10 ppb of citric acid. Mobilized and rigged up Centrilift and GBR equipment. Make up screen intake. Staged pumps per Centrilift. Shut down operations and laid down same equipment. The call was made to wait for ambient temperature to rise above -35 to -40 below freezing. Run in the hole with 22 stands of 5” drill pipe to 2237’ MD. Circulate every two hours. Monitored the well to be static. 02/02/2012 Continued to wait for ambient temperatures to rise above -35 to -40 below freezing. Remove wear ring with Vetco Gray representative. Remobilize the floor with Centrilift ESP equipment and GBR equipment. Rig up the slickline crew. Set pump and tubing packoff and test per well plan. Run 4 ½” tubing jewelry with ESP pump assembly. 02/03/2012 Continue tripping in the hole with 143 joints of 4 ½” completion tubing per details to 5912’ MD. Test lines every 1000 feet. Pick up the hanger and make up the tubing hanger. Make the final splice of ESP cable and test the conductivity. Test was good. Land the 4 ½” production string. Test the upper and lower hanger body seals. Rig down the equipment on the rig floor. Nipple down the BOP stack. Mudloggers began rigging down the logging unit to prepare for the rig move. Power was shut off and the logging unit was moved by the loader operator. 02/04/2012 The mudloggers continued to rig down the unit to prepare for the rig move. Mudlogger Zach Beekman arrives on location and changed out with Emil Opitz who left location. Rig crew has been breaking down the rig to prepare for the rig move. Today was the final day of SP23-N3. . . Density (ppg) Viscosity out (sec/qt) Depth Mud Type YP Cor Solids (lb/100ft 2) mg/l ml/30min Cht Silt Siltst Ss Lst EVAMAR 1 5-Jan-2011 24:00:00 Time: Report #: Date: API FL ENI Petroleum SP23-N3 Spy Island 24 hr Max North Slope Doyon 15 Customer: Well: Avg Weight (ppb Eq) cP PV PWD MBT Tools Lithology (%) (current) 160' Sh Clyst Cly Tuff Gvl Coal Bit Type TFA - pH Chlorides -Min - Avg Min Max Max Picking up pipe Rig Activity: Flow In (spm) $2,810.00 $7,620.00 Report For: Ross/Wimmer/Buchanan Total Charges: 0' 0' 0' Current Depth: 24 Hour Progress: Flow In (gpm) Current Pump & Flow Data: - Max @ ft Current Avg ROP (ft/hr) % -MWD Summary RPM Condition 0' in Drilling All Circ Mud Data - 4.23 Hours Depth in / out Footage WOB Daily Charges: Rig: Job No.: to Size Area: Location: 96% SPP (psi) Gallons/stroke @ Yesterday's Depth: ROP Set At Size 178.9 X-65 Bit # Casing Summary 0' Depth 20" Make Grade * 10000 units = 100% Gas In Air 24 hr Recap: Background Trip Chromatograph (ppm) 0 0 C-5n 0 md. pits. Halliburton mudloggers are now completely rigged up and operational. Gas equipment is up and running and is reading 0 units. Load pipe shed with pipe. Strap all joints. Single in joints and rack back stands into derrick. Take on 230 bbls of mud into the Gas Summary 0 0 0 0Maximum Minimum Average 0 Depth 0 0 0 0 0 00 Units* 0 0000 C-2 C-3 C-5i C-1 C-4i C-4n Logging Engineers: Zach Beekman / Dave McKechnie (max) (current) Report By: Zach Beekman 0 . . Density (ppg) Viscosity out (sec/qt) Grade Bit # Casing Summary 374' Depth 20" Make ROP Set At Size 178.9 X-65 Area: Location: 96% 541 128 SPP (psi) Gallons/stroke 750 @ Yesterday's Depth: 20.0 Rig: Job No.: to Size Smith XR+ Milltooth Mud Data - 4.23 Hours Depth in / out Footage WOB RPM Condition 160' in Drilling All Circ % -MWD Summary ROP (ft/hr) 424'4.1 Flow In (gpm) Current Pump & Flow Data: - Max @ ft Current Avg Report For: Keener/Wimmer/Buchanan Total Charges: 160' 374' 214' Current Depth: 24 Hour Progress: Daily Charges: Min Max Max Gyro 16" surface Rig Activity: Flow In (spm) 454.0 $2,810.00 $10,430.00 2.0 Bit Type TFA - pH Chlorides -Min - Avg Tuff Gvl Coal 160' Sh Clyst Cly 1.117 20 Lithology (%) (current) cP PV PWD MBT Tools API FL ENI Petroleum SP23-N3 Spy Island 24 hr Max North Slope Doyon 15 Customer: 92 2 6-Jan-2011 24:00:00 Time: Report #: Date: Well: Avg (ppb Eq) 24.0 30 Weight Lst 160' 214' EVAMAR 4.00 8.80 123.0 15.0 Ss 5.4 1 Cht Silt Siltst 16" YP Cor Solids (lb/100ft 2) 2,300 9.00 mg/l ml/30min 374' Gel Mud Depth Mud Type * 10000 units = 100% Gas In Air 0 Report By: Zach Beekman C-5i C-1 C-4i C-4n Logging Engineers: Zach Beekman / Dave McKechnie (max) (current) Units* 0 0000 C-2 C-3 0 Depth 0 0 0 0 0 00 0Maximum Minimum Average 10 247 0403' 312' 5 Gas Summary 0 the conductor and another obstruction at 132 ft. Rotate and clean out to 160 ft. Circulate. Pre-spud meeting. Pull out of the hole and pick Continue rig up for drilling. Rig up Gyro unit. Make 13 3/8" landing joint dummy run. Pick up the 16" bit. Tag ice at 67 feet in 1 md. up BHA #2. Drill to 273 ft and Gyro survey. Rack back heavy weight drill pipe. Noticed 10-20K overpull and hole not taking proper fill. Make up drilling BHA. Drill to 374 ft MD. Prepare to Gyro survey at midnight. C-5n 0 0 0 Chromatograph (ppm) Trip 24 hr Recap: 2Background . . Density (ppg) Viscosity out (sec/qt) 1394' Gel Mud Depth Mud Type YP Cor Solids (lb/100ft 2) 2,900 9.20 mg/l ml/30min 1 Cht Silt Siltst 16" 9.10 220.0 20.0 Ss 5.5 Lst 160' 1234' EVAMAR 12.10 20.0 28 Weight - 3 7-Jan-2011 24:00:00 Time: Report #: Date: Well: Avg (ppb Eq) API FL ENI Petroleum SP23-N3 Spy Island 24 hr Max North Slope Doyon 15 Customer: cP PV PWD MBT Tools 1.117 18 Lithology (%) (current) 160' Sh Clyst Cly Tuff Gvl Coal 460.0 $2,810.00 $13,240.00 3.5 Bit Type TFA - pH Chlorides 374' 1394' 1020' Current Depth: 24 Hour Progress: Daily Charges: Drilling Ahead Rig Activity: Current Avg Report For: Keener/Wimmer/Buchanan Total Charges: Min Max Max Flow In (spm) Flow In (gpm) Current Pump & Flow Data: - Max @ ft -Min - Avg ROP (ft/hr) 434'47.7 -MWD Summary Condition 374' in Drilling All Circ % Mud Data - 4.23 Hours Depth in / out Footage WOB 100.0 Rig: Job No.: to Size Smith XR+ Milltooth Area: Location: 96% 795 188 SPP (psi) Gallons/stroke 1578 @ Yesterday's Depth: ROP Set At Size 178.9 X-65 1394' Depth 20" Make Grade Bit # Casing Summary RPM * 10000 units = 100% Gas In Air 24 hr Recap: 50 Background Trip Chromatograph (ppm) 0 0 C-5n 0 11 md. 15 units. 1394' MD / 1365' TVD as of midnight. We observed max gas at 240 units at a depth of 1478' MD. Average background for the day was Drill ahead from 374' MD to 829' MD / 822' TVD. Change out saver sub Gyro and rig down. Directional drill from 829' MD to 6 240 Gas Summary 27036 01478' 807' 0Maximum Minimum Average 1092 0 Depth 0 0 0 0 0 00 00475 C-2 C-3 C-4i C-4n Logging Engineers: Zach Beekman / Dave McKechnie (max) (current) Units* 0 0 Report By: Zach Beekman 0 C-5i C-1 . . Density (ppg) Viscosity out (sec/qt) Bit # Casing Summary RPM Make Grade ROP Set At Size 178.9 X-65 2762' Depth Area: Location: 96% 787 188 SPP (psi) Gallons/stroke 1538 @ Yesterday's Depth: Size Smith XR+ Milltooth 20" % Mud Data - Hours Depth in / out Footage WOB Condition 1394' in Drilling All Circ -MWD Summary Avg ROP (ft/hr) 2680'56.0 Max Max Flow In (spm) Flow In (gpm) --Min - Current Avg Report For: Keener/Wimmer/Buchanan Total Charges: Min Current Pump & Flow Data: Max @ ft 4.23 0.0 1394' 2762' 1368' Current Depth: 24 Hour Progress: Daily Charges: Backreaming Rig Activity: Rig: Job No.: 531.0 $3,410.00 $16,650.00 4.5 Bit Type TFA - pH Chlorides Tuff Gvl Coal 160' Sh Clyst Cly 1.117 20 Lithology (%) (current) cP PV PWD MBT Tools to API FL ENI Petroleum SP23-N3 Spy Island 24 hr Max North Slope Doyon 15 Customer: - 4 8-Jan-2011 24:00:00 Time: Report #: Date: Well: Avg (ppb Eq) 20.0 30 Weight 160' 2762' 2602' EVAMAR 12.10 9.20 60.0 17.0 Ss 5.3 Lst 1 Cht Silt Siltst 16" YP Cor Solids (lb/100ft 2) 2,200 9.30 mg/l ml/30min 2762' Gel Mud Depth Mud Type * 10000 units = 100% Gas In Air C-5i C-1 Logging Engineers: Zach Beekman / Dave McKechnie (max) (current) Units* 0 0 Report By: Zach Beekman 0096 C-2 C-3 0 Depth 0 0 0 0 0 00 0Maximum Minimum Average 13176 54585 01992' 2730' 464 Gas Summary C-4i C-4n 0 3 bottoms up and one bottoms up per each stand racked back for a total of five bottoms up to 2346' MD as of midnight. came back with no resulting gas so performed second test after double checking equipment. Second test resulted in a gas peak that Continue drilling ahead with 16" bit from 1394' MD to TD at 2762' MD / 2490' TVD. Performed two carbide tests. First test 137 md. came in almost 1600 stokes early. Backreaming out of the hole to clean out before running in with casing. Circulate for four complete C-5n 0 0 0 Chromatograph (ppm) Trip 24 hr Recap: 90 Background . . Density (ppg) Viscosity out (sec/qt) 2762' Gel Mud Depth Mud Type YP Cor Solids (lb/100ft 2) -8.90 mg/l ml/30min 1 Cht Silt Siltst 16" 9.30 60.0 17.0 Ss - Lst 160' 2762' 2602' EVAMAR 12.10 - 32 Weight - 5 9-Jan-2011 24:00:00 Time: Report #: Date: Well: Avg (ppb Eq) API FL ENI Petroleum SP23-N3 Spy Island 24 hr Max North Slope Doyon 15 Customer: cP PV PWD MBT Tools to 19 Lithology (%) (current) 160' Sh Clyst Cly Tuff Gvl Coal $3,410.00 $20,060.00 - Bit Type TFA - pH Chlorides 2762' 2762' 0' Current Depth: 24 Hour Progress: Daily Charges: RIH w/13 3/8" casing Rig Activity: Rig: Job No.: Current Avg Report For: Keener/Wimmer/Buchanan Total Charges: Min Current Pump & Flow Data: Max @ ft 4.23 Max Max Flow In (spm) Flow In (gpm) --Min - Avg ROP (ft/hr) -MWD Summary Condition 2762' in Drilling All Circ % Mud Data - Hours Depth in / out Footage WOB Size Smith XR+ Milltooth 20" Area: Location: 96% 84 20 SPP (psi) Gallons/stroke 21 @ Yesterday's Depth: ROP Set At Size 178.9 X-65 2762' Depth Grade Bit # Casing Summary RPM Make 1.117 * 10000 units = 100% Gas In Air 24 hr Recap: Background Trip Chromatograph (ppm) 0 0 C-5n 0 md. are good. Run in the hole with 13 3/8" casing to 628' MD as of midnight. hole to 830' MD. Circulate per K&M rep. Pull out of the hole. Rig up and run 13 3/8" casing. Make up shoe track and check floats. Floats Continue to backream out of the hole from 2346' MD performing one bottoms up per stand to 2234' MD. Backream out of the Gas Summary C-4i C-4n 00 0 0Maximum Minimum Average 0 0 Depth 0 0 0 0 0 00 000 C-2 C-3 Logging Engineers: Zach Beekman / Dave McKechnie (max) (current) Units* 0 0 Report By: Zach Beekman C-5i C-1 . . Density (ppg) Viscosity out (sec/qt) Bit # Casing Summary RPM Make 1.117 Grade ROP Set At Size 178.9 X-65 2762' Depth Area: Location: 96% SPP (psi) Gallons/stroke @ Yesterday's Depth: Size Smith XR+ Milltooth 20" % Mud Data Hours Depth in / out Footage WOB Condition 2762' in Drilling All Circ -MWD Summary - Avg ROP (ft/hr) Max Max Flow In (spm) Flow In (gpm) --Min Avg Report For: Keener/Wimmer/Buchanan Total Charges: Min Current Pump & Flow Data: Max @ ft 4.23 - 2762' 2762' 0' Current Depth: 24 Hour Progress: Daily Charges: Clean pits N/D Riser Rig Activity: Rig: Job No.: $3,410.00 $23,470.00 - Bit Type TFA - pH Chlorides Current Tuff Gvl Coal 160' Sh Clyst Cly 18 Lithology (%) (current) cP PV PWD MBT Tools to API FL ENI Petroleum SP23-N3 Spy Island 24 hr Max North Slope Doyon 15 Customer: - 6 10-Jan-2011 24:00:00 Time: Report #: Date: Well: Avg (ppb Eq) - 15 Weight 160' 2762' 2602' EVAMAR 12.10 9.40 60.0 17.0 Ss - Lst 1 Cht Silt Siltst 16" YP Cor Solids (lb/100ft 2) -8.20 mg/l ml/30min 2762' Gel Mud Depth Mud Type * 10000 units = 100% Gas In Air C-5i C-1 Logging Engineers: Zach Beekman / Dave McKechnie (max) (current) Units* 0 0 Report By: Zach Beekman 000 C-2 C-3 0 Depth 0 0 0 0 0 00 0Maximum Minimum Average 0 0 0 Gas Summary C-4i C-4n 0 Run 13 3/8" casing from 628' MD to 2748' MD. Circulate and condition the mud for cement job. Pressure test the cement lines Total cement to surface was 180 bbls. Flush the diverter equipment of contaminated cement returns. Clean the pits and rig down the casing equipment as of midnight. to 1000 psi low and 3500 psi high. Pump cement as per details. Displace cement with 9.4 ppg mud. Bump plug at 388 bbls/3876 stks. md. C-5n 0 0 0 Chromatograph (ppm) Trip 24 hr Recap: Background . . Density (ppg) Viscosity out (sec/qt) Depth Mud Type ml/30min 2762' Gel Mud 16" YP 2-1-WT-M-E-I-PN-TD Cor Solids (lb/100ft 2) -8.30 mg/l Cht Silt Siltst 9.30 60.0 17.0 Ss - Lst 160' 2762' 2602' EVAMAR 12.10 Well: Avg (ppb Eq) - 14 7 11-Jan-2011 24:00:00 Time: Report #: Date: API FL ENI Petroleum SP23-N3 Spy Island 24 hr Max North Slope Doyon 15 Customer: cP PV PWD MBT Tools to - Lithology (%) (current) 160' Sh Clyst Cly Weight Tuff Gvl Coal $3,410.00 $26,880.00 - Bit Type TFA - pH Chlorides Current 18 2762' 2762' 0' Current Depth: 24 Hour Progress: Daily Charges: Test BOP Rig Activity: Rig: Job No.: Avg Report For: Keener/Wimmer/Buchanan Total Charges: Min Current Pump & Flow Data: Max @ ft 4.23 - Max Max Flow In (spm) Flow In (gpm) --Min - Avg ROP (ft/hr) -MWD Summary Condition 2762' in Drilling All Circ % Mud Data Hours Depth in / out Footage WOB Size Smith XR+ Milltooth 20" Area: Location: 96% SPP (psi) Gallons/stroke @ Yesterday's Depth: ROP Set At Size 178.9 X-65 2762' Depth Grade Bit # Casing Summary RPM Make 1.117 1 * 10000 units = 100% Gas In Air 24 hr Recap: Background Trip Chromatograph (ppm) 0 0 C-5n 0 md. head on SP23 and test multi bowl. Nipple up the BOP. Energize Koomey and function tested all rams and HCR valves. Rig up to test BOPE. Test annular bag, kill line valve, upper IBOP, and choke valves as of midnight. 20' riser to the rig floor. Function and wash the cement and contaminated mud from 20" Hydril. Nipple down the 20" Hydril. Install well Rig down the casing equipment from casing and cement job. Clean the pits and ship all unused mud to the WIF. Pull the Gas Summary C-4i C-4n 00 0 0Maximum Minimum Average 0 0 Depth 0 0 0 0 0 00 000 C-2 C-3 Logging Engineers: Zach Beekman / Dave McKechnie (max) (current) Units* 0 0 Report By: Zach Beekman C-5i C-1 . . Density (ppg) Viscosity out (sec/qt) Bit # Casing Summary RPM 13 3/8" Make 0.942 2 Grade L-80 ROP Set At Size 178.9 X-65 2787' Depth Gallons/stroke 703 @ Yesterday's Depth: 20" Area: Location: 96% 406 97 SPP (psi) Hours Depth in / out Footage WOB Size Hughes VM-3 Milltooth Condition 2762' in Drilling All Circ % -MWD Summary ROP (ft/hr) Max Max Flow In (spm) Flow In (gpm) --Min Report For: Keener/Smith/Buchanan Total Charges: Min Current Pump & Flow Data: Max @ ft 4.23 - $30,290.00 2762' 2787' 25' Current Depth: 24 Hour Progress: Daily Charges: Displace Mud Rig Activity: Rig: Job No.: Bit Type TFA - pH Chlorides -9.30 ml/30min - Avg Current 18 Avg Tuff Gvl Coal 160' 2748' Sh Clyst Weight Lithology (%) (current) 68.0 cP PV PWD MBT Tools to Mud Data ENI Petroleum SP23-N3 Spy Island 24 hr Max North Slope Doyon 15 AK-AM-0009110185 Customer: $3,410.00 8 12-Jan-2011 24:00:00 Time: Report #: Date: Well: Avg (ppb Eq) - 15 2762' 25' EVAMAR 0.20 45.0 20.0 Cly Ss - Lst Cht Silt Siltst YP Cor Solids (lb/100ft 2) -- mg/l API FL -2762' GEL Mud Depth Mud Type 12.25" * 10000 units = 100% Gas In Air C-5i C-1 Logging Engineers: Zach Beekman / Dave McKechnie (max) (current) Units* 0 0 Report By: Zach Beekman 000 C-2 C-3 0 Depth 0 0 0 0 0 00 Maximum Minimum Average 0 0 0 0 C-4i C-4n 0 Gas Summary #3. Shallow test as per Schlumberger. Slip and cut drill line. Circulate and condition mud for casing pressure test. Drill 25 feet of new Pull test plug, pump out stack. Blow down choke manifold, kill line, choke line, and rinse. Install wear bushing. Pick up BHA md. formation to 2787' MD. Displace mud and prepare for LOT as of midnight. C-5n 0 0 0 Chromatograph (ppm) 24 hr Recap: Background Trip . . Viscosity Depth Mud Type 12.25" LSND Bit # YP Lst 20 Cht Bit Type Cor Solids (lb/100ft2) 8009.70 mg/l API FL 4.55.0 80 3820' EVAMAR Well: Avg (ppb Eq) 10.0 30 Date: 9.30 cP PV 9 13-Jan-2012 24:00:00Time: Report #:ENI Petroleum SP23-N3 Spy Island 24 hr Max North Slope Doyon 15 AK-AM-0009110185 Customer: MBT Tools SP Motor 1.50, ARC 825, PowerPulse 825to Mud Data Lithology (%) (current) 68.0 Ss Casing Summary ClySilt 160' 2748' ShClyst Weight Current 12 Avg TuffGvlCoal 2787' 3930' 1143' Current Depth: 24 Hour Progress: Daily Charges:Drill AheadRig Activity: Rig: Job No.: Max @ ft 4.23 - 849.6110.2 MWD Summary - -A v g Min Flow In (gpm) --Min - Current Pump & Flow Data: PWD Max Max Flow In (spm) TFA pH Chlorides ROP (ft/hr)3560'310.9 in Drilling All Circ % Size Hughes VM-3 Milltooth Condition 2787' 549.20 ml/30min Area: Location: 96% 758 181 SPP (psi) Report For:Keener/Smith/BuchananTotal Charges: 20" Gallons/stroke 1747 @ Yesterday's Depth: ROP Set AtSize 178.9 X-65 3930' Grade L-80 Siltst 13 3/8" Make 1.117 BTC 2762'2 Depth (sec/qt) Density (ppg) out RPM Hours Depth in / out Footage WOB * 10000 units = 100% Gas In Air 24 hr Recap: 1Background Trip 21 Maximum Minimum 1 Chromatograph (ppm) 0 0 Displace to LSND and perform LOT to 12.1 ppg EMW. Drill ahead. md Gas Summary C-4i C-4n 0 C-5n 0 104 0 0 Average 2161 2941' 3650' 13971 0 Depth 0 0 0 0 0 00 0123 C-2 C-3C-1 Logging Engineers:Emil Opitz / Dave McKechnie (max)(current) Units* 0 0 Report By: Emil Opitz C-5i 0 . . Viscosity Depth Mud Type 12.25" LSND Bit # YP LstCht Bit Type 100 Cor Solids (lb/100ft2) 1,4009.90 mg/l API FL 5.54.24474' EVAMAR Well: Avg (ppb Eq) 10.0 28 Date: 9.25 cP PV 10 14-Jan-2012 24:00:00Time: Report #:ENI Petroleum SP23-N3 Spy Island 24 hr Max North Slope Doyon 15 AK-AM-0009110185 Customer: MBT Tools SP Motor 1.50, ARC 825, PowerPulse 825to Mud Data Lithology (%) (current) 68.0 Ss Casing Summary ClySilt 160' 2748' ShClyst Weight Current 13 Avg TuffGvlCoal 3930' 4474' 544' Current Depth: 24 Hour Progress: Daily Charges:Drill AheadRig Activity: Rig: Job No.: Max @ ft 4.23 - 601.018.8 MWD Summary - -A v g Min Flow In (gpm) --Min - Current Pump & Flow Data: PWD Max Max Flow In (spm) TFA pH Chlorides ROP (ft/hr)4365'25.8 in Drilling All Circ % Size Hughes VM-3 Milltooth Condition 3930' 549.15 ml/30min Area: Location: 96% 883 211 SPP (psi) Report For:Keener/Smith/BuchananTotal Charges: 20" Gallons/stroke 2263 @ Yesterday's Depth: ROP Set AtSize 178.9 X-65 4474' Grade L-80 Siltst 13 3/8" Make 1.117 BTC 2762'2 Depth (sec/qt) Density (ppg) out RPM Hours Depth in / out Footage WOB * 10000 units = 100% Gas In Air 24 hr Recap: 1Background Trip 6 Maximum Minimum 1 Chromatograph (ppm) 0 0 Continue drilling ahead, primarily sliding. ECD 9.66. Slow drilling as expected through hard spots in Lower Ugnu. md Gas Summary C-4i C-4n 0 C-5n 0 17 0 0 0 Average 488 4264' 4440' 1844 0 Depth 0 0 0 0 0 00 138 C-2 C-3C-1 Logging Engineers:Emil Opitz / Dave McKechnie (max)(current) Units* 0 0 Report By: Emil Opitz C-5i 0 . . Viscosity Depth Mud Type 12.25" LSND Bit # YP LstCht Bit Type 100 Cor Solids (lb/100ft2) 1,3009.80 mg/l API FL 5.54.14192' EVAMAR Well: Avg (ppb Eq) 11.5 26 Date: 9.20 cP PV 11 15-Jan-2012 24:00:00Time: Report #:ENI Petroleum SP23-N3 Spy Island 24 hr Max North Slope Doyon 15 AK-AM-0009110185 Customer: MBT Tools SP Motor 1.50, ARC 825, PowerPulse 825to Mud Data Lithology (%) (current) 68.0 Ss Casing Summary ClySilt 160' 2748' ShClyst Weight Current 13 Avg TuffGvlCoal 4474' 4602' 128' Current Depth: 24 Hour Progress: Daily Charges:BROOHRig Activity: Rig: Job No.: Max @ ft 4.23 - 836.0 MWD Summary - -A v g Min Flow In (gpm) --Min - Current Pump & Flow Data: PWD Max Max Flow In (spm) TFA pH Chlorides ROP (ft/hr)4480'8.3 in Drilling All Circ % Size Hughes VM-3 Milltooth Condition 4474' 549.20 ml/30min Area: Location: 96% 893 214 SPP (psi) Report For:Keener/Smith/BuchananTotal Charges: 20" Gallons/stroke 1787 @ Yesterday's Depth: ROP Set AtSize 178.9 X-65 4602' Grade L-80 Siltst 13 3/8" Make 1.117 BTC 2762'2 Depth (sec/qt) Density (ppg) out RPM Hours Depth in / out Footage WOB * 10000 units = 100% Gas In Air 9 24 hr Recap: Background Trip 2 Maximum Minimum 1 Chromatograph (ppm) 0 0 Continued slow ROP. Decision made to POOH. BROOH. Continue drilling ahead to 4573' MD. BROOH to 4194' MD. Monitor well - static. RIH and resume drilling. Drill to 4602' MD. md Gas Summary C-4i C-4n 0 C-5n 0 5 0 0 0 Average 192 4495' 4552' 444 0 Depth 0 0 0 0 0 00 119 C-2 C-3C-1 Logging Engineers:Emil Opitz / Dave McKechnie (max)(current) Units* 0 0 Report By: Emil Opitz C-5i 0 . . Viscosity Depth Mud Type 12.25" LSND Bit # 2 YP Lst Hughes VM-3 Milltooth Cht Bit Type 100 Cor Solids (lb/100ft2) 1,30010.00 mg/l API FL 6.53.84667' 402762' 4602' EVAMAR 21.90 1840' Well: Avg (ppb Eq) 12.5 28 Date: 9.30 cP PV 12 16-Jan-2012 24:00:00Time: Report #:ENI Petroleum SP23-N3 Spy Island 24 hr Max North Slope Doyon 15 AK-AM-0009110185 Customer: MBT Tools SP Motor 1.50, ARC 825, Telescopeto Mud Data Lithology (%) (current) 68.0 Ss Casing Summary ClySilt 3-8-WT-G-F-12-LN-ROP 160' 2748' ShClyst 12.25 Weight 60 Current 12 Avg TuffGvlCoal 4602' 4685' 83' Current Depth: 24 Hour Progress: Daily Charges:Drilling AheadRig Activity: Rig: Job No.: Max @ ft 4.23 - 521.934.3 MWD Summary - -A v g Min Flow In (gpm) --Min - Current Pump & Flow Data: PWD Max Max Flow In (spm) TFA pH Chlorides ROP (ft/hr)4627'177.8 in Drilling All Circ % Size Hughes VM-3 Milltooth Condition 4602' 599.35 ml/30min Area: Location: 96% 690 163 SPP (psi) Report For:Keener/Smith/BuchananTotal Charges: 20" Gallons/stroke 1865 @ Yesterday's Depth: ROP Set AtSize 178.9 X-65 4685' Grade L-80 Siltst 1.117 13 3/8" Make 1.117 BTC 4602' 3 Depth (sec/qt) Density (ppg) out RPM Hours Depth in / out Footage WOB * 10000 units = 100% Gas In Air 85 24 hr Recap: 3Background Trip 18 Maximum Minimum 4 Chromatograph (ppm) 0 0 drilling. Finish BROOH to surface casing shoe. Check well - static. POOH on elevators. L/D BHA #3. P/U BHA #4 and RIH. Resume md Gas Summary C-4i C-4n 0 C-5n 0 39 0 0 0 Average 1044 4621' 4603' 2268 0 Depth 0 0 0 0 0 00 154 C-2 C-3C-1 Logging Engineers:Emil Opitz / Dave McKechnie (max)(current) Units* 0 0 Report By: Emil Opitz C-5i 0 . . Viscosity Depth Mud Type 12.25" LSND Bit # YP Lst 30 Cht Bit Type 40 Cor Solids (lb/100ft2) 1,3509.50 mg/l API FL 7.03.45951' 30 EVAMAR Well: Avg (ppb Eq) 16.5 29 Date: 9.55 cP PV 13 17-Jan-2012 24:00:00Time: Report #:ENI Petroleum SP23-N3 Spy Island 24 hr Max North Slope Doyon 15 AK-AM-0009110185 Customer: MBT Tools SP Motor 1.50, ARC 825, Telescopeto Mud Data Lithology (%) (current) 68.0 Ss Casing Summary ClySilt 160' 2748' ShClyst Weight Current 15 Avg TuffGvlCoal 4685' 5940' 1255' Current Depth: 24 Hour Progress: Daily Charges:Drilling AheadRig Activity: Rig: Job No.: Max @ ft 4.23 - 745.0116.4 MWD Summary - -A v g Min Flow In (gpm) --Min - Current Pump & Flow Data: PWD Max Max Flow In (spm) TFA pH Chlorides ROP (ft/hr)5307'126.2 in Drilling All Circ % Size Hughes VM-3 Milltooth Condition 4685' 619.45 ml/30min Area: Location: 96% 903 213 SPP (psi) Report For:Keener/Smith/BuchananTotal Charges: 20" Gallons/stroke 3022 @ Yesterday's Depth: ROP Set AtSize 178.9 X-65 5940' Grade L-80 Siltst 13 3/8" Make 1.117 BTC 4602' 3 Depth (sec/qt) Density (ppg) out RPM Hours Depth in / out Footage WOB * 10000 units = 100% Gas In Air 24 hr Recap: 30Background Trip 76 Maximum Minimum 6 Chromatograph (ppm) 21 11 Continue drilling ahead. md Gas Summary C-4i C-4n 0 C-5n 0 299 0 142 22 Average 2897 5026' 4721' 16780 12 Depth 6 0 16 1 0 2012 347 C-2 C-3C-1 Logging Engineers:Emil Opitz / Dave McKechnie (max)(current) Units* 5 0 Report By: Emil Opitz C-5i 0 . . Viscosity 3 Depth (sec/qt) Density (ppg) out RPM Hours Depth in / out Footage WOB 13 3/8" Make 1.117 BTC 4602' Grade L-80 Siltst ROP Set AtSize 178.9 X-65 6390' Gallons/stroke 2541 @ Yesterday's Depth: 20" Area: Location: 96% 897 212 SPP (psi) Report For:Keener/Smith/BuchananTotal Charges: Hughes VM-3 Milltooth Condition 5940' 489.40 ml/30minin Drilling All Circ % Size ROP (ft/hr)6256'174.9 Max Max Flow In (spm) TFA pH Chlorides Flow In (gpm) --Min - Current Pump & Flow Data: PWD Max @ ft 4.23 - 878.2 MWD Summary - -A v g Min 5940' 6390' 450' Current Depth: 24 Hour Progress: Daily Charges:BROOHRig Activity: Rig: Job No.: Current 14 Avg TuffGvlCoal 160' 2748' ShClyst Weight Lithology (%) (current) 68.0 Ss Casing Summary ClySilt MBT Tools SP Motor 1.50, ARC 825, Telescopeto Mud Data ENI Petroleum SP23-N3 Spy Island 24 hr Max North Slope Doyon 15 AK-AM-0009110185 Customer:14 18-Jan-2012 24:00:00Time: Report #: Well: Avg (ppb Eq) 18.0 26 Date: cP PV EVAMAR 6390' Cor Solids (lb/100ft2) 1,3009.70 mg/l API FL 6.53.8 YP Lst 10 Cht Bit Type 90 LSND Bit # Depth Mud Type 12.25" * 10000 units = 100% Gas In Air C-5i 3 Logging Engineers:Emil Opitz / Dave McKechnie (max)(current) Units* 385 4 Report By: Emil Opitz 665 C-2 C-3C-1 53 Depth 523 7 107 363 9 8774Average13591 6297' 5989' 91656 725 425 C-4n 206 C-5n 6 2072 3 Gas Summary C-4i continue to determine backreaming speed. Currently @ 3800' MD as of 0230 hrs. Continue drilling ahead to intermediate TD of 6390' MD. BROOH @ 1x CBU per stand for first 6 stands, and hole cleanliness will md 111 71 Chromatograph (ppm) 447 Maximum Minimum 24 87 24 hr Recap: Background Trip . . Viscosity Depth Mud Type 12.25" LSND Bit # YP LstCht Bit Type Cor Solids (lb/100ft2) 1,3009.50 mg/l API FL 6.53.86390' 100.032.0 1-1-WT-A-E-1-NO-TD6390' 1788' EVAMAR Well: Avg (ppb Eq) 18.0 24 Date: cP PV 15 19-Jan-2012 24:00:00Time: Report #:ENI Petroleum SP23-N3 Spy Island 24 hr Max North Slope Doyon 15 AK-AM-0009110185 Customer: MBT Tools to Mud Data Lithology (%) (current) 68.0 Ss Casing Summary ClySilt 160' 2748' ShClyst Weight Current 15 Avg TuffGvlCoal 6390' 6390' 0' Current Depth: 24 Hour Progress: Daily Charges:CasingRig Activity: Rig: Job No.: Max @ ft 4.23 -MWD Summary - -A v g Min Flow In (gpm) --Min - Current Pump & Flow Data: PWD Max Max Flow In (spm) TFA pH Chlorides ROP (ft/hr) in Drilling All Circ % Size Hughes VM-3 Milltooth Condition 6390' 499.40 ml/30min Area: Location: 96% SPP (psi) Report For:Ross/Smith/BuchananTotal Charges: 20" Gallons/stroke @ Yesterday's Depth: ROP Set AtSize 178.9 X-65 6390' Grade L-80 Siltst 13 3/8" 9 5/8" Make 1.117 BTC 21.70 4602' 3 Depth (sec/qt) Density (ppg) out RPM Hours Depth in / out Footage WOB * 10000 units = 100% Gas In Air 69 24 hr Recap: Background Trip Maximum Minimum Chromatograph (ppm) 0 0 Continue to BROOH to inside shoe @ 2595' MD. CBU 2x. POOH on elevators. L/D BHA #4. R/U casing. RIH casing. md Gas Summary C-4i C-4n 0 C-5n 00 0 0 Average 0 0 0 Depth 0 0 0 0 0 00 0 C-2 C-3C-1 Logging Engineers:Emil Opitz / Dave McKechnie (max)(current) Units* 0 0 Report By: Emil Opitz C-5i 0 . . Viscosity Depth Mud Type 12.25" LSND Bit # YP LstCht Bit Type Cor Solids (lb/100ft2) 1,3009.40 mg/l API FL 6.53.96390' 100.032.0 1-1-WT-A-E-1-NO-TD6390' 1788' EVAMAR Well: Avg (ppb Eq) 17.5 17 Date: cP PV 16 20-Jan-2012 24:00:00Time: Report #:ENI Petroleum SP23-N3 Spy Island 24 hr Max North Slope Doyon 15 AK-AM-0009110185 Customer: MBT Tools to Mud Data Lithology (%) (current) 68.0 Ss Casing Summary ClySilt 160' 2748' 6369' ShClyst Weight Current 11 Avg TuffGvlCoal 6390' 6390' 0' Current Depth: 24 Hour Progress: Daily Charges:N/DRig Activity: Rig: Job No.: Max @ ft 4.23 -MWD Summary - -A v g Min Flow In (gpm) --Min - Current Pump & Flow Data: PWD Max Max Flow In (spm) TFA pH Chlorides ROP (ft/hr) in Drilling All Circ % Size Hughes VM-3 Milltooth Condition 6390' 449.40 ml/30min Area: Location: 96% SPP (psi) Report For:Ross/Smith/BuchananTotal Charges: 20" Gallons/stroke @ Yesterday's Depth: ROP Set AtSize 178.9 X-65 6390' Grade L-80 40.0 L-80 Siltst 13 3/8" 9 5/8" Make 1.117 BTC HYDRIL 563 21.70 4602' 3 Depth (sec/qt) Density (ppg) out RPM Hours Depth in / out Footage WOB * 10000 units = 100% Gas In Air 24 hr Recap: Background Trip Maximum Minimum Chromatograph (ppm) 0 0 Finish running casing. R/D casing. M/U cement head. CBU 3.5x. Cement casing. R/D cement. Prepare to N/D. md Gas Summary C-4i C-4n 0 C-5n 00 0 0 Average 0 0 0 Depth 0 0 0 0 0 00 0 C-2 C-3C-1 Logging Engineers:Emil Opitz / Dave Le Salle (max)(current) Units* 0 0 Report By: Emil Opitz C-5i 0 . . Viscosity Depth (sec/qt) Density (ppg) out RPM Hours Depth in / out Footage WOB 13 3/8" 9 5/8" Make BTC HYDRIL 563 Grade L-80 40.0 L-80 Siltst ROP Set AtSize 178.9 X-65 6390' Gallons/stroke @ Yesterday's Depth: 20" Area: Location: 96% SPP (psi) Report For:Ross/Smith/BuchananTotal Charges: Condition 6390' 459.40 ml/30minin Drilling All Circ % Size ROP (ft/hr) Max Max Flow In (spm) TFA pH Chlorides Flow In (gpm) --Min - Current Pump & Flow Data: PWD Max @ ft 4.23 -MWD Summary - -A v g Min 6390' 6390' 0' Current Depth: 24 Hour Progress: Daily Charges:Cleaning PitsRig Activity: Rig: Job No.: Current 11 Avg TuffGvlCoal 160' 2748' 6369' ShClyst Weight Lithology (%) (current) 68.0 Ss Casing Summary ClySilt MBT Tools to Mud Data ENI Petroleum SP23-N3 Spy Island 24 hr Max North Slope Doyon 15 AK-AM-0009110185 Customer:17 21-Jan-2012 24:00:00Time: Report #: Well: Avg (ppb Eq) 17.5 17 Date: cP PV EVAMAR 6390' Cor Solids (lb/100ft2) 1,3009.40 mg/l API FL 6.43.9 YP LstCht Bit Type LSND Bit # Depth Mud Type * 10000 units = 100% Gas In Air C-5i 0 Logging Engineers:Emil Opitz / Dave Le Salle (max)(current) Units* 0 0 Report By: Emil Opitz 0 C-2 C-3C-1 0 Depth 0 0 0 0 0 00Average0 000 C-4n 0 C-5n 00 Gas Summary C-4i N/U. Set Test Plug. Change Top Rams. R/U and test BOPs. R/D testing BOPs. Install wear bushing. Freeze protect. md 0 0 Chromatograph (ppm) Maximum Minimum 24 hr Recap: Background Trip . . Density (ppg) Viscosity out (sec/qt) Bit # Casing Summary L-80 RPM 13 3/8" 9 5/8" Make 0.902 BTC HYDRIL 563 Grade L-80 40.0 ROP Set AtSize 178.9 X-65 6415' Depth Area: Location: 96% SPP (psi) Gallons/stroke @ Yesterday's Depth: Size Smith MDsi616 PDC 20" % Mud Data Hours Depth in / out Footage WOB Condition 6390' in Drilling All Circ -MWD Summary -A v g ROP (ft/hr)6409'274.6 Max Max Flow In (spm) Flow In (gpm) --Min Avg Report For:Ross/Smith/BuchananTotal Charges: Min Current Pump & Flow Data: Max @ ft 4.23 - 6390' 6415' 25' Current Depth: 24 Hour Progress: Daily Charges:Prepare for FITRig Activity: Rig: Job No.: 391.3 9.8 Bit Type TFA - Alkal Lime Current TuffGvlCoal 160' 2748' 6369' ShClystCly 13 Lithology (%) (current) 68.0 9.40 cP PV PWD Oil / Water Tools Xceed, Periscope, Telescope, ANDto API FL ENI Petroleum SP23-N3 Spy Island 24 hr Max North Slope Doyon 15 AK-AM-0009110185 Customer: 53 18 22-Jan-2012 24:00:00Time: Report #: Date:Well: Avg Ratio 64 / 36 15 Weight 6390' EVAMAR 9.40 Ss 4.4 Lst 4 10 Cht Silt Siltst 90 8 3/4" YP Cor Solids (lb/100ft2) 21.90 Mud (lb/bbl)ml/30min 6415' FazePro Depth Mud Type * 10000 units = 100% Gas In Air C-5iC-1 Logging Engineers:Emil Opitz / Dave Le Salle (max)(current) Units* 68 19 Report By: Emil Opitz 298419086 C-2 C-3 6 Depth 73 20 42 33 1 1739 109Maximum Minimum Average 49961 93617 3376413' 6391' 735 Gas Summary C-4i C-4n 13 Inspect and service top drive. M/U BHA #5. Shallow MWD test - OK. TIH to 6170' MD filling every 10 stands. Circulate and 67 Drill out cement and 25' new formation. Prepare to conduct FIT. condition mud. Perform casing test to 3000psi - OK. Cut & slip drill line. Calibrate blocks. Displace to OBM. Tag cement @ 6370' MD 451 md C-5n 0 190 63 Chromatograph (ppm) Trip 24 hr Recap: Background . . Density (ppg) Viscosity out (sec/qt)Depth Mud Type 8 3/4" 8413' FazePro YP Cor Solids (lb/100ft2) 32.00 Mud (lb/bbl) API FL Ss 4.2 LstCht Silt Siltst 100 6390' EVAMAR Well: Avg Ratio 64 / 36 27 19 23-Jan-2012 24:00:00Time: Report #: Date: ENI Petroleum SP23-N3 Spy Island 24 hr Max North Slope Doyon 15 AK-AM-0009110185 Customer: 9.50 cP PV PWD Oil / Water Tools Xceed, Periscope, Telescope, ANDto Cly Weight Lithology (%) (current) 68.0 160' 2748' 6369' ShClyst Current 16 Avg TuffGvlCoal 12.7 Bit Type TFA - Alkal Lime 559.50 ml/30min 6415' 8490' 2075' Current Depth: 24 Hour Progress: Daily Charges:Drilling AheadRig Activity: Rig: Job No.: Report For:Ross/Smith/BuchananTotal Charges: Min Current Pump & Flow Data: Max @ ft 4.23 - 460.9203.1 Max Max Flow In (spm) Flow In (gpm) --Min -A v g ROP (ft/hr)6754'245.4 -MWD Summary Condition 6415' in Drilling All Circ % Mud Data Hours Depth in / out Footage WOBSize Smith MDsi616 PDC 20" Area: Location: 96% 546 129 SPP (psi) Gallons/stroke 1931 @ Yesterday's Depth: ROP Set AtSize 178.9 X-65 8490' Depth BTC HYDRIL 563 Grade L-80 40.0 Bit # Casing Summary L-80 RPM 13 3/8" 9 5/8" Make 0.9024 * 10000 units = 100% Gas In Air 24 hr Recap: 161Background Trip Chromatograph (ppm) 442 178 C-5n 53 953 md Perform LOT to 12.1 ppg EMW. Rotary drill ahead. 91 2684 Gas Summary C-4i C-4n 99315803 9798160' 7160' 341Maximum Minimum Average 126104 59 Depth 306 150 177 185 102 113148 11919722391 C-2 C-3 Logging Engineers:Emil Opitz / Dave Le Salle (max)(current) Units* 264 121 Report By: Emil Opitz C-5iC-1 . . Density (ppg) Viscosity out (sec/qt)Depth Mud Type 8 3/4" FazePro YP Cor Solids (lb/100ft2)Mud (lb/bbl) API FL LstCht Silt Siltst 100 10100' Cly 6390' EVAMAR Well: Avg Ratio 20 24-Jan-2012 24:00:00Time: Report #: Date: ENI Petroleum SP23-N3 Spy Island 24 hr Max North Slope Doyon 15 AK-AM-0009110185 Customer: 9.45 cP PV PWD Oil / Water Tools Xceed, Periscope, Telescope, ADN6Cto Mud Data Lithology (%) (current) 68.0 Ss 160' 2748' 6369' ShClyst Weight Current Avg TuffGvlCoal Bit Type TFA - Alkal Lime 519.45 ml/30min -A v g 8490' 9971' 1481' Current Depth: 24 Hour Progress: Daily Charges:Drilling AheadRig Activity: Rig: Job No.: Min Current Pump & Flow Data: Max @ ft 4.23 - 473.185.2 Max Max Flow In (spm) Flow In (gpm) --Min ROP (ft/hr)8836'292.6 -MWD Summary Condition 8490' in Drilling All Circ % Hours Depth in / out Footage WOBSize Smith MDsi616 PDC Area: Location: 96% 541 128 SPP (psi) Report For:Ross/Wimmer/BuchananTotal Charges: 20" Gallons/stroke 1996 @ Yesterday's Depth: ROP Set AtSize 178.9 X-65 9971' Depth BTC HYDRIL 563 Grade L-80 40.0 Bit # Casing Summary L-80 RPM 13 3/8" 9 5/8" Make 0.9024 * 10000 units = 100% Gas In Air 24 hr Recap: 85Background Trip 86 Chromatograph (ppm) 434 1941305 md NOTE: No extensive mud data due to mud engineer not being on location currently. hole sidetrack successful @ 9845' MD. Continue drilling ahead. Drill ahead to 10187' MD. Cross fault that puts us out of zone. BROOH to 9815' MD and begin open hole sidetrack. Open 3635 Gas Summary C-4i C-4n 127 C-5n 389533' 346792 1260 488Maximum Minimum Average 132888 8739' 71 Depth 417 78 195 240 66 128160 46549068 C-2 C-3 Logging Engineers:Emil Opitz / Dave Le Salle (max)(current) Units* 362 57 Report By: Emil Opitz C-5iC-1 . . Density (ppg) Viscosity out (sec/qt)Depth Mud Type 8 3/4" FazePro YP Cor Solids (lb/100ft2)Mud (lb/bbl) API FL LstCht Silt Siltst 100 10100' Cly 6390' EVAMAR Well: Avg Ratio 21 25-Jan-2012 24:00:00Time: Report #: Date: ENI Petroleum SP23-N3 Spy Island 24 hr Max North Slope Doyon 15 AK-AM-0009110185 Customer: 9.45 cP PV PWD Oil / Water Tools Xceed, Periscope, Telescope, ADN6Cto Mud Data Lithology (%) (current) 68.0 Ss Coal 13 3/8" 9 5/8" 6369' ShClyst Weight BTC HYDRIL 563 Make Avg TuffGvl Bit Type TFA - Alkal Lime 519.45 ml/30min -A v g 9971' 11825' 1854' Current Depth: 24 Hour Progress: Daily Charges:Drilling AheadRig Activity: Rig: Job No.: Current Pump & Flow Data: Max @ ft 4.23 - 475.1 - Current Max Flow In (spm) Flow In (gpm) --Min Min ROP (ft/hr)10304'223.868.0 Condition 9971' Max in Drilling All Circ % Hours Depth in / out Footage MWD Summary Area: Location: 96% 545 129 SPP (psi) Report For:Ross/Wimmer/BuchananTotal Charges: 20" Gallons/stroke 2318 @ Yesterday's Depth: ROP Set AtSize 178.9 X-65 11825' Depth WOBSize Smith MDsi616 PDC Bit # Casing Summary L-80 RPM 0.9024 Grade L-80 40.0 160' 2748' * 10000 units = 100% Gas In Air 24 hr Recap: 94Background Trip 75 1004 Chromatograph (ppm) 219 126 NOTE: No extensive mud data due to Mud Engineer not creating his report as of 0330 hrs. Drilling ahead. Gas Summary Maximum C-5i md C-4i C-4n 84 C-5n 31 3386 731 366 Minimum Average 74046 10329' 11544' 42 Depth 295 58 121 149 48 7498 6365 C-2 C-3C-1 292867 Logging Engineers:Emil Opitz / Dave Le Salle (max)(current) Units* 254 40 Report By: Emil Opitz 3024 . . Density (ppg) Viscosity out (sec/qt) 0.9024 Grade L-80 40.0 160' 2748' Bit # Casing Summary L-80 RPM ROP Set AtSize 178.9 X-65 13829' Depth WOBSize Smith MDsi616 PDC Gallons/stroke 2456 @ Yesterday's Depth: 20" Area: Location: 96% 528 125 SPP (psi) Report For:Ross/Wimmer/BuchananTotal Charges: in Drilling All Circ % Hours Depth in / out Footage MWD Summary Condition 11825' Max 13279'238.2165.9 --Min Min Current Pump & Flow Data: Max Max @ ft 4.23 - 476.3 - Current Flow In (spm) Flow In (gpm) ROP (ft/hr) 11825' 13829' 2004' Current Depth: 24 Hour Progress: Daily Charges:Drilling AheadRig Activity: Rig: Job No.: Bit Type TFA - Alkal Lime 539.40 ml/30min -A v g 17 Avg TuffGvlShClyst Weight BTC HYDRIL 563 Make Lithology (%) (current) 68.0 Ss Coal 13 3/8" 9 5/8" 6369' 9.40 cP PV PWD Oil / Water Tools Xceed, Periscope, Telescope, ADN6Cto Mud Data ENI Petroleum SP23-N3 Spy Island 24 hr Max North Slope Doyon 15 AK-AM-0009110185 Customer:22 26-Jan-2012 24:00:00Time: Report #: Date:Well: Avg Ratio 64/36 23 EVAMAR Cly 6390' 4.6 LstCht Silt Siltst 100 13828' YP Cor Solids (lb/100ft2) 32.00 Mud (lb/bbl) API FL 13.3FazePro Depth Mud Type 8 3/4" * 10000 units = 100% Gas In Air 8068 Logging Engineers:Emil Opitz / Dave Le Salle (max)(current) Units* 338 79 Report By: Emil Opitz 3321 C-2 C-3C-1 128643 69 Depth 373 102 215 192 78 125187 Minimum Average 50072 12039' 13277' 864 518 C-4i C-4n 102 C-5n 44 1172 Gas Summary Maximum C-5i md Drilling ahead. 408 272 Chromatograph (ppm) 61 557 24 hr Recap: 71Background Trip . . Density (ppg) Viscosity out (sec/qt) 0.9024 Grade L-80 40.0 160' 2748' Bit # Casing Summary L-80 RPM ROP Set AtSize 178.9 X-65 14021' Depth WOBSize Smith MDsi616 PDC Gallons/stroke 1953 @ Yesterday's Depth: 20" Area: Location: 96% 203 118 SPP (psi) Report For:Ross/Wimmer/BuchananTotal Charges: in Drilling All Circ % Hours Depth in / out Footage MWD Summary Condition 13829' Max 13889'251.9 --Min Min Current Pump & Flow Data: Max Max @ ft 4.23 - 336.3 - Current Flow In (spm) Flow In (gpm) ROP (ft/hr) 13829' 14021' 192' Current Depth: 24 Hour Progress: Daily Charges:BROOHRig Activity: Rig: Job No.: Bit Type TFA - Alkal Lime 539.40 ml/30min -A v g 16 Avg TuffGvlShClyst Weight BTC HYDRIL 563 Make Lithology (%) (current) 68.0 Ss Coal 13 3/8" 9 5/8" 6369' 9.40 cP PV PWD Oil / Water Tools Xceed, Periscope, Telescope, ADN6Cto Mud Data ENI Petroleum SP23-N3 Spy Island 24 hr Max North Slope Doyon 15 AK-AM-0009110185 Customer:23 27-Jan-2012 24:00:00Time: Report #: Date:Well: Avg Ratio 64/36 23 EVAMAR Cly 6390' LstCht Silt Siltst 14021' YP Cor Solids (lb/100ft2) 21.80 Mud (lb/bbl) API FL 13.3FazePro Depth Mud Type 8 3/4" * 10000 units = 100% Gas In Air 160171 Logging Engineers:Emil Opitz / Dave La Salle (max)(current) Units* 400 125 Report By: Emil Opitz 10456 C-2 C-3C-1 115132 91 Depth 435 148 302 230 98 170273 Minimum Average 60717 13893' 13925' 995 655 C-4i C-4n 122 C-5n 53 1042 Gas Summary Maximum C-5i md establish loss rate. Pump Safe Carb pill. 40 bph loss rate. BROOH and flow check at connections - static. Daily loss of 341 bbls. Drill ahead to TD of 14021' MD. CBU. Hole taking losses @ 13994' MD while BROOH - 160 bbl/hr. RIH to 14014' MD and 594 422 Chromatograph (ppm) 103 559 44 24 hr Recap: Background Trip . . Density (ppg) Viscosity out (sec/qt)Depth Mud Type 8 3/4" FazePro YP Cor Solids (lb/100ft2)Mud (lb/bbl) API FL LstCht Silt Siltst 14021' Cly 6390' EVAMAR Well: Avg Ratio 24 28-Jan-2012 24:00:00Time: Report #: Date: ENI Petroleum SP23-N3 Spy Island 24 hr Max North Slope Doyon 15 AK-AM-0009110185 Customer: 9.40 cP PV PWD Oil / Water Tools Xceed, Periscope, Telescope, ADN6Cto Mud Data Lithology (%) (current) 68.0 Ss Coal 13 3/8" 9 5/8" 6369' ShClyst Weight BTC HYDRIL 563 Make Avg TuffGvl Bit Type TFA - Alkal Lime 549.40 ml/30min -A v g 14021' 14021' 0' Current Depth: 24 Hour Progress: Daily Charges:BROOHRig Activity: Rig: Job No.: Max @ ft 4.23 -- Current Flow In (spm) Flow In (gpm) ROP (ft/hr) --Min Min Current Pump & Flow Data: Max Condition 14021' Max in Drilling All Circ % Hours Depth in / out Footage MWD Summary Area: Location: 96% 203 118 SPP (psi) Report For:Ross/Wimmer/BuchananTotal Charges: 20" Gallons/stroke 1953 @ Yesterday's Depth: ROP Set AtSize 178.9 X-65 14021' Depth WOBSize Smith MDsi616 PDC Bit # Casing Summary L-80 RPM 0.9024 Grade L-80 40.0 160' 2748' * 10000 units = 100% Gas In Air 24 24 hr Recap: Background Trip Chromatograph (ppm) 594 422 NOTE: No extensive mud data due to no mud report BROOH. Gas Summary Maximum C-5i md C-4i C-4n 122 C-5n 53 995 655 Minimum Average 60717 91 Depth 435 148 302 230 98 170273 10456 C-2 C-3C-1 115132 Logging Engineers:Emil Opitz / Dave La Salle (max)(current) Units* 400 125 Report By: Emil Opitz 160171 WELL NAME:SP23-N3 LOCATION:Spy Island OPERATOR:ENI Petroleum AREA:North Slope MUD CO:MI Swaco STATE:Alaska RIG:Doyon 15 SPUD:6-Jan-12 SPERRY JOB:AK-AM-0009110185 TD:27-Jan-12BIT RECORD MWD BHA# SDL RUN # Bit #Bit Type Bit Size Depth In (ft) Depth Out (ft) Footage Bit Hours TFA AVG ROP WOB (max) RPM (max) SPP (max) FLOW GPM (max) Bit Grade Remarks 2 100 1 Smith XR+ Milltooth 16"160 2762 2602 18.60 1.117 139.9 20 531 2082 817 2-1-WT-M-E-1-PN-TD Surface TD reached 3 200 2 Hughes VM -3 Milltooth 12.25"2762 4602 1840 21.90 1.117 84.0 35 850 1809 779 3-8-WT-G-F-12-LN-ROP Pulled due to low doglegs and very low ROP 4 300 3 Hughes VM -3 Milltooth 12.25"4602 6390 1788 21.70 1.117 82.4 25 878 3267 906 1-1-WT-A-E-1-NO-TD Intermediate TD reached 5 400 4 Smith MDsi616 PDC 8.75"6390 14021 7631 55.90 0.902 136.5 25 476 2615 580 0-0-NO-A-X-1-NO-TD Production TD reached WELL NAME:LOCATION: OPERATOR:AREA: MUD CO:STATE: RIG:SPUD: SPERRY JOB:TD: Water Based Mud Record 160' to 2,762' 2,762' to 6,390' Date Depth Wt Vis PV YP Gels Filt R600/R300/R200/R100/ R6/R3 Cake Solids Oil/Water Sd Pm pH MBT Pf/Mf Chlor Hard Remarks ft - MD ppg sec lb/100 lb/100ft2 m/30m Rheometer 32nds % vol % vol mg/l Ca++ 6-Jan 314 8.80 92 20 30 20/47/58 5.4 70/50/42/32/19/17 1/-2.0 1/97 0.00 0.10 9.0 24.0 .08/.52 2300 80 P/U 16" BHA 7-Jan 1297 9.10 -18 28 18/41/47 5.5 64/46/39/31/19/17 1/-3.5 .5/96 0.10 0.12 9.2 20.0 .08/.42 2900 60 Drill 16" Surface 8-Jan 2762 9.20 -20 30 19/47/56 5.3 70/50/43/34/19/17 1/-4.5 .5/95 0.20 0.12 9.3 20.0 .08/.58 2200 60 Backream 9-Jan 2762 9.30 -19 32 19/53/65 -70/51/44/35/20/19 -----8.9 ----RIH with 13 3/8 Casing 10-Jan 2762 9.40 -18 15 8/19/--51/33/27/20/8/6 -----8.2 ----Clean Pits N/D Riser 11-Jan 2762 9.30 -18 14 9/19/--50/32/27/21/8/7 -----8.3 ----Test BOP 12-Jan 2762 9.30 -18 15 8/19/--51/33/27/20/8/6 ----------P/U BHA #3, RIH 13-Jan 3983 9.20 54 12 30 14/21/27 5.0 54/42/36/29/13/11 1/-4.5 2/94 -0.13 9.7 10.0 .08/1.25 800 80 Drill Out, LOT, Drill Ahead 14-Jan 4474 9.15 54 13 28 12/21/24 4.2 54/41/35/27/12/11 1/-5.5 3/92 0.05 0.13 9.9 10.0 .11/1.35 1400 80 Drill Ahead with 12 1/4" Bit 15-Jan 4602 9.20 54 13 26 12/21/24 4.1 52/39/33/26/12/10 1/-5.5 2/92 0.05 0.10 9.8 11.5 .11/1.40 1300 80 Drill Ahead, BROOH 16-Jan 4684 9.35 59 12 28 14/24/27 3.8 52/40/34/26/13/12 1/-6.5 3/91 0.10 0.14 10.0 12.5 .14/1.36 1300 60 BROOH, RIH, Drill Ahead 17-Jan 5951 9.45 61 15 29 16/35/40 3.4 59/44/37/29/15/14 1/-7.0 3/91 0.05 0.07 9.5 16.5 .07/1.45 1350 80 Drill Ahead 18-Jan 6390 9.40 48 14 26 13/30/37 3.8 54/40/34/27/13/12 1/-6.5 3/91 0.10 0.12 9.7 18.0 .10/1.40 1300 40 Drill Ahead, BROOH 19-Jan 6390 9.40 49 15 24 13/27/34 3.8 54/39/34/26/12/11 1/-6.5 3/91 0.10 0.11 9.5 18.0 .11/.15 1300 40 BROOH, RIH w/ 9 5/8" Casing 20-Jan 6390 9.40 44 11 17 9/17/22 3.9 39/28/26/19/9/8 1/-6.5 3/91 0.10 0.10 9.4 17.5 .08/1.23 1300 40 RIH w/ 9 5/8" Casing, Cement 21-Jan 6390 9.40 45 11 17 9/17/22 3.9 39/28/24/17/9/7 1/-6.4 3/91 0.10 0.11 9.4 17.5 .10/1.22 1300 40 N/U BOP, Test BOP Oil Based Mud Record 6,390' to 14,021' Date Depth Wt Vis PV YP Gels Filt R600/R300/R200/R100/ R6/R3 Cake Corr. Solid Oil/Water Oil Pm Lime Salt Cl- Emul Stability Sd Remarks ft - MD ppg sec lb/100 lb/100ft2 m/30m Rheometer 32nds % vol % vol lb/bbl % Wt mg/L mg/l % vol 22-Jan 6415 9.40 53 13 15 7/8/9 -41/28/23/17/8/7 -/1 9.8 64/36 56 1.90 2.47 28.77 80000 380 -RIH with BHA #5, LOT 23-Jan 8415 9.50 55 16 27 10/11/12 -59/43/36/28/10/9 -/1 12.7 64/36 54 2.00 2.60 29.44 80000 750 0.10 Drill Ahead 24-Jan 9800 9.45 50 16 19 9/10/12 -51/35/30/26/10/9 -/1 12.1 66/34 56 2.00 2.60 28.68 74000 750 0.10 Drill Ahead, Sidetrack 25-Jan 11722 9.40 53 15 26 9/10/11 -53/38/31/23/10/9 -/-12.3 66/34 56 2.00 2.60 27.84 71000 680 0.15 Drill Ahead 26-Jan 13828 9.40 53 17 23 10/10/11 -57/40/33/25/11/10 -/1 13.3 64/36 54 2.00 2.60 26.18 68000 680 0.15 Drill Ahead 27-Jan 14021 9.40 53 16 23 10/10/11 -55/39/33/24/11/10 -/-13.3 64/36 54 1.80 2.34 26.18 68000 720 0.15 BROOH 28-Jan 14021 9.40 52 15 23 9/9/10 -53/38/31/23/10/9 -/-13.3 64/36 54 2.00 2.60 26.18 68000 680 0.10 BROOH 29-Jan 14021 9.40 52 15 22 9/9/10 -52/37/31/23/10/9 -/-13.4 64/36 54 2.00 2.60 25.61 66000 680 0.10 BROOH 30-Jan 14021 9.40 60 14 22 9/9/10 -50/36/29/21/10/9 -/-13.2 64/36 54 2.00 2.60 26.18 68000 660 0.01 L/D BHA #5, RIH w/ 5 1/2" Liner 31-Jan 14021 9.00 27 ---------------Displace w/ KCl/NaCl Brine 1-Feb 14021 9.00 27 ---------------L/D Drill Pipe, R/U GBR Equip 2-Feb 14021 9.00 27 ---------------R/U Slickline, Set Pump/Tubing 3-Feb 14021 9.00 27 ---------------Land 4 1/2" Prod String, Test 4-Feb 14021 -----------------N/D BOP, Rig Move SP23-N3 ENI Petroleum MI Swaco Doyon 15 9 5/8" Intermediate @ 6,375' MD Surface Section FazePro MI Spud Mud LSND AK-AM-0009110185 13 3/8" Surface @ 2,747' MD Casing Record Production Section Intermediate Section Spy Island North Slope Alaska 6-Jan-12 27-Jan-12 20" Conductor @ 160' MD Marker MD INC AZ TVD TVDSS 16" Surface Borehole 20" Conductor Shoe 160.00 1.00 164.10 160.00 106.00 SV-4 765.00 7.80 159.70 761.70 707.70 SV-3 1131.00 19.20 159.80 1118.30 1064.30 SV-2 1410.00 21.50 161.60 1379.40 1325.40 Permafrost Base 1828.00 23.00 159.60 1766.90 1712.90 SV-1 2019.00 33.60 161.90 1935.30 1881.30 Ugnu Top (UG4)2430.00 42.70 184.10 2259.80 2205.80 13 3/8" Casing Shoe 2748.70 49.20 192.30 2481.00 2427.00 TD 16" Borehole 2762.00 49.10 192.30 2489.70 2435.70 12 1/4" Intermediate Borehole UG-2 Coal Bed marker 3214.00 49.90 205.10 2784.40 2730.40 Lower Ugnu 4261.00 53.30 253.80 3438.40 3384.40 Schrader Bluff 4713.00 63.30 271.80 3682.10 3628.10 N Sequence Top 4799.00 68.00 276.10 3717.50 3663.50 N Sand Top 4930.00 75.00 283.40 3759.20 3705.20 N-2 Top 4964.00 76.70 285.30 3767.40 3713.40 N-3 Top 5006.00 77.60 287.50 3776.80 3722.80 N Sand Bottom 5127.00 79.10 293.20 3800.90 3746.90 Lower N Marker 5294.00 85.00 300.20 3822.60 3768.60 N Sequence Base 5532.00 86.20 313.10 3839.00 3785.00 OA Sand Top 6154.00 85.50 316.10 3886.20 3832.20 OA-sbl2 6256.00 87.30 315.80 3892.70 3838.80 OA-sbl3 6354.00 89.30 316.50 3895.00 3841.00 9 5/8" Intermediate Casing 6369.00 89.20 317.10 3895.20 3841.20 TD 12 1/4" Borehole 6390.00 89.10 318.00 3895.50 3841.50 8 3/4" Lateral Borehole OA-sbl3 7458.00 92.80 318.50 3882.80 3828.80 OA-sbl2 7531.00 92.70 318.90 3879.30 3825.30 OA-sbl2 8494.00 87.90 316.80 3874.00 3820.00 OA-sbl3 8547.00 87.50 316.70 3876.10 3822.10 SP23-N3 Fault A 9305.00 90.20 322.40 3887.50 3833.50 OA Sand Bottom 9609.00 94.50 332.20 3868.20 3814.30 OA-sbl4 9740.00 93.50 332.10 3859.30 3805.30 SP23-N3 Fault B 10025.00 89.00 327.10 3853.00 3799.00 OA-sbl2 10140.00 89.40 322.10 3854.90 3800.90 SP23-N3 Fault C 10205.00 90.40 318.50 3855.10 3801.10 SP23-N3 Fault D 10390.00 93.30 312.80 3847.90 3793.90 OA Sand Top 10495.00 91.90 312.10 3843.00 3789.00 OA Sand Top 10578.00 87.80 310.10 3843.10 3789.10 SP23-N3 Fault E 10686.00 89.60 310.50 3846.50 3792.50 OA Sand Top 10792.00 86.60 310.70 3850.40 3796.40 OA-sbl2 10881.00 86.70 310.50 3855.60 3801.60 OA-sbl3 10938.00 87.00 311.30 3858.70 3804.70 SP23-N3 Fault F 11035.00 89.10 312.80 3862.30 3808.30 OA-sbl4 11255.00 91.60 316.30 3863.10 3809.10 SP23-N3 Fault G 11305.00 92.40 317.00 3861.20 3807.20 OA Sand Bottom 11585.00 98.60 315.80 3830.90 3776.90 OA-sbl4 11650.00 96.70 314.70 3821.90 3767.90 SP23-N3 Fault H 12090.00 89.60 310.00 3813.50 3759.50 OA-sbl4 12241.00 92.90 311.20 3810.40 3756.40 OA-sbl3 12570.00 93.00 311.80 3795.30 3741.30 OA-sbl2 12668.50 92.30 308.50 3790.50 3736.50 SP23-N3 Fault I 13096.00 90.20 313.40 3789.00 3735.00 OA Sand Top 13336.00 84.90 310.80 3802.20 3748.20 OA-sbl2 13416.00 85.60 311.50 3809.40 3755.40 OA-sbl3 13465.00 87.60 311.90 3812.30 3758.30 TD 8 3/4" Borehole 14021.00 91.50 309.30 3806.00 3752.00 8 3/4" PB1 Sidetrack Point 9845.00 91.60 330.50 3854.50 3800.50 Fault 2 10000.00 94.30 325.80 3843.80 3789.80 TD 8 3/4" PB1 10187.00 97.60 323.10 3823.00 3769.00 SP23-N3 Interpolated Tops Well Name: Depth (MD) to ft Location: (TVD) to ft Operator:Show Report No. Show Reports Report Prepared By: Formation: Report Delivered To: Date Drilled: 4930 5120SP23-N3 Spy Island ENI Petroleum 3799 1 3759 Andrew Buchanan 17-Jan-12 N SandsEmil Opitz Dt h ft C1 C1 C1 C11300Md C h l i d ( / L ) Hydrocarbon Ratios No producible oil within these zones based upon gas and chromatograph data collected. 2804932 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 -= 1300Mud Chlorides (mg/L) = 0 0 10 1632 15704 125 2 0 113 0 12 123 #DIV/0!2 280 13 1 14072 1173 7036 4932 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 = 1300 122 Mud Chlorides (mg/L) = 1040129 4953 16188 283 10 1632 Gas Units 14556 119 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) =1300 14 1 2 0 5008 145561 1 0 15 7278 2 233Gas 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 15 3 3 7 105 50 13397 5751 0 7646 25492 1 7646 956 139 3 55 4 8 100.0 1000.0 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) =1300 6 0 6 16780 5751 50 5027 22 5 2 142 3 1838 120 7 15 735 3676 11029 299 92 Gas Units 4 10.0 NPH Oil Gas C5 -= Production Analysis Gas Oil Water x Non-Producible Hydrocarbons 6 0 6 1.0 NPH Well Name: Depth (MD) to ft Location: (TVD) to ft Operator:Show Report No. Show Reports Report Prepared By: Formation: Report Delivered To: Date Drilled: 3894 2 3885 Andrew Buchanan 18-Jan-12 OA SandsEmil Opitz 6140 6390SP23-N3 Spy Island ENI Petroleum Dt h ft C1 C1 C1 C1 1 6145 Interpretation: GU i t 1871 No producible oil within these zones based upon gas and chromatograph data collected. 1450Md C h l i d ( / L ) Hydrocarbon Ratios 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 -= 6145 Gas Units 173762 1871 366 16 80646 230 106 618 521 350 637 19 2268 82914 130 818 56 56 465 1450Mud Chlorides (mg/L) = 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 = 2 Gas Units 69758 534 553 6178 72026 1581 19 2268 Mud Chlorides (mg/L) = 229 1450 131 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 Hydrocarbon Ratios3 Gas Units 358 2072 195 16 305 56 321 6297 414 56 280 Mud Chlorides (mg/L) =1350 305 249 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 4 404 708 90111 223 127 417 313 21697 288 106 91656 1545 21 725 17 425 385 523 100.0 1000.0 NPH Depth ft Flowline Background Show ppm ppm ppm Hydrocarbon Ratios C1 -=C1/C2 = C2 -=C1/C3 = C3 -=C1/C4 = C4 -=C1/C5 = 4 474 Gas Units 222 350 60272 1331 228 127 21 271 172 269 97 491 17 6314 292 370 106 264 61817 1545 Mud Chlorides (mg/L) =1350 10.0 NPH Oil Gas C5 -= Production Analysis Gas Oil Water x Non-Producible Hydrocarbons 370 106 264 1.0 NPH Well Name: Depth (MD) to ft Location: (TVD) to ft Operator:Show Report No. Show Reports Report Prepared By: Formation: Report Delivered To: Date Drilled: 3894 Andrew Buchanan 23-Jan-12 OA SandsEmil Opitz 6700 7500SP23-N3 Spy Island ENI Petroleum 3880 3 Dt h ft C1 C1 C1 C1 1 6766 Interpretation: GU i t 1782 Non producible oil within these zones based upon gas and chromatograph data collected. 78000Md C h l i d ( / L ) Hydrocarbon Ratios 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 -= 6766 Gas Units 5463137 1782 221 91 174802 1345 1276 461 114 130 646 185 31762 206564 379 307 170 82 32 78000Mud Chlorides (mg/L) = 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 = 2 Gas Units 296031 1140 327793 1732 185 31762 1325 6992 Mud Chlorides (mg/L) = 748 78000 260 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 Hydrocarbon Ratios3 Gas Units 977 303 2093 91 345 170 487 7351 1692 385 82 Mud Chlorides (mg/L) =78000 396 175 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 4 415 1320 822 258 274 295 105 341157 363053 21896 1509 189 182 535 400 456 120 3249 1245 100.0 1000.0 NPH Depth ft Flowline Background Show ppm ppm ppm Hydrocarbon Ratios C1 -=C1/C2 = C2 -=C1/C3 = C3 -=C1/C4 = C4 -=C1/C5 = 4 1264 Gas Units 870 3564 335041 1973 265 120 385 94 1274389 295 1453 7448 505 445 182 263 356937 21896 189 Mud Chlorides (mg/L) =78000 10.0 NPH Oil Gas C5 -= Production Analysis Gas Oil Water x Non-Producible Hydrocarbons 445 182 263 1.0 NPH Well Name: Depth (MD) to ft Location: (TVD) to ft Operator:Show Report No. Show Reports Report Prepared By: Formation: Report Delivered To: Date Drilled: 3870 Andrew Buchanan 23-Jan-12 OA SandsEmil Opitz 8000 9300SP23-N3 Spy Island ENI Petroleum 3886 4 Dt h ft C1 C1 C1 C1 1 8161 Interpretation: GU i t 2684 Non producible oil within these zones based upon gas and chromatograph data collected. 80000Md C h l i d ( / L ) Hydrocarbon Ratios 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 -= 8161 Gas Units 1984373 2684 343 80 289676 1101 777 846 287 263 990 144 25152 314828 342 572 199 141 146 80000Mud Chlorides (mg/L) = 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 = 2 Gas Units 269697 740 288367 2113 97 18670 837 8492 Mud Chlorides (mg/L) = 1022 80000 364 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 Hydrocarbon Ratios3 Gas Units 1369 197 3635 53 246 133 317 8739 2387 291 94 Mud Chlorides (mg/L) =75000 264 113 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 4 396 1103 820 294 262 223 139 324528 346792 22264 1260 157 155 488 362 417 92 2335 1239 100.0 1000.0 NPH Depth ft Flowline Background Show ppm ppm ppm Hydrocarbon Ratios C1 -=C1/C2 = C2 -=C1/C3 = C3 -=C1/C4 = C4 -=C1/C5 = 4 1194 Gas Units 721 1557 323762 3234 271 68 449 208 1018386 178 1294 9052 517 446 128 318 335655 11893 100 Mud Chlorides (mg/L) =75000 10.0 NPH Oil Gas C5 -= Production Analysis Gas Oil Water x Non-Producible Hydrocarbons 446 128 318 1.0 NPH Well Name: Depth (MD) to ft Location: (TVD) to ft Operator:Show Report No. Show Reports Report Prepared By: Formation: Report Delivered To: Date Drilled: 3853 Andrew Buchanan 25-Jan-12 OA SandsEmil Opitz 10100 11300SP23-N3 Spy Island ENI Petroleum 3860 5 Dt h ft C1 C1 C1 C1 1 10263 Interpretation: GU i t 3094 Non producible oil within these zones based upon gas and chromatograph data collected. 74000Md C h l i d ( / L ) Hydrocarbon Ratios 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 -= 10263 Gas Units 1598444 3094 361 41 273242 854 615 676 231 320 731 55 8688 281930 404 536 92 60 171 74000Mud Chlorides (mg/L) = 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 = 2 Gas Units 284179 676 292867 3384 55 8688 731 10327 Mud Chlorides (mg/L) = 874 74000 420 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 Hydrocarbon Ratios3 Gas Units 1209 235 2936 41 254 92 366 10972 1754 295 60 Mud Chlorides (mg/L) =74000 325 162 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 4 313 644 818 398 214 154 112 256082 273251 17169 730 86 98 382 266 312 69 2286 1197 100.0 1000.0 NPH Depth ft Flowline Background Show ppm ppm ppm Hydrocarbon Ratios C1 -=C1/C2 = C2 -=C1/C3 = C3 -=C1/C4 = C4 -=C1/C5 = 4 739 Gas Units 710 1526 266971 2975 361 44 376 175 1027289 114 788 11178 420 341 81 260 275232 8261 49 Mud Chlorides (mg/L) =74000 10.0 NPH Oil Gas C5 -= Production Analysis Gas Oil Water x Non-Producible Hydrocarbons 341 81 260 1.0 NPH Well Name: Depth (MD) to ft Location: (TVD) to ft Operator:Show Report No. Show Reports Report Prepared By: Formation: Report Delivered To: Date Drilled: 3827 Andrew Buchanan 26-Jan-12 OA SandsEmil Opitz 11600 13100SP23-N3 Spy Island ENI Petroleum 3787 6 Dt h ft C1 C1 C1 C1 1 12281 Interpretation: GU i t 818 Non producible oil within these zones based upon gas and chromatograph data collected. 70000Md C h l i d ( / L ) Hydrocarbon Ratios 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 -= 12281 Gas Units 605433 818 436 86 87740 251 203 618 260 350 706 88 5678 93418 142 617 184 115 145 70000Mud Chlorides (mg/L) = 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 = 2 Gas Units 101063 698 106741 959 88 5678 786 12405 Mud Chlorides (mg/L) = 260 70000 145 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 Hydrocarbon Ratios3 Gas Units 421 240 1083 86 313 184 474 12952 783 355 115 Mud Chlorides (mg/L) =70000 388 129 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 4 504 869 228 132 275 183 180 114805 119714 4909 950 81 125 588 363 400 84 638 417 100.0 1000.0 NPH Depth ft Flowline Background Show ppm ppm ppm Hydrocarbon Ratios C1 -=C1/C2 = C2 -=C1/C3 = C3 -=C1/C4 = C4 -=C1/C5 = 4 813 Gas Units 211 587 102669 976 126 84 486 175 382358 183 894 13034 570 394 125 269 107578 4909 81 Mud Chlorides (mg/L) =72000 10.0 NPH Oil Gas C5 -= Production Analysis Gas Oil Water x Non-Producible Hydrocarbons 394 125 269 1.0 NPH Well Name: Depth (MD) to ft Location: (TVD) to ft Operator:Show Report No. Show Reports Report Prepared By: Formation: Report Delivered To: Date Drilled: 13300 14021SP23-N3 Spy Island ENI Petroleum 3806 7 3797 Andrew Buchanan 26-Jan-12 OA SandsEmil Opitz Dt h ft C1 C1 C1 C168000Md C h l i d ( / L ) Hydrocarbon Ratios Non producible oil within these zones based upon gas and chromatograph data collected. 99113529 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 -= 68000Mud Chlorides (mg/L) = 115 173 64 4277 110844 130 676 161 822 288 475 886 616515 991 544 69 106567 224 207 13529 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 = 68000 124 Mud Chlorides (mg/L) = 204770 13702 91357 829 64 4041 Gas Units 87316 706 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) =68000 427 161 333 101 13800 54269 307 146 496 376 232 1122Gas 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 657 398 432 115 1018 118 120856 7476 132 620 378215 183 113380 209 126 300 900 4 542 100.0 1000.0 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) =68000 435 132 303 115132 7476 118 13895 655 400 215 995 185 355 123 115 540 199 582 107656 1042 877 Gas Units 4 10.0 NPH Oil Gas C5 -= Production Analysis Gas Oil Water x Non-Producible Hydrocarbons 435 132 303 1.0 NPH DIRECTIONAL SURVEY REPORT Eni Petroleum SP23-N3 PB1 Nikaitchu q Alaska United States AK-XX-0009110185 Measured Vertical Vertical Depth Inclination Direction Depth Latitude Departure Section Dogleg (feet) (degrees) (degrees) (feet) (feet) (feet) (feet) (deg/100ft) 0.00 0.00 0.00 0.00 0.00 N 0.00 E 0.00 TIE-IN 88.00 0.17 88.17 88.00 0.00 N 0.13 E 0.00 0.19 178.00 1.28 165.95 177.99 0.97 S 0.51 E -0.97 1.39 276.00 3.19 168.91 275.91 4.70 S 1.30 E -4.70 1.95 366.00 5.58 168.77 365.64 11.45 S 2.63 E -11.45 2.66 455.00 7.23 171.79 454.08 21.24 S 4.27 E -21.24 1.89 547.00 7.16 171.88 545.36 32.65 S 5.91 E -32.65 0.08 640.00 6.51 168.09 637.70 43.55 S 7.82 E -43.55 0.85 730.00 7.53 161.27 727.02 54.12 S 10.76 E -54.12 1.46 824.00 8.38 157.26 820.12 66.27 S 15.39 E -66.27 1.08 919.00 11.46 160.62 913.69 81.56 S 21.20 E -81.56 3.30 946.38 12.03 161.32 940.50 86.83 S 23.02 E -86.83 2.15 1040.49 15.55 161.61 1031.88 108.10 S 30.14 E -108.10 3.74 1133.32 19.29 159.80 1120.44 134.31 S 39.36 E -134.31 4.07 1226.95 19.76 161.32 1208.68 163.82 S 49.77 E -163.82 0.74 1320.35 21.72 160.81 1296.03 195.10 S 60.51 E -195.10 2.11 1413.50 21.50 161.67 1382.63 227.58 S 71.54 E -227.58 0.41 1507.13 22.29 160.58 1469.50 260.61 S 82.84 E -260.61 0.95 1600.50 21.97 157.87 1556.00 293.49 S 95.31 E -293.49 1.15 1693.85 22.06 160.01 1642.54 326.14 S 107.88 E -326.14 0.86 1787.12 21.76 158.55 1729.08 358.69 S 120.19 E -358.69 0.67 1880.28 24.60 160.83 1814.71 393.09 S 132.88 E -393.09 3.20 1973.77 31.50 161.21 1897.17 434.64 S 147.15 E -434.64 7.38 2067.09 35.74 162.61 1974.86 483.76 S 163.16 E -483.76 4.62 2160.10 35.34 167.54 2050.56 535.95 S 177.08 E -535.95 3.11 2253.44 37.80 175.10 2125.56 590.85 S 185.36 E -590.85 5.49 2346.47 40.87 178.96 2197.51 649.71 S 188.35 E -649.71 4.22 2440.09 42.91 184.67 2267.23 712.13 S 186.31 E -712.13 4.62 2534.42 43.78 190.55 2335.86 776.24 S 177.71 E -776.24 4.38 2627.15 47.33 192.13 2400.78 841.13 S 164.67 E -841.13 4.02 2692.40 49.04 192.35 2444.28 888.66 S 154.36 E -888.66 2.63 2719.04 49.67 192.35 2461.64 908.40 S 150.04 E -908.40 2.36 2812.63 48.80 192.62 2522.75 977.61 S 134.71 E -977.61 0.95 2905.55 48.86 196.86 2583.93 1045.23 S 116.92 E -1045.23 3.44 2999.56 48.92 197.63 2645.74 1112.87 S 95.93 E -1112.87 0.62 3091.99 49.66 202.10 2706.05 1178.73 S 72.11 E -1178.73 3.75 3183.68 50.36 204.24 2764.97 1243.30 S 44.47 E -1243.30 1.94 3279.54 49.04 207.00 2826.98 1309.22 S 12.88 E -1309.22 2.59 3373.02 49.78 208.98 2887.81 1371.89 S 20.44 W -1371.89 1.79 3468.56 51.44 213.18 2948.45 1435.09 S 58.57 W -1435.09 3.82 3559.11 51.58 218.07 3004.83 1492.67 S 99.83 W -1492.67 4.23 3653.75 51.35 223.56 3063.81 1548.66 S 148.18 W -1548.66 4.54 3745.97 50.63 226.93 3121.87 1599.11 S 199.04 W -1599.11 2.94 3838.99 50.92 231.49 3180.71 1646.15 S 253.58 W -1646.15 3.81 3932.37 51.56 237.36 3239.21 1688.47 S 312.77 W -1688.47 4.95 4025.85 51.65 242.56 3297.29 1725.12 S 376.15 W -1725.12 4.36 4118.95 53.47 245.89 3353.90 1757.23 S 442.71 W -1757.23 3.45 4211.29 53.59 251.09 3408.81 1784.44 S 511.76 W -1784.44 4.53 4306.20 53.03 256.24 3465.54 1805.85 S 584.75 W -1805.85 4.39 4397.15 57.56 259.88 3517.32 1821.24 S 657.87 W -1821.24 5.97 4492.11 57.13 263.50 3568.57 1832.80 S 736.96 W -1832.80 3.24 4586.11 57.69 266.56 3619.21 1839.66 S 815.85 W -1839.66 2.81 4679.44 61.43 270.18 3666.50 1841.89 S 896.25 W -1841.89 5.22 4771.48 66.60 274.59 3706.82 1838.38 S 978.85 W -1838.38 7.08 4865.15 71.38 279.68 3740.42 1827.47 S 1065.55 W -1827.47 7.19 4957.60 76.60 284.99 3765.92 1808.45 S 1152.28 W -1808.45 7.90 5051.33 78.46 289.83 3786.17 1781.06 S 1239.57 W -1781.06 5.42 5138.24 79.17 293.74 3803.04 1749.42 S 1318.73 W -1749.42 4.49 5235.68 84.23 297.08 3817.10 1708.05 S 1405.77 W -1708.05 6.20 5330.58 85.52 302.21 3825.59 1661.31 S 1487.89 W -1661.31 5.55 5424.26 86.51 306.85 3832.10 1608.35 S 1564.85 W -1608.35 5.05 5512.78 86.18 311.84 3837.75 1552.37 S 1633.15 W -1552.37 5.64 5611.37 86.05 318.36 3844.43 1482.73 S 1702.54 W -1482.73 6.60 5704.60 85.17 318.23 3851.57 1413.33 S 1764.39 W -1413.33 0.95 5799.16 86.02 317.15 3858.83 1343.61 S 1827.85 W -1343.61 1.45 5892.33 85.72 317.06 3865.54 1275.53 S 1891.10 W -1275.53 0.34 5985.66 85.94 316.44 3872.33 1207.73 S 1954.88 W -1207.73 0.70 6079.19 84.78 316.40 3879.90 1140.20 S 2019.14 W -1140.20 1.24 6172.72 85.68 316.07 3887.67 1072.89 S 2083.61 W -1072.89 1.02 6265.05 87.52 315.76 3893.15 1006.69 S 2147.73 W -1006.69 2.02 6326.38 89.54 315.40 3894.72 962.90 S 2190.64 W -962.90 3.35 6391.42 89.07 318.00 3895.51 915.58 S 2235.24 W -915.58 4.06 6485.00 89.47 316.30 3896.70 846.98 S 2298.88 W -846.98 1.87 6577.99 90.27 318.63 3896.91 778.46 S 2361.74 W -778.46 2.65 6670.85 91.38 317.99 3895.58 709.13 S 2423.49 W -709.13 1.38 6764.53 92.54 318.66 3892.37 639.20 S 2485.74 W -639.20 1.43 6858.08 91.79 318.10 3888.84 569.31 S 2547.83 W -569.31 1.00 6951.46 91.29 315.78 3886.33 501.12 S 2611.56 W -501.12 2.54 7044.85 90.05 313.52 3885.24 435.49 S 2677.99 W -435.49 2.76 7137.90 88.90 311.83 3886.09 372.43 S 2746.39 W -372.43 2.20 7230.64 89.03 314.56 3887.77 308.97 S 2813.99 W -308.97 2.95 7323.57 90.90 317.36 3887.82 242.17 S 2878.58 W -242.17 3.62 7417.71 92.83 318.49 3884.76 172.34 S 2941.62 W -172.34 2.38 7511.08 92.67 318.53 3880.28 102.48 S 3003.41 W -102.48 0.18 7603.10 92.76 320.15 3875.92 32.75 S 3063.30 W -32.75 1.76 7697.03 93.57 319.52 3870.73 38.92 N 3123.79 W 38.92 1.09 7790.94 89.32 317.24 3868.37 109.08 N 3186.13 W 109.08 5.14 7884.07 88.83 316.39 3869.87 176.97 N 3249.85 W 176.97 1.05 7976.65 89.98 315.73 3870.83 243.63 N 3314.09 W 243.63 1.43 8071.45 90.46 317.39 3870.47 312.46 N 3379.27 W 312.46 1.82 8164.97 90.18 317.15 3869.95 381.16 N 3442.72 W 381.16 0.39 8257.92 89.26 316.47 3870.40 448.92 N 3506.34 W 448.92 1.23 8351.53 90.07 316.72 3870.95 516.93 N 3570.66 W 516.93 0.91 8446.04 88.24 316.90 3872.34 585.83 N 3635.34 W 585.83 1.95 8539.06 87.50 316.76 3875.80 653.62 N 3698.93 W 653.62 0.81 8633.03 87.89 316.53 3879.58 721.89 N 3763.39 W 721.89 0.48 8725.70 87.84 315.34 3883.03 788.43 N 3827.80 W 788.43 1.28 8819.03 90.48 315.01 3884.40 854.62 N 3893.58 W 854.62 2.85 8912.15 89.76 315.14 3884.20 920.55 N 3959.34 W 920.55 0.79 9006.13 89.83 316.60 3884.54 988.00 N 4024.77 W 988.00 1.56 9099.47 89.79 318.35 3884.85 1056.79 N 4087.86 W 1056.79 1.88 9192.47 88.53 319.32 3886.21 1126.79 N 4149.06 W 1126.79 1.71 9286.22 89.94 321.40 3887.46 1198.97 N 4208.86 W 1198.97 2.68 9379.91 91.26 326.59 3886.48 1274.73 N 4263.92 W 1274.73 5.72 9472.74 95.89 330.41 3880.69 1353.69 N 4312.31 W 1353.69 6.46 9566.20 95.04 332.14 3871.79 1435.27 N 4357.02 W 1435.27 2.05 9659.83 93.93 332.34 3864.47 1517.87 N 4400.50 W 1517.87 1.20 9752.27 93.39 332.07 3858.57 1599.48 N 4443.51 W 1599.48 0.65 9845.40 93.48 329.36 3852.99 1680.55 N 4488.98 W 1680.55 2.91 9938.01 93.04 327.86 3847.72 1759.48 N 4537.14 W 1759.48 1.69 10031.83 94.91 324.70 3841.22 1837.31 N 4589.09 W 1837.31 3.91 10126.65 97.55 323.11 3830.93 1913.47 N 4644.61 W 1913.47 3.25 10187.00 97.55 323.11 3823.00 1961.32 N 4680.52 W 1961.32 0.00 CALCULATION BASED ON MINIMUM CURVATURE METHOD SURVEY COORDINATES RELATIVE TO WELL SYSTEM REFERENCE POINT TVD VALUES GIVEN RELATIVE TO DRILLING MEASUREMENT POINT VERTICAL SECTION RELATIVE TO WELL HEAD VERTICAL SECTION IS COMPUTED ALONG A DIRECTION OF 0.00 DEGREES (GRID) A TOTAL CORRECTION OF 0.00 DEG FROM MAGNETIC NORTH TO GRID NORTH HAS BEEN APPLIE D HORIZONTAL DISPLACEMENT IS RELATIVE TO THE WELL HEAD. HORIZONTAL DISPLACEMENT(CLOSURE) AT 10187.00 FEET () IS 5074.85 FEET ALONG 292.74 DEGREES (GRID) Date Printed:21 February 2012 DIRECTIONAL SURVEY REPORT Eni Petroleum SP23-N3 Nikaitchu q Alaska United States AK-XX-0009110185 Measured Vertical Vertical Depth Inclination Direction Depth Latitude Departure Section Dogleg (feet) (degrees) (degrees) (feet) (feet) (feet) (feet) (deg/100ft) 0.00 0.00 0.00 0.00 0.00 N 0.00 E 0.00 TIE-IN 88.00 0.17 88.17 88.00 0.00 N 0.13 E 0.00 0.19 178.00 1.28 165.95 177.99 0.97 S 0.51 E -0.97 1.39 276.00 3.19 168.91 275.91 4.70 S 1.30 E -4.70 1.95 366.00 5.58 168.77 365.64 11.45 S 2.63 E -11.45 2.66 455.00 7.23 171.79 454.08 21.24 S 4.27 E -21.24 1.89 547.00 7.16 171.88 545.36 32.65 S 5.91 E -32.65 0.08 640.00 6.51 168.09 637.70 43.55 S 7.82 E -43.55 0.85 730.00 7.53 161.27 727.02 54.12 S 10.76 E -54.12 1.46 824.00 8.38 157.26 820.12 66.27 S 15.39 E -66.27 1.08 919.00 11.46 160.62 913.69 81.56 S 21.20 E -81.56 3.30 946.38 12.03 161.32 940.50 86.83 S 23.02 E -86.83 2.15 1040.49 15.55 161.61 1031.88 108.10 S 30.14 E -108.10 3.74 1133.32 19.29 159.80 1120.44 134.31 S 39.36 E -134.31 4.07 1226.95 19.76 161.32 1208.68 163.82 S 49.77 E -163.82 0.74 1320.35 21.72 160.81 1296.03 195.10 S 60.51 E -195.10 2.11 1413.50 21.50 161.67 1382.63 227.58 S 71.54 E -227.58 0.41 1507.13 22.29 160.58 1469.50 260.61 S 82.84 E -260.61 0.95 1600.50 21.97 157.87 1556.00 293.49 S 95.31 E -293.49 1.15 1693.85 22.06 160.01 1642.54 326.14 S 107.88 E -326.14 0.86 1787.12 21.76 158.55 1729.08 358.69 S 120.19 E -358.69 0.67 1880.28 24.60 160.83 1814.71 393.09 S 132.88 E -393.09 3.20 1973.77 31.50 161.21 1897.17 434.64 S 147.15 E -434.64 7.38 2067.09 35.74 162.61 1974.86 483.76 S 163.16 E -483.76 4.62 2160.10 35.34 167.54 2050.56 535.95 S 177.08 E -535.95 3.11 2253.44 37.80 175.10 2125.56 590.85 S 185.36 E -590.85 5.49 2346.47 40.87 178.96 2197.51 649.71 S 188.35 E -649.71 4.22 2440.09 42.91 184.67 2267.23 712.13 S 186.31 E -712.13 4.62 2534.42 43.78 190.55 2335.86 776.24 S 177.71 E -776.24 4.38 2627.15 47.33 192.13 2400.78 841.13 S 164.67 E -841.13 4.02 2692.40 49.04 192.35 2444.28 888.66 S 154.36 E -888.66 2.63 2719.04 49.67 192.35 2461.64 908.40 S 150.04 E -908.40 2.36 2812.63 48.80 192.62 2522.75 977.61 S 134.71 E -977.61 0.95 2905.55 48.86 196.86 2583.93 1045.23 S 116.92 E -1045.23 3.44 2999.56 48.92 197.63 2645.74 1112.87 S 95.93 E -1112.87 0.62 3091.99 49.66 202.10 2706.05 1178.73 S 72.11 E -1178.73 3.75 3183.68 50.36 204.24 2764.97 1243.30 S 44.47 E -1243.30 1.94 3279.54 49.04 207.00 2826.98 1309.22 S 12.88 E -1309.22 2.59 3373.02 49.78 208.98 2887.81 1371.89 S 20.44 W -1371.89 1.79 3468.56 51.44 213.18 2948.45 1435.09 S 58.57 W -1435.09 3.82 3559.11 51.58 218.07 3004.83 1492.67 S 99.83 W -1492.67 4.23 3653.75 51.35 223.56 3063.81 1548.66 S 148.18 W -1548.66 4.54 3745.97 50.63 226.93 3121.87 1599.11 S 199.04 W -1599.11 2.94 3838.99 50.92 231.49 3180.71 1646.15 S 253.58 W -1646.15 3.81 3932.37 51.56 237.36 3239.21 1688.47 S 312.77 W -1688.47 4.95 4025.85 51.65 242.56 3297.29 1725.12 S 376.15 W -1725.12 4.36 4118.95 53.47 245.89 3353.90 1757.23 S 442.71 W -1757.23 3.45 4211.29 53.59 251.09 3408.81 1784.44 S 511.76 W -1784.44 4.53 4306.20 53.03 256.24 3465.54 1805.85 S 584.75 W -1805.85 4.39 4397.15 57.56 259.88 3517.32 1821.24 S 657.87 W -1821.24 5.97 4492.11 57.13 263.50 3568.57 1832.80 S 736.96 W -1832.80 3.24 4586.11 57.69 266.56 3619.21 1839.66 S 815.85 W -1839.66 2.81 4679.44 61.43 270.18 3666.50 1841.89 S 896.25 W -1841.89 5.22 4771.48 66.60 274.59 3706.82 1838.38 S 978.85 W -1838.38 7.08 4865.15 71.38 279.68 3740.42 1827.47 S 1065.55 W -1827.47 7.19 4957.60 76.60 284.99 3765.92 1808.45 S 1152.28 W -1808.45 7.90 5051.33 78.46 289.83 3786.17 1781.06 S 1239.57 W -1781.06 5.42 5138.24 79.17 293.74 3803.04 1749.42 S 1318.73 W -1749.42 4.49 5235.68 84.23 297.08 3817.10 1708.05 S 1405.77 W -1708.05 6.20 5330.58 85.52 302.21 3825.59 1661.31 S 1487.89 W -1661.31 5.55 5424.26 86.51 306.85 3832.10 1608.35 S 1564.85 W -1608.35 5.05 5512.78 86.18 311.84 3837.75 1552.37 S 1633.15 W -1552.37 5.64 5611.37 86.05 318.36 3844.43 1482.73 S 1702.54 W -1482.73 6.60 5704.60 85.17 318.23 3851.57 1413.33 S 1764.39 W -1413.33 0.95 5799.16 86.02 317.15 3858.83 1343.61 S 1827.85 W -1343.61 1.45 5892.33 85.72 317.06 3865.54 1275.53 S 1891.10 W -1275.53 0.34 5985.66 85.94 316.44 3872.33 1207.73 S 1954.88 W -1207.73 0.70 6079.19 84.78 316.40 3879.90 1140.20 S 2019.14 W -1140.20 1.24 6172.72 85.68 316.07 3887.67 1072.89 S 2083.61 W -1072.89 1.02 6265.05 87.52 315.76 3893.15 1006.69 S 2147.73 W -1006.69 2.02 6326.38 89.54 315.40 3894.72 962.90 S 2190.64 W -962.90 3.35 6391.42 89.07 318.00 3895.51 915.58 S 2235.24 W -915.58 4.06 6485.00 89.47 316.30 3896.70 846.98 S 2298.88 W -846.98 1.87 6577.99 90.27 318.63 3896.91 778.46 S 2361.74 W -778.46 2.65 6670.85 91.38 317.99 3895.58 709.13 S 2423.49 W -709.13 1.38 6764.53 92.54 318.66 3892.37 639.20 S 2485.74 W -639.20 1.43 6858.08 91.79 318.10 3888.84 569.31 S 2547.83 W -569.31 1.00 6951.46 91.29 315.78 3886.33 501.12 S 2611.56 W -501.12 2.54 7044.85 90.05 313.52 3885.24 435.49 S 2677.99 W -435.49 2.76 7137.90 88.90 311.83 3886.09 372.43 S 2746.39 W -372.43 2.20 7230.64 89.03 314.56 3887.77 308.97 S 2813.99 W -308.97 2.95 7323.57 90.90 317.36 3887.82 242.17 S 2878.58 W -242.17 3.62 7417.71 92.83 318.49 3884.76 172.34 S 2941.62 W -172.34 2.38 7511.08 92.67 318.53 3880.28 102.48 S 3003.41 W -102.48 0.18 7603.10 92.76 320.15 3875.92 32.75 S 3063.30 W -32.75 1.76 7697.03 93.57 319.52 3870.73 38.92 N 3123.79 W 38.92 1.09 7790.94 89.32 317.24 3868.37 109.08 N 3186.13 W 109.08 5.14 7884.07 88.83 316.39 3869.87 176.97 N 3249.85 W 176.97 1.05 7976.65 89.98 315.73 3870.83 243.63 N 3314.09 W 243.63 1.43 8071.45 90.46 317.39 3870.47 312.46 N 3379.27 W 312.46 1.82 8164.97 90.18 317.15 3869.95 381.16 N 3442.72 W 381.16 0.39 8257.92 89.26 316.47 3870.40 448.92 N 3506.34 W 448.92 1.23 8351.53 90.07 316.72 3870.95 516.93 N 3570.66 W 516.93 0.91 8446.04 88.24 316.90 3872.34 585.83 N 3635.34 W 585.83 1.95 8539.06 87.50 316.76 3875.80 653.62 N 3698.93 W 653.62 0.81 8633.03 87.89 316.53 3879.58 721.89 N 3763.39 W 721.89 0.48 8725.70 87.84 315.34 3883.03 788.43 N 3827.80 W 788.43 1.28 8819.03 90.48 315.01 3884.40 854.62 N 3893.58 W 854.62 2.85 8912.15 89.76 315.14 3884.20 920.55 N 3959.34 W 920.55 0.79 9006.13 89.83 316.60 3884.54 988.00 N 4024.77 W 988.00 1.56 9099.47 89.79 318.35 3884.85 1056.79 N 4087.86 W 1056.79 1.88 9192.47 88.53 319.32 3886.21 1126.79 N 4149.06 W 1126.79 1.71 9286.22 89.94 321.40 3887.46 1198.97 N 4208.86 W 1198.97 2.68 9379.91 91.26 326.59 3886.48 1274.73 N 4263.92 W 1274.73 5.72 9472.74 95.89 330.41 3880.69 1353.69 N 4312.31 W 1353.69 6.46 9566.20 95.04 332.14 3871.79 1435.27 N 4357.02 W 1435.27 2.05 9659.83 93.93 332.34 3864.47 1517.87 N 4400.50 W 1517.87 1.20 9752.27 93.39 332.07 3858.57 1599.48 N 4443.51 W 1599.48 0.65 9845.00 91.62 330.53 3854.52 1680.73 N 4488.00 W 1680.73 2.53 9845.26 91.61 330.53 3854.51 1680.96 N 4488.13 W 1680.96 1.31 9939.22 90.58 329.87 3852.71 1762.47 N 4534.82 W 1762.47 1.31 10032.08 88.91 326.88 3853.12 1841.53 N 4583.50 W 1841.53 3.69 10125.83 89.16 322.85 3854.70 1918.17 N 4637.44 W 1918.17 4.31 10219.52 90.58 317.71 3854.91 1990.21 N 4697.28 W 1990.21 5.69 10312.97 92.94 314.82 3852.04 2057.69 N 4761.85 W 2057.69 3.99 10405.82 93.32 312.36 3846.97 2121.61 N 4828.99 W 2121.61 2.68 10499.86 91.78 312.11 3842.79 2184.76 N 4898.55 W 2184.76 1.66 10593.36 87.00 309.65 3843.78 2245.92 N 4969.21 W 2245.92 5.75 10686.61 89.63 310.50 3846.53 2305.93 N 5040.53 W 2305.93 2.96 10779.77 86.55 310.69 3849.63 2366.50 N 5111.22 W 2366.50 3.31 10873.07 86.67 310.41 3855.15 2427.05 N 5181.99 W 2427.05 0.33 10964.97 87.19 311.68 3860.07 2487.31 N 5251.20 W 2487.31 1.49 11057.54 89.74 313.21 3862.55 2549.76 N 5319.47 W 2549.76 3.21 11152.65 88.98 312.41 3863.61 2614.39 N 5389.24 W 2614.39 1.16 11245.95 91.43 316.21 3863.28 2679.54 N 5455.99 W 2679.54 4.85 11339.88 92.91 317.43 3859.72 2747.98 N 5520.21 W 2747.98 2.04 11432.70 96.15 317.16 3852.39 2815.97 N 5582.96 W 2815.97 3.50 11525.54 99.13 316.09 3840.05 2882.85 N 5646.14 W 2882.85 3.41 11619.28 98.29 315.58 3825.85 2949.31 N 5710.70 W 2949.31 1.05 11711.79 93.52 313.02 3816.34 3013.55 N 5776.54 W 3013.55 5.84 11806.03 90.59 310.00 3812.96 3075.95 N 5847.05 W 3075.95 4.46 11900.59 90.38 309.12 3812.16 3136.17 N 5919.95 W 3136.17 0.96 11993.97 89.27 309.63 3812.44 3195.41 N 5992.13 W 3195.41 1.31 12087.82 89.54 309.95 3813.42 3255.47 N 6064.24 W 3255.47 0.45 12181.45 91.44 309.84 3812.62 3315.52 N 6136.07 W 3315.52 2.03 12274.49 93.73 311.89 3808.42 3376.32 N 6206.35 W 3376.32 3.30 12367.09 93.29 312.93 3802.75 3438.66 N 6274.60 W 3438.66 1.22 12462.69 90.93 311.92 3799.23 3503.10 N 6345.11 W 3503.10 2.68 12554.76 93.01 312.53 3796.07 3564.94 N 6413.24 W 3564.94 2.35 12647.08 92.74 308.02 3791.43 3624.53 N 6483.57 W 3624.53 4.89 12739.11 90.78 310.06 3788.61 3682.46 N 6555.01 W 3682.46 3.07 12832.72 89.84 310.75 3788.10 3743.13 N 6626.29 W 3743.13 1.25 12926.03 89.73 312.26 3788.45 3804.97 N 6696.17 W 3804.97 1.62 13018.99 89.70 313.13 3788.91 3868.00 N 6764.49 W 3868.00 0.94 13113.85 90.30 313.42 3788.91 3933.03 N 6833.56 W 3933.03 0.70 13207.10 86.09 312.59 3791.85 3996.58 N 6901.70 W 3996.58 4.60 13301.45 85.04 310.50 3799.15 4058.97 N 6972.10 W 4058.97 2.47 13393.06 84.61 311.27 3807.41 4118.68 N 7041.07 W 4118.68 0.96 13488.18 88.61 312.15 3813.03 4181.85 N 7111.94 W 4181.85 4.31 13581.11 89.89 312.57 3814.25 4244.46 N 7180.60 W 4244.46 1.45 13674.36 90.68 312.89 3813.79 4307.73 N 7249.10 W 4307.73 0.91 13767.33 91.53 311.34 3811.99 4370.06 N 7318.05 W 4370.06 1.90 13861.13 91.07 310.24 3809.86 4431.33 N 7389.05 W 4431.33 1.27 13960.11 91.51 309.27 3807.64 4494.61 N 7465.12 W 4494.61 1.08 14021.00 91.51 309.27 3806.03 4533.14 N 7512.24 W 4533.14 0.00 CALCULATION BASED ON MINIMUM CURVATURE METHOD SURVEY COORDINATES RELATIVE TO WELL SYSTEM REFERENCE POINT TVD VALUES GIVEN RELATIVE TO DRILLING MEASUREMENT POINT VERTICAL SECTION RELATIVE TO WELL HEAD VERTICAL SECTION IS COMPUTED ALONG A DIRECTION OF 0.00 DEGREES (GRID) A TOTAL CORRECTION OF 0.00 DEG FROM MAGNETIC NORTH TO GRID NORTH HAS BEEN APPLIE D HORIZONTAL DISPLACEMENT IS RELATIVE TO THE WELL HEAD. HORIZONTAL DISPLACEMENT(CLOSURE) AT 14021.00 FEET IS 8774.00 FEET ALONG 301.11 DEGREES (GRID) Date Printed:21 February 2012 0 1000 2000 3000 4000 5000 6000 7000 8000 9000 10000 11000 12000 13000 14000 15000 0 4 8 12 16 20 24 28 32 Me a s u r e d D e p t h Rig Days Series1 Series2 SP23-N3 Days vs. Depth 8 Jan 2012 Reached surface TD at 1700 hrs 2672' MD / 2490' TVD 24 Jan 2012 Performed open hole sidetrack at 9845' MD at 2000 hrs 27 Jan 2012 Reached TD of the lateral section at 0150 hrs 22 Jan 2012 Drilled out cement and performed LOT to 12.1 ppg EMW. Resumed drilling. 13 Jan 2012 Drilled out cement and performed LOT to 12.1 ppg EMW. Resumed drilling 3 Jan 2012 SDL rig up unit and gas equipment 6 Jan 2012 Pre Spud meeting and well spudded 15 Jan 2012 Drilled to 4602 MD POOH at 1720 hrs due to slow ROP 16 Jan 2012 RIH and resume drilling with a new bit at 2200 hrs 18 Jan 2012 Reached intermediate TD at 1255hrs 6390' MD / 3894' TVD
