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211-141
MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg DATE: P.I. Supervisor SUBJECT: FROM: Petroleum Inspector Section:5 Township:13N Range:9E Meridian:Umiat Drilling Rig:Rig Elevation:Total Depth:19240 Lease No.:ADL0373301 Operator Rep:Suspend:X P&A: Conductor:20"O.D. Shoe@ 160 Feet Csg Cut@ Feet Surface:13-3/8"O.D. Shoe@ 2418 Feet Csg Cut@ Feet Intermediate:9-5/8"O.D. Shoe@ 10432 Feet Csg Cut@ Feet Production:O.D. Shoe@ Feet Csg Cut@ Feet Liner:4 1/2"O.D. Shoe@ 19226 Feet Csg Cut@ Feet Tubing:4-1/2"O.D. Tail@ 7574 Feet Tbg Cut@ Feet Type Plug Founded on Depth (Btm)Depth (Top)MW Above Verified Fullbore Other 10340 ft 6932 ft 6.9 ppg C.T. Tag Initial 15 min 30 min 45 min Result Tubing IA OA Remarks: Attachments: I traveled to location and met with Rich Newman representing Hilcorp. The is the reservoir abandonment plug. They previously had trouble getting a cement retainer to the target depth and were given approval to pump cement with no retainer in place. Estimated bottom of cement is 10,340 ft MD before any fall out. The coil unit was rigged up and had already ran in the hole and tagged the top of cement (TOC). They ran in the hole and tagged the TOC with 7K down weight on the 2.25-inch down jet nozzle.The minimum target depth for the TOC is 7574 ft MD. They tagged high at 6932 ft MD, showing 642 ft of cement above the targeted depth. There was no MIT requested for this plug in the sundry. There was a passing MIT-IA performed prior to pumping cement. October 24, 2025 Josh Hunt Well Bore Plug & Abandonment Nikaitchuq OI15-S4 Hilcorp Alaska LLC PTD 2111410; Sundry 325-576 none Test Data: Casing Removal: Rich Newman Casing/Tubing Data (depths are MD): Plugging Data (depths are MD): rev. 3-24-2022 2025-1024_Plug_Verification_Nikaitchuq_OI15-S4_jh From:Rixse, Melvin G (OGC) To:DOA AOGCC Prudhoe Bay Cc:AOGCC Records (CED sponsored) Subject:20251021 1606 APPROVAL FOR ABANDONMENT TOC Nikaitchuaq - OI15 Reservoir P&A (PTD#211-141) Date:Tuesday, October 21, 2025 4:09:08 PM Inspectors, FYI regarding approved TOC on well PTD 211-141. Mel Rixse Senior Petroleum Engineer (PE) Alaska Oil and Gas Conservation Commission 907-793-1231 Office 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). From: Rixse, Melvin G (OGC) Sent: Tuesday, October 21, 2025 2:28 PM To: 'Ryan Rupert' <Ryan.Rupert@hilcorp.com> Cc: Sara Hannegan <shannegan@hilcorp.com>; Darci Horner <dhorner@hilcorp.com>; Miles Shaw <Miles.Shaw@hilcorp.com>; Daniel Donovan <ddonovan@hilcorp.com>; Daniel Scarpella <Daniel.Scarpella@hilcorp.com>; Dewhurst, Andrew D (OGC) <andrew.dewhurst@alaska.gov>; Joshua Zuber <Joshua.Zuber@hilcorp.com> Subject: RE: [EXTERNAL] RE: OI15 Reservoir P&A (PTD#211-141) Ryan, AOGCC agrees with the cementing abandonment plan as described below. Mel Rixse Senior Petroleum Engineer (PE) Alaska Oil and Gas Conservation Commission 907-793-1231 Office 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 CAUTION: External sender. DO NOT open links or attachments from UNKNOWN senders. 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). From: Ryan Rupert <Ryan.Rupert@hilcorp.com> Sent: Tuesday, October 21, 2025 1:09 PM To: Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov> Cc: Sara Hannegan <shannegan@hilcorp.com>; Darci Horner <dhorner@hilcorp.com>; Miles Shaw <Miles.Shaw@hilcorp.com>; Daniel Donovan <ddonovan@hilcorp.com>; Daniel Scarpella <Daniel.Scarpella@hilcorp.com>; Dewhurst, Andrew D (OGC) <andrew.dewhurst@alaska.gov>; Joshua Zuber <Joshua.Zuber@hilcorp.com> Subject: RE: [EXTERNAL] RE: OI15 Reservoir P&A (PTD#211-141) Ok. Sounds good. 1. We will perform a witnessed tag, and if that comes in at 7574’ MD or above, we’ll call that good and rig down 2. If ToC found lower, or not found, we’ll lay in cement up to at least 7574’ (not to exceed 3000’ MD) 3. Then perform another state witnessed tag of ToC. Pass criteria = above 7574’ MD Let me know if I got any of that wrong. Thanks, Ryan Rupert WNS Ops Engineer (#4508) ODS & OPP Drill Sites 907-301-1736 (Cell) 907-777-8503 (Office) From: Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov> Sent: Tuesday, October 21, 2025 11:47 AM To: Ryan Rupert <Ryan.Rupert@hilcorp.com> Cc: Sara Hannegan <shannegan@hilcorp.com>; Darci Horner <dhorner@hilcorp.com>; Miles Shaw <Miles.Shaw@hilcorp.com>; Daniel Donovan <ddonovan@hilcorp.com>; Daniel Scarpella <Daniel.Scarpella@hilcorp.com>; Dewhurst, Andrew D (OGC) <andrew.dewhurst@alaska.gov>; Joshua Zuber <Joshua.Zuber@hilcorp.com> Subject: RE: [EXTERNAL] RE: OI15 Reservoir P&A (PTD#211-141) Ryan, If Hilcorp has a way to assure cement across all annuli from 10,206’ MD to 7936’ MD that would be satisfactory. Otherwise AOGCC would like to see cement across in all annuli at the confining intervals from 7780’ MD to 7574’ MD. Mel Rixse Senior Petroleum Engineer (PE) Alaska Oil and Gas Conservation Commission 907-793-1231 Office 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). From: Ryan Rupert <Ryan.Rupert@hilcorp.com> Sent: Tuesday, October 21, 2025 11:30 AM To: Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov> Cc: Sara Hannegan <shannegan@hilcorp.com>; Darci Horner <dhorner@hilcorp.com>; Miles Shaw <Miles.Shaw@hilcorp.com>; Daniel Donovan <ddonovan@hilcorp.com>; Daniel Scarpella <Daniel.Scarpella@hilcorp.com>; Dewhurst, Andrew D (OGC) <andrew.dewhurst@alaska.gov>; Joshua Zuber <Joshua.Zuber@hilcorp.com> Subject: RE: [EXTERNAL] RE: OI15 Reservoir P&A (PTD#211-141) Mel- See attached for annotated log of OI15. Given the confining zone top at ~8530’ MD / 3454’ TVD, Hilcorp’s position is that any cement tag at 7775’ MD / 3335’ TVD or above gives us plenty of cement above the confining zone / pool, and that additional cement above that is unnecessary. Please let us know your thoughts. Thanks, Ryan Rupert WNS Ops Engineer (#4508) ODS & OPP Drill Sites 907-301-1736 (Cell) CAUTION: External sender. DO NOT open links or attachments from UNKNOWN senders. 907-777-8503 (Office) From: Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov> Sent: Tuesday, October 21, 2025 9:01 AM To: Ryan Rupert <Ryan.Rupert@hilcorp.com> Cc: Sara Hannegan <shannegan@hilcorp.com>; Darci Horner <dhorner@hilcorp.com>; Miles Shaw <Miles.Shaw@hilcorp.com>; Daniel Donovan <ddonovan@hilcorp.com>; Daniel Scarpella <Daniel.Scarpella@hilcorp.com>; Dewhurst, Andrew D (OGC) <andrew.dewhurst@alaska.gov> Subject: [EXTERNAL] RE: OI15 Reservoir P&A (PTD#211-141) Ryan, I would like to see TOC near 7574’ MD. If you have justification for placing it at 7780’ MD, we can discuss. Mel Rixse Senior Petroleum Engineer (PE) Alaska Oil and Gas Conservation Commission 907-793-1231 Office 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. Sara, Darci Saha, Donovan, Scarpella, Dewhurst. From: Rixse, Melvin G (OGC) Sent: Monday, October 20, 2025 4:46 PM To: 'Ryan Rupert' <Ryan.Rupert@hilcorp.com> Cc: Sara Hannegan <shannegan@hilcorp.com>; Darci Horner <dhorner@hilcorp.com>; Miles Shaw <Miles.Shaw@hilcorp.com>; Daniel Donovan <ddonovan@hilcorp.com>; Daniel Scarpella <Daniel.Scarpella@hilcorp.com>; Dewhurst, Andrew D (OGC) <andrew.dewhurst@alaska.gov> Subject: RE: OI15 Reservoir P&A (PTD#211-141) Ryan, I will have to check with AOGCC geologist to assure the deeper depth covers the SB confining zones. If you have cement to the tubing tail at 7574’ MD that should be acceptable, as this 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. would be cement across all annuli. Mel Rixse Senior Petroleum Engineer (PE) Alaska Oil and Gas Conservation Commission 907-793-1231 Office 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). From: Ryan Rupert <Ryan.Rupert@hilcorp.com> Sent: Monday, October 20, 2025 4:32 PM To: Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov> Cc: Sara Hannegan <shannegan@hilcorp.com>; Darci Horner <dhorner@hilcorp.com>; Miles Shaw <Miles.Shaw@hilcorp.com>; Daniel Donovan <ddonovan@hilcorp.com>; Daniel Scarpella <Daniel.Scarpella@hilcorp.com> Subject: RE: OI15 Reservoir P&A (PTD#211-141) See below for update on OI15. Looks like we got a successful downsqueeze! Per below contingencies, Hilcorp’s amended path forward is as follows. Please let us know if this is satisfactory: 1. Rig CT back up 2. State witnessed tag of ToC a. If tag is above failed packer at 7780’ MD, RDMO b. If no cement tagged before reaching failed packer at 7780’ MD, proceed with cement job #2 3. Cement job #2 (if needed) a. No LCM required b. Given no losses, pump ~30bbls of cement laying it in from 7550’ MD up to 5580’ MD 4. State witnessed tag: cement to be above tubing tail at 7574’ MD Ryan Rupert WNS Ops Engineer (#4508) ODS & OPP Drill Sites 907-301-1736 (Cell) 907-777-8503 (Office) From: Ryan Rupert Sent: Friday, October 17, 2025 2:58 PM To: 'Rixse, Melvin G (OGC)' <melvin.rixse@alaska.gov> Cc: Sara Hannegan <shannegan@hilcorp.com>; Ryan Rupert <Ryan.Rupert@hilcorp.com>; Darci Horner <dhorner@hilcorp.com> Subject: RE: OI15 Reservoir P&A (PTD#211-141) Mel- Below is our proposed path forward we’re asking the AOGCC for approval on. We did just conduct another MIT-IA to 1500psi, and that passed, so we know our barriers / integrity haven’t changed since the last rigup. Please let me know if Hilcorp has approval for the below scope. Thanks, Proposed path forward: Document baseline injectivity: 5.0bpm at 375 WHIP Downsqueeze cement plug RIH with cementing nozzle to ~7625’ above packer fish, but below upper tubing tail Downsqueeze LCM pill to wound injection liner: Pumped Polyswell, and reduced injectivity to 4.5bpm at 700psi Downsqueeze originally planned cement volume (208bbls) possible add LCM to cement: Stop pumping when leading edge of cement reaches planned plug set depth = 10,340’ MD This places cement from 7445’ – 10,340’ MD (before any cement falls) Pumped balanced plug of 215bbls 15.8ppg class G down CT from 7445’ MD Leaving base of cement at 10,825’ MD (assuming no losses) and ToC at 7445’ MD Initial CT x Tubing pressure was 360psi, and climbed to 960psi by end of job POOH and WoC: cement in place at 19:00 10/18/25 Attempt MIT down tubing to test ToC. Obtain new injectivity data if fails: 10/20/25 10:00 MIT down tubing against cement plug to 1550psi PASSED RIH and tag ToC If no tag above packer fish, lay in cement plug #2 (possible add LCM) from 7750’ to 3000’ MD POOH and WoC MIT down tubing Tag ToC Ryan Rupert WNS Ops Engineer (#4508) ODS & OPP Drill Sites 907-301-1736 (Cell) 907-777-8503 (Office) From: Ryan Rupert Sent: Friday, October 17, 2025 11:27 AM To: Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov> Cc: Sara Hannegan <shannegan@hilcorp.com>; Ryan Rupert <Ryan.Rupert@hilcorp.com> Subject: OI15 Reservoir P&A (PTD#211-141) Hi Mel- Give me a ring when you get a chance today, please. We’re having no success getting to planned plug set depth on OI15 (PTD #211-141) reservoir P&A. I wanted to discuss contingency options for this weekend to include pivoting to a downsqueeze. Thanks, Work thus far: 8 runs over 4 days, none of which were able to get into packer fish at 7780’ MD 5 nozzle drifts (1.75” to 3.70”) 3 venturi runs: recovered sand and cement chunks Can hold ~200psi WHP, but above that well goes on vacuum Possible casing leak between 7520’ and 7780’ MD dumping in fill / solids / cement on top of packer fish at 7780’ MD. Ryan Rupert WNS Ops Engineer (#4508) ODS & OPP Drill Sites 907-301-1736 (Cell) 907-777-8503 (Office) The information contained in this email message is confidential and may be legally privileged and is intended only for the use of theindividual or entity named above. If you are not an intended recipient or if you have received this message in error, you are herebynotified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, pleaseimmediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently deletethis message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that theonward 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. The information contained in this email message is confidential and may be legally privileged and is intended only for the use of theindividual or entity named above. If you are not an intended recipient or if you have received this message in error, you are herebynotified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, pleaseimmediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently deletethis message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that theonward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibilityis accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. The information contained in this email message is confidential and may be legally privileged and is intended only for the use of theindividual or entity named above. If you are not an intended recipient or if you have received this message in error, you are herebynotified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, pleaseimmediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently deletethis message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that theonward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibilityis accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. From:Rixse, Melvin G (OGC) To:DOA AOGCC Prudhoe Bay Subject:20251020 0716 APPROVAL : OI15 Reservoir P&A (PTD#211-141) Date:Monday, October 20, 2025 7:17:33 AM Attachments:Sundry_325-576_092625.pdf Inspectors, FYI. Hilcorp is approved for downsqueeze w/o a retainer as they were not able to drift per the approved sundry (attached). Mel Rixse Senior Petroleum Engineer (PE) Alaska Oil and Gas Conservation Commission 907-793-1231 Office 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). Mel From: Rixse, Melvin G (OGC) Sent: Friday, October 17, 2025 4:42 PM To: 'Ryan Rupert' <Ryan.Rupert@hilcorp.com> Cc: Sara Hannegan <shannegan@hilcorp.com>; Darci Horner <dhorner@hilcorp.com> Subject: RE: OI15 Reservoir P&A (PTD#211-141) Ryan, Hilcorp is approved to proceed for reservoir abandonment with down squeeze w/o a retainer and additional cementing as described below. Mel Rixse Senior Petroleum Engineer (PE) Alaska Oil and Gas Conservation Commission 907-793-1231 Office 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). 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: Ryan Rupert <Ryan.Rupert@hilcorp.com> Sent: Friday, October 17, 2025 2:58 PM To: Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov> Cc: Sara Hannegan <shannegan@hilcorp.com>; Ryan Rupert <Ryan.Rupert@hilcorp.com>; Darci Horner <dhorner@hilcorp.com> Subject: RE: OI15 Reservoir P&A (PTD#211-141) Mel- Below is our proposed path forward we’re asking the AOGCC for approval on. We did just conduct another MIT-IA to 1500psi, and that passed, so we know our barriers / integrity haven’t changed since the last rigup. Please let me know if Hilcorp has approval for the below scope. Thanks, Proposed path forward: Document baseline injectivity Downsqueeze cement plug RIH with cementing nozzle to ~7625’ above packer fish, but below upper tubing tail Downsqueeze LCM pill to wound injection liner Downsqueeze originally planned cement volume (208bbls) possible add LCM to cement Stop pumping when leading edge of cement reaches planned plug set depth = 10,340’ MD This places cement from 7445’ – 10,340’ MD (before any cement falls) POOH and WoC Attempt MIT down tubing to test ToC. Obtain new injectivity data if fails RIH and tag ToC If no tag above packer fish, lay in cement plug #2 (possible add LCM) from 7750’ to 3000’ MD POOH and WoC MIT down tubing Tag ToC Ryan Rupert WNS Ops Engineer (#4508) ODS & OPP Drill Sites 907-301-1736 (Cell) 907-777-8503 (Office) From: Ryan Rupert Sent: Friday, October 17, 2025 11:27 AM To: Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov> Cc: Sara Hannegan <shannegan@hilcorp.com>; Ryan Rupert <Ryan.Rupert@hilcorp.com> Subject: OI15 Reservoir P&A (PTD#211-141) Hi Mel- Give me a ring when you get a chance today, please. We’re having no success getting to planned plug set depth on OI15 (PTD #211-141) reservoir P&A. I wanted to discuss contingency options for this weekend to include pivoting to a downsqueeze. Thanks, Work thus far: 8 runs over 4 days, none of which were able to get into packer fish at 7780’ MD 5 nozzle drifts (1.75” to 3.70”) 3 venturi runs: recovered sand and cement chunks Can hold ~200psi WHP, but above that well goes on vacuum Possible casing leak between 7520’ and 7780’ MD dumping in fill / solids / cement on top of packer fish at 7780’ MD. Ryan Rupert WNS Ops Engineer (#4508) ODS & OPP Drill Sites 907-301-1736 (Cell) 907-777-8503 (Office) The information contained in this email message is confidential and may be legally privileged and is intended only for the use of theindividual 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 theonward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibilityis 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: Abandon for sidetrack 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: Exploratory Development 3. Address:Stratigraphic Service 6. API Number: 7. If perforating:8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Yes No 9. Property Designation (Lease Number): 10. Field: 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: Junk (MD): 19,240 See schematic Casing Collapse Structural Conductor NA Surface 2,260psi Intermediate 3,090psi Production 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 NIKAITCHUQ PHL Retrievable Packer and NA 7,520' MD / 3,301' TVD and NA NA 10,432' 4-1/2" 3,715' - 3,616' 907-777-8503 ryan.rupert@hilcorp.com Operations Manager October 9, 2025 19,226'9,020' 4-1/2" 3,691' Perforation Depth MD (ft): 10,432' -19,226' 20" 13-3/8" 160' 9-5/8"10,399' 2,383' NA 5,020psi 160' 2,160' 3,715' 160' 2,418' 12.6# / L-80 TVD Burst 7,574 MD 5,750psi Hilcorp Alaska, LLC Length Size Proposed Pools: 3,615 19,226 3,616 1,156 SCHRADER BLUFF OIL Same STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0355024, ADL0373301, ADL0390616, ADL0391283 211-141 NIK OI15-S4 3800 Centerpoint Dr, Suite 1400 Anchorage, AK 99503 50-029-23460-00-00 PRESENT WELL CONDITION SUMMARY AOGCC USE ONLY NA Tubing Grade: Tubing MD (ft):Perforation Depth TVD (ft): Ryan Rupert 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: Form 10-403 Revised 06/2023 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov 325-576 By Gavin Gluyas at 10:47 am, Sep 24, 2025 Digitally signed by Sara Hannegan (2519) DN: cn=Sara Hannegan (2519) Date: 2025.09.24 10:35:46 - 08'00' Sara Hannegan (2519) A.Dewhurst 25SEP25 * BOPE pressure test to 2500 psi. 48 hour notice for opportunity to witness. * AOGCC to witness service coil tag of TOC (~7445' MD) for reservoir abandonment plug. 48 hour notice. MGR24SEP2025 DSR-9/24/25 10-404 *&: Jessie L. Chmielowski Digitally signed by Jessie L. Chmielowski Date: 2025.09.26 09:51:35 -08'00'09/26/25 RBDMS JSB 092625 Decomplete for Sidetrack Well: OI15 Well Name:OI15 API Number:50-029-23460-00-00 Current Status:Offline water injector Permit to Drill Number:211-141 First Call Engineer:Ryan Rupert (907) 301-1736 (c) Second Call Engineer:Keith Lopez (907) 903-5432 (c) Maximum Expected BHP:1,650 psi @3,691’ TVD(8.6ppg) Worst case water gradient from casing leak Max. Potential Surface Pressure: 1281 psi Using 0.1 psi/ft Brief Well Summary Water injector OI15 failed an MIT-IA in 2021. The casing integrity was ultimately proven to still be competent in 2021, and tubing holes were to blame for subsequent failing MIT-IA’s. The well was returned to injection under an AA, but later in 2021 a water breakthrough event (suspected Matrix Bypass Event: MBE) was recorded at offset producer OP14. A RWO was performed in 2022 to swap the tubing. The bottom 155’ of the completion got stuck while pulling out of hole with top fish at 7780’ MD. In 2025 CT diagnostic work found a casing leak somewhere between the upper packer and the Liner Top Packer (LTP). Given the completion fish in the hole, and the challenges of remediating the casing leak, this well will be prepared as a donor bore for sidetrack This procedure aims to abandon the reservoir, and set the well up for a sidetrack with KOP at ~2000’ MD Pertinent wellbore information: - Inclination o Goes > 70 degrees at 3375’ MD’ o Sail angle of 82 degrees from 3600 – 10,700’ MD - Critical depths: o 9-5/8” ToC: 7000’ MD /3230’ TVD (logged 2/23/12) o Injection packer: 7520’ MD /3301’ TVD (bottom of current monitorable annulus) o Top Nikaitchuq Schrader Bluff Oil Pool: 8660’ MD /3474’ TVD - 13-3/8” shoe o 1/28/12 LOT broke over at 12.3ppg EMW at 2160’ TVD Æ Fracture pressure at depth = 1381psi o 2/10/12: 13-3/8” x 9-5/8” OA freeze protected with 165bbls diesel (open shoe) Started at 1.9bpm at 550psi Ended at 1.5bpm at 1250psi Decomplete for Sidetrack Well: OI15 History: - 12/9/16: MIT-IA passed to 1640psi - 3/21/21: MIT-IA FAILED - June-2021 o Multiple tubing leaks found o CMIT-TxIA PASSED to 1650psi against an IBP set at 10,076’ MD (proves 9-5/8” integrity) - 6/24/21: AA approved for continued injection with known TxIA communication - 10/18/21 o WHIP drops from 300psi to vacuum instantaneously o Offset producer, OP14 went from 1200bopd to 99%+ WC instantly - Nov-2021: Conformance logging of injection liner finds a few possible ‘hot spots’ where localized injection may be going suggesting failed AICD’s or holes in liner - 12/1/21: Most recent sustained injection stops. Well SI. - 2022 RWO: Planned tubing swap o Released packer from 10,073’ MD. Let relax, and POOH o Get stuck while POOH with packer at 7780’ MD o Cut tubing ~1 joint above packer, and POOH with no issues o RIH to fish packer / tailpipe assembly, pulled up to 350k and pop’d free o Came out of hole with all pipe above packer, and small section of packer (parted at top packer) o Shallow packer completion set with packer at 7520’ MD / 3301’ TVD o MIT-IA passed to 1500psi (3/31/22) -3/21/25: MIT-IA to 1597psi PASSED. Proves casing from surface down to upper packer at 7520’ MD - August-2025 CT Diagnostics o Successfully made it into packer fish after milling o Milled XN-nipple at 7573’ MD to 3.80” o Drift to 13,418’ MD (weight lockup) o Nipple reducer pulled from XN-nipple at 7799’ MD (now have full 3.80” passthrough) o Drifted to 10,411’ CTMD with 3.70” nozzle o RIH and set Baker ME plug (OD = 3.58”) at 10,344’ MD (see 8/10/25 WSR for configuration) o MIT down tubing to 1650psi FAILED: indicates casing leak between 7520’ – 10,344’ MD o CT pulled plug from 10,344’ MD Decomplete for Sidetrack Well: OI15 CT Lower Abandonment Procedure 1. MIRU CT (1.75” or 2” needed) 2. PT lubricator to 250psi low / 2500psi high 3. MU 4-1/2” CIBP (see prior WSR’s for exact BHA configuration to get into injection liner) 4. RIH and set CIBP in top liner at ±10,340’ MD 5. After setting, lay in cement a. Lay in cement from top CIBP at 10,340’ to 75’ above upper production packer at 7520’ MD, placing ToC at 7445’ MD (or higher) b. 14-16# cement will be used c. Higher ToC, even by hundreds of feet is not a problem d. Volume to lay in = 208bbls 6. POOH and FP well to 2300’ with diesel (35bbls) 7. RDMO CT 8. WoC EL procedure w/ FB assist 1. Rigup FB to OA and PT lines to 250low / 1500high 2. Attempt injectivity BELOW frac gradient a. Want to pump down OA taking returns to formation b. Use diesel as working fluid c. Max surface pressure = 525psi d. Target injectivity at 2.0bpm e. Likely won’t be able to inject at high rates (or at all) 3. Attempt injectivity ABOVE frac gradient a. Target injectivity at 2.0bpm b. Max surface pressure 1250psi c.Target 20bbls injected 4. Move over to tubing and perform MIT against cement plug to 1500psi 5. MIRU EL and PT PCE to 1500 high / 250psi low 6. MU and RIH with 4-1/2” tubing cutter 7.Cut 4-1/2” tubing at 2200’ MD a. Bleed IAP down b. Hold ~200psi differential on tubing above IAP c. Make cut and look for IAP response to indicate successful communication 8. MU puncher and RIH 9. Punch at 2150’ MD a. Want to punch through 4-1/2” and 9-5/8”, but NOT 13-3/8” Service coil tag of TOC(~7445' MD). AOGCC to witness. AOGCC to witness service coil tag of TOC for reservoir abandonment plug. 24 hour notice. - mgr Decomplete for Sidetrack Well: OI15 b. Bleed OAP down c. Hold ~200psi differential on tubing/IA above OAP d. Make cut and look for OAP response to indicate successful communication 10. RDMO EL 11. Circulate from tubing to OA a. Use diesel as working fluid b. Close in IA c. Inject down tubing taking OA returns to surface d. Max pressure = 525psi e. Target 10bbls returned to surface from OA f. If can’t inject below max pressure, ok to bump up to max p = 1250psi after trying below 525psi g. Target 10bbls injected down tubing at that point and note volume returned to surface out OA (if any) 12. RDMO pumpers Decomplete for Sidetrack Well: OI15 RWO Procedure 1. MIRU Nordic #4 2. Circulate well: a. Work over fluid will be injection water (8.33ppg or heavier) b. Ensure any wellbore fluids are fully displaced with KWF either via circulation or bullheading c. Tubing volume to punches at 2150’ MD = 33bbls d. IA volume to punches at 2150’ MD = 121 bbls e. OA volume to punches at 2150’ MD = 130bbls 3. Set BPV/TWC, ND tree, NU BOP stack (see attached) a. Notify AOGCC 48 hours in advance for witness b. Test to 250psi Low /2,500psi High / 2,500psi Annular c. BOPE will be used as needed to circulate the well 4. Pull BPV/TWC 5. BOLDS and unseat tubing hanger 6. POOH laying down 4-1/2” tubing from cut at 2200’ MD 7. Makeup workstring (used 4-1/2” tubing) and 9-5/8” casing cutter 8. RIH and cut 9-5/8” casing at 2150’ MD 9. Pull 9-5/8” casing from 2150’ MD 10. MU and RIH with 13-3/8” cement retainer 11. Set 13-3/8” cement retainer at ±2100’ MD 12. Establish injectivity below retainer:Max P = 1100psi 13. Downsqueeze casing stub a. 14-16# cement will be used b. Target 150’ of cement below retainer into 9-5/8” x 13-3/8” annulus (10bbls) c.Max P = 1100psi d. Unsting from retainer when rates fall below 0.25bpm, max pressure is reached, or total volume pumped 14. Lay in 50’ of cement (8bbls) on top of cement retainer bringing ToC to 2050’ MD (planned KOP = 2000’ MD 15. Pull out of hole to 1950’ MD and hang off 4-1/2” to be used as kill string 16. MIT to 1500psi against 13-3/8” cement retainer and cement plug 17. Freeze protect kill string and annulus with diesel or dead crude (300bbls) 18. Set BPV/TWC, ND BOP 19. Install dryhole tree 20. RDMO RWO crew and equipment Attachments: 1. Current Wellbore Schematic 2. Proposed wellbore schematic 3. Nordic-4 BOPE diagram Nikaitchuq Field Last Completed: 3/29/2022 PTD: 211-141 API #: 50-029-23460-00-00 Casing 20” 20" Size ID Top Btm 1 20" NA Surface 160’ 13-3/8" 12.415" Surface 2,418' 13-3/8" 9-5/8" 8.835” Surface 10,432' 4-1/2” 4.000” 10,206' 19,226' 4-1/2” 4.000" Surface 4,946' 2 4-1/2” 4.000" 4,946' 7,510' 4-1/2” 4.000" 7,510' 7,533' 3 4-1/2” 4.000" 7,533' 7,564' 4 4-1/2” 4.000" 7,564' 7,583' JEWELRY DETAIL 5 No Top MD TVD Inc ID OD 1 2,232' 2,026' 43 3.812" 4.500" 6 3 7,573' 3,307' 83 3.81" 5.030" 4 7,574' 3,307' 83 3.958" 4.500" 5 7,780' 3,335' 81 3.850" 8.450" 6 7,799' 3,338' 81 3.725" 5.030" 7 7 7,813' 3,340' 81 3.880" 5.880" 8 8 7,815' 3,340' 81 3.880" 5.880" 997,911' 3,356' 80 3.958" 8.550" 10 10 7,936' 3,361' 80 3.958" 5.750" 11 10,206' 3,691' 83 3.850" 8.450" 11 Zonal Isolation Packers Injection Control Devices 9-5/8"4-1/2" liner to 19,226' MD/3,616' TVD, hole TD 19,240' MD OA Sand CEMENT DETAIL Cement Details Hole MD 160' 2,430' Driven 16" hole, 10.7 ppg ASL: 488 bbls, 12.5 ppg LiteCrete: 73.5 bbls, TOC at surface CASING DETAIL Wt/ Grade/ ConnType 40#, L-80, Hyd 563Intermediate 13-3/8" 12-1/4" hole, 12.5 ppg LiteCrete: 196 bbls. 2/23/2012 log shows TOC at 7,000' MD 2 8.450" Surface Conductor 7,520' 3,301' 83 Tubing (Non-coated) Tubing (TK-15XT coated) Tubing (TK-15XT coated) Production TUBING DETAIL 12.6#, L-80 Tubing (Oceanit coated) WLEG, bottom at 7,583' PHL Retrievable Packer, 9-5/8" x 4-1/2" 3.725" XN-Nipple 12.6#, L-80 Tubing (TK-15XT coated) 12.6#, L-80 12.6#, L-80 4-1/2" XN-Nipple milled to 3.81" 8/7/2025 OI15-S4 Schematic Monobore Injector Item 3.812" X-Nipple w/uncoated pups, potential injection valve location PHL Retrievable Packer, 9-5/8" x 4-1/2", w/TK-15 coated pups on either side3.850" 12.6#, L-80 68#, L-80, BTC 179#, X-65 9-5/8" 10,450' 11.6#, L-80, Hyd 521 HAL Autofill Sub Mirage Plug with Auto-fill valve No-Go Locator Sub Fluted WLEG SLZXP Liner Hanger/Packer 70 degree inclination @ ~3,377' X XN Estimated Top of cement @ 7,000' XN OI15-S04 Schematic 8-12-2025 Last edited by : DH on 9/2/2025 Nikaitchuq Field Last Completed: 3/29/2022 PTD: 211-141 API #: 50-029-23460-00-00 20"Casing 20” 1 Size ID Top Btm 20"NA Surface 160’ 13-3/8" 12.415" Surface 2,418' 13-3/8" 9-5/8" 8.835”2,150'10,432' 4-1/2” 4.000” 10,206' 19,226' 4-1/2” 4.000" Surface 1,950' 4-1/2” 4.000"2,200'4,946' 4-1/2” 4.000" 4,946' 7,510' 4-1/2” 4.000" 7,510' 7,533' 4-1/2” 4.000" 7,533' 7,564' 4-1/2” 4.000" 7,564' 7,583' 2 3 No Top MD TVD Inc ID OD Item 1 2,232' 2,026' 43 3.812" 4.500" 4 3 7,573' 3,307' 83 3.81" 5.030" 4 7,574' 3,307' 83 3.958" 4.500" 5 7,780' 3,335' 81 3.850" 8.450" 6 7,799' 3,338' 81 3.725" 5.030" 7 7,813' 3,340' 81 3.880" 5.880" 8 7,815' 3,340' 81 3.880" 5.880" 9 7,911' 3,356' 80 3.958" 8.550" 5 10 7,936' 3,361' 80 3.958" 5.750" 11 10,206' 3,691' 83 3.850" 8.450" 6 12 10,340' 3,706' 84 NA 4.000" 7 89 10 Cast Iron Bridge Plug Tubing (Non-coated) 12.6#, L-80 Killstring (TK-15XT coated) 12.6#, L-80 Tubing (Oceanit coated) Tubing (TK-15XT coated) OI15-S4 Proposed Schematic - Prep for Sidetrack Final JEWELRY DETAIL PHL Retrievable Packer, 9-5/8" x 4-1/2", w/TK-15 coated pups on either side 3.812" X-Nipple w/uncoated pups, potential injection valve location HAL Autofill Sub Mirage Plug with Auto-fill valve No-Go Locator Sub Fluted WLEG SLZXP Liner Hanger/Packer 10,450' 11.6#, L-80, Hyd 521Production TUBING DETAIL 12.6#, L-80 Tubing (TK-15XT coated) 12.6#, L-80 12.6#, L-80 8.450"3.850" 4-1/2" XN-Nipple milled to 3.81" 8/7/2025 WLEG, bottom at 7,583' PHL Retrievable Packer, 9-5/8" x 4-1/2" 3.725" XN-Nipple 40#, L-80, Hyd 563Intermediate 2 Surface Conductor 7,520' 3,301' 83 Injector 12.6#, L-80 68#, L-80, BTC 179#, X-65 9-5/8" 13-3/8" 12-1/4" hole, 12.5 ppg LiteCrete: 196 bbls. 2/23/2012 log shows TOC at 7,000' MD Tubing (TK-15XT coated) CEMENT DETAIL Cement Details Hole MD 160' 2,430' Driven 16" hole, 10.7 ppg ASL: 488 bbls, 12.5 ppg LiteCrete: 73.5 bbls, TOC at surface CASING DETAIL Wt/ Grade/ ConnType 11 Zonal Isolation Packers Injection Control Devices 9-5/8"4-1/2" liner to 19,226' MD/3,616' TVD, hole TD 19,240' MD 12 OA Sand 70 degree inclination Estimated Top of cement @ 7,000' XN X PlannedTOC in 4-1/2" @ 7,445' Proposed kickoff @ 2,000'cement retainer Plannedcement retainer in 13-3/8" @ ~2,100' with~ 50' of cement above Planned4-1/2" killstring to 1,950' OI15-S04 Proposed Sidetrack Final Schematic 9-16-2025 Last edited by : DH on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n3&'&3&/$&45"/%"3%'3"$5*0/"-$"45*/(4"/(6-"3n6/-&4405)&38*4&41&$*'*&%%*.&/4*0/4"3&*/*/$)&4463'"$&'*/*4)'*--&53"%**$)".'&349n3&.07&4)"31&%(&4*/5&313&5(&0.&53*$50-&3"/$*/("41&3"/4*:.Annular2-7/8" x 5" VBR'sBlind / Shear9-5/8" fixed5k Rated Stack Sundry Application Well Name______________________________ (PTD _________; Sundry _________) Plug for Re-drill Well Workflow This process is used to identify wells that are suspended for a very short time prior to being re-drilled. Those wells that are not re-drilled immediately are identified every 6 months and assigned a current status of "Suspended." Step Task Responsible 1 The initial reviewer will check to ensure that the "Plug for Redrill" box in the upper left corner of Form 10-403 is checked. If the "Abandon" or "Suspend" boxes are also checked, cross out that erroneous entry and initial it on the Form 10-403. Geologist 2 If the “Abandon” box is checked in Box 15 (Well Status after proposed work) the initial reviewer will cross out that checkbox and instead, check the "Suspended" box and initial those changes. Geologist The drilling engineer will serve as quality control for steps 1 and 2. Petroleum Engineer (QC) 3 When the RA2 receives a Form 10-403 with a check in the "Plug for Redrill" box, they will enter the Typ_Work code "IPBRD" into the History tab for the well in RBDMS. This code automatically generates a comment in the well history that states "Intent: Plug for Redrill." Research Analyst 2 4 When the RA2 receives Form 10-407, they will check the History tab in RBDMS for the IPBRD code. If IPBRD is present and there is no evidence that a subsequent re-drill has been completed, the RA2 will assign a status of SUSPENDED to the well bore in RBDMS. The RA2 will update the status on the 10-407 form to SUSPENDED, and date and initial this change. If the RA2 does not see the "Intent: Plug for Redrill" comment or code, they will enter the status listed on the Form 10-407 into RBDMS. Research Analyst 2 5 When the Form 10-407 for the redrill is received, the RA2 will change the original well's status from SUSPENDED to ABANDONED. Research Analyst 2 6 The first week of every January and July, the RA2 and a Geologist or Reservoir Engineer will check the "Well by Type Work Outstanding" user query in RBDMS to ensure that all Plug for Redrill sundried wells have been updated to reflect current status. At this same time, they will also review the list of suspended wells for accuracy and assign expiration dates as needed. Research Analyst 2 Geologist or Reservoir Engineer NIKAITCHUQ OI15-S4 211-141 325-576 A.Dewhurst 25SEP25 A.Dewhurst 25SEP25 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:Wallace, Chris D (OGC) To:AOGCC Records (CED sponsored) Subject:FW: Not Operable: OI15-S4 (PTD# 2111410) - 30 day Injection test complete Date:Tuesday, April 22, 2025 8:06:53 AM From: Ryan Thompson <Ryan.Thompson@hilcorp.com> Sent: Monday, April 21, 2025 11:54 AM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov>; Regg, James B (OGC) <jim.regg@alaska.gov> Cc: Sara Hannegan <shannegan@hilcorp.com> Subject: Not Operable: OI15-S4 (PTD# 2111410) - 30 day Injection test complete Mr. Wallace, The 30 day injection test on PWI well OI15-S04 (PTD# 2111410) per sundry 325-127 is now complete. The well is now re-classified as Not Operable and will remain shut in. Thank you, Ryan Thompson Milne / Islands / WNS Well Integrity Engineer 907-564-5005 From: Stephen Soroka <Steve.Soroka@hilcorp.com> Sent: Saturday, March 22, 2025 3:00 PM To: chris.wallace@alaska.gov Cc: jim.regg <jim.regg@alaska.gov>; Ryan Thompson <Ryan.Thompson@hilcorp.com> Subject: RE: PWI OI15-S4 (PTD 211-141) Mr. Wallace, After further consideration, we are making PWI OI15 under evaluation per the Under Evaluation Procedure. Please contact us with any questions or concerns. Thank You Steve From: Stephen Soroka Sent: Friday, March 21, 2025 3:55 PM To: chris.wallace@alaska.gov Cc: jim.regg <jim.regg@alaska.gov>; Ryan Thompson <Ryan.Thompson@hilcorp.com> Subject: PWI OI15-S4 (PTD 211-141) Mr. Wallace PWI OI15-S4 passed an off-line charted MIT-IA to 1,597 psi. We would like to reclassify the Well from 'Not Operable' to 'Under Evaluation' to further investigate any TxIA issues while online. See attached under evaluation procedure and charted MIT-IA passing test. Please respond at your earliest convenience. Thank you Steve Soroka Hilcorp Alaska LLC Field Well Integrity Steve.Soroka@hilcorp.com P: (907) 830-8976 The information contained in this email message is confidential and may be legally privileged and is intended only for the use of theindividual or entity named above. If you are not an intended recipient or if you have received this message in error, you are herebynotified 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 theonward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibilityis accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:Wallace, Chris D (OGC) To:AOGCC Records (CED sponsored) Subject:FW: PWI OI15-S4 (PTD 211-141) Date:Monday, March 24, 2025 10:16:55 AM Attachments:SI15-S4 MIT-IA 032125.pdf OI15-S4 10-403 Mar 2025 Approved.pdf From: Stephen Soroka <Steve.Soroka@hilcorp.com> Sent: Saturday, March 22, 2025 3:00 PM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Cc: Regg, James B (OGC) <jim.regg@alaska.gov>; Ryan Thompson <Ryan.Thompson@hilcorp.com> Subject: RE: PWI OI15-S4 (PTD 211-141) Mr. Wallace, After further consideration, we are making PWI OI15 under evaluation per the Under Evaluation Procedure. Please contact us with any questions or concerns. Thank You Steve From: Stephen Soroka Sent: Friday, March 21, 2025 3:55 PM To: chris.wallace@alaska.gov Cc: jim.regg <jim.regg@alaska.gov>; Ryan Thompson <Ryan.Thompson@hilcorp.com> Subject: PWI OI15-S4 (PTD 211-141) Mr. Wallace PWI OI15-S4 passed an off-line charted MIT-IA to 1,597 psi. We would like to reclassify the Well from 'Not Operable' to 'Under Evaluation' to further investigate any TxIA issues while online. See attached under evaluation procedure and charted MIT-IA passing test. Please respond at your earliest convenience. Thank you Steve Soroka Hilcorp Alaska LLC Field Well Integrity Steve.Soroka@hilcorp.com P: (907) 830-8976 The information contained in this email message is confidential and may be legally privileged and is intended only for the use of theindividual or entity named above. If you are not an intended recipient or if you have received this message in error, you are herebynotified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, pleaseimmediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently deletethis 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 responsibilityis accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:Wallace, Chris D (OGC) To:AOGCC Records (CED sponsored) Subject:FW: PWI OI15-S4 (PTD 211-141) Date:Monday, March 24, 2025 10:14:05 AM Attachments:OI15-S4 10-403 Mar 2025 Approved.pdf SI15-S4 MIT-IA 032125.pdf From: Stephen Soroka <Steve.Soroka@hilcorp.com> Sent: Friday, March 21, 2025 3:55 PM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Cc: Regg, James B (OGC) <jim.regg@alaska.gov>; Ryan Thompson <Ryan.Thompson@hilcorp.com> Subject: PWI OI15-S4 (PTD 211-141) Mr. Wallace PWI OI15-S4 passed an off-line charted MIT-IA to 1,597 psi. We would like to reclassify the Well from 'Not Operable' to 'Under Evaluation' to further investigate any TxIA issues while online. See attached under evaluation procedure and charted MIT-IA passing test. Please respond at your earliest convenience. Thank you Steve Soroka Hilcorp Alaska LLC Field Well Integrity Steve.Soroka@hilcorp.com P: (907) 830-8976 The information contained in this email message is confidential and may be legally privileged and is intended only for the use of theindividual or entity named above. If you are not an intended recipient or if you have received this message in error, you are herebynotified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, pleaseimmediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently deletethis 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 responsibilityis accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. 10W 10.30 11:00 Mar 21 Fri 2025. _.�, au,��« oe.momr +amp wn: nmasu,�o �iM31073JAIIPVCV OIiS[WAMLAUSPRS 2.n On 321120Z59:57WAM 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: Injectivity test 2.Operator Name:4.Current Well Class:5.Permit to Drill Number: Exploratory Development 3. Address:Stratigraphic Service 6. API Number: 7. If perforating:8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Yes No 9.Property Designation (Lease Number):10. Field: 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: Junk (MD): 19,240 See schematic Casing Collapse Structural Conductor NA Surface 2,260psi Intermediate 3,090psi Production 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 Ryan Rupert 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 NA 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 ADL0355024, ADL0373301, ADL0390616, ADL0391283 211-141 C.O. 639 NIK OI15-S4 3800 Centerpoint Dr, Suite 1400 Anchorage, AK 99503 50-029-23460-00-00 Hilcorp Alaska, LLC Length Size Proposed Pools: 3,615 19,226 3,616 1,156 SCHRADER BLUFF OIL Same 12.6# / L-80 TVD Burst 7,574 MD 5,750psi 2,383' NA 5,020psi 160' 2,160' 3,715' 160' 2,418' 10,432' -19,226' 20" 13-3/8" 160' 9-5/8"10,399' 3,715' - 3,616' 907-777-8503 ryan.rupert@hilcorp.com Operations Manager March 19, 2025 19,226'9,020' 4-1/2" 3,691' Perforation Depth MD (ft): NIKAITCHUQ PHL Retrievable Packer and NA 7,520' MD / 3,301' TVD and NA NA 10,432' 4-1/2" Form 10-403 Revised 06/2023 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov 325-127 By Gavin Gluyas at 10:38 am, Mar 05, 2025 Digitally signed by Sara Hannegan (2519) DN: cn=Sara Hannegan (2519) Date: 2025.03.05 06:52:54 - 09'00' Sara Hannegan (2519) A.Dewhurst 11MAR25 Injecttivity test limited maximums of 30-days duration, 660 psi WHP, and 10,000 BWPD DSR-3/10/25MGR12MAR25 CDW 03/11/2025 Injection operations to be in accordance with AIO 36. Rule 4: 2400 psi max. at the reservoir sand-face. 10-404 *&: Jessie L. Chmielowski Digitally signed by Jessie L. Chmielowski Date: 2025.03.13 14:07:30 -08'00'03/13/25 RBDMS JSB 031825 Under Eval Injection Well: OI15 Well Name:OI15 API Number:50-029-23460-00-00 Current Status:Offline water injector Permit to Drill Number:211-141 First Call Engineer:Ryan Rupert (907) 301-1736 (c) Second Call Engineer:Keith Lopez (907) 903-5432 (c) Maximum Expected BHP:1,527 psi @3,714’ TVD(7.9ppg) SITP calculated down (May-2021) Max. Potential Surface Pressure: 1156 psi Using 0.1 psi/ft Brief Well Summary Water injector OI15 was drilled in 2012 and had no notable events until it failed an MIT-IA in 2021. Tubing holes were found and patches set to remediate. The casing integrity was ultimately proven to still be competent in 2021, and additional tubing holes were to blame for failing MIT-IA’s. The well was returned to injection under an AA, but later in 2021 a water breakthrough event (possible Matrix Bypass Event: MBE) was recorded at offset producer OP14. A RWO was performed in 2022 to swap the tubing, and restore full ID passthrough, so that liner remediation could be executed through tubing. The bottom 155’ of the completion got stuck with top fish at 7780’ MD. CT diagnostics are planned to see if passthrough can be obtained through the fish, and ultimately if a plug can be set in the injection liner and a casing MIT performed. If the direct connect / MBE is no longer present, then full passthrough ID may not be necessary, and casing integrity evaluation may be possible in the well’s current state via an inflatable plug. If the direct connect / MBE is still active, then a more aggressive CT operation (milling / swedging) will be planned to restore full ID in conjunction with evaluating the casing’s integrity. The goal of this project is to temporarily inject to see if the direct connect / MBE still exists or has healed Pertinent wellbore information: - Inclination o Goes > 70 degrees at 3375’ MD’ o Sail angle of 82 degrees from 3600 – 10,700’ MD - Critical depths: o 9-5/8” ToC: 7000’ MD /3230’ TVD (logged 2/23/12) o Injection packer: 7520’ MD /3301’ TVD (bottom of current monitorable annulus) o Top completion fish: 7780’ MD /3335’ TVD (deepest current mechanical access) o Confining interval from: 8530’ – 8950’ MD / 3444’ - 3516 TVD (72’ TVD thick) o Top Nikaitchuq Schrader Bluff Oil Pool: 8660’ MD /3474’ TVD o 9-5/8” Intermediate casing shoe: 10,432’ MD / 3714’ TVD - 9-5/8” cement o 9-5/8” intermediate casing in 12-1/4” hole Cemented with 196bbls of 12.5 ppg LiteCrete Full returns throughout job Volumetric ToC = 7044’ MD o 2/23/12 log shows ToC at 7000’ MD / 3230’ TVD Under Eval Injection Well: OI15 History: - 2012: Initial D&C: o 9-5/8” casing MIT passed to 3000psi o 9-5/8” x 13-3/8” OA has open shoe, and is monitorable - 4/13/12: initial MIT-IA PASSED to 1650psi - 12/9/16: MIT-IA passed to 1640psi - 3/21/21: MIT-IA FAILED - June-2021 o Multiple tubing leaks found o 2 patches set o Find additional leaks o CMIT-TxIA PASSED to 1650psi against an IBP set at 10,076’ MD (proves 9-5/8” integrity) - 6/24/21: AA approved for continued injection with known TxIA communication - 10/18/21 o WHIP drops from 300psi to vacuum instantaneously o Offset producer, OP14 went form 1200bopd to 99%+ WC instantly - Nov-2021: Conformance logging of injection liner finds a few possible ‘hot spots’ where localized injection may be going suggesting failed AICD’s or holes in liner - 12/1/21: Most recent sustained injection stops. Well SI. - 2022 RWO: Planned tubing swap (can’t easily remediate conformance issues in 4-1/2” liner with multiple tubing patches above) o Released packer from 10,073’ MD. Let relax, and POOH o Get stuck while POOH with packer at 7780’ MD o Cut tubing ~1 joint above packer, and POOH with no issues o RIH to fish packer / tailpipe assembly, pulled up to 350k and pop’d free o Came out of hole with all pipe above packer, and small section of packer (parted at top packer) o Multiple swedge runs: minimal footage made, can’t jar fish downward either o Multiple EL caliper log runs Finds ovalized casing right above packer fish Appear to make it into packer assembly ~10-18’ each time. Could be bottoming out on nipple reducer (2.205” ID) set in XN-nipple ~19’ below top of fish Final min ID logged inside packer fish = 3.74” o Flat bottomed mill @ 5.312” attempted to jar fish downhole (no movement) o EL drifts after down jarring suggest a 3.5” OD centralizer won’t pass top packer now (but 1.875” OD lower part of tool will and made it in 9’ (no tag) o Shallow packer completion set with packer at 7520’ MD / 3301’ TVD o MIT-IA passed to 1500psi (3/31/22) Under Eval Injection Well: OI15 Under Evaluation Injection Procedure 1. MIT-IA to 1500psi (charted) 2. Bring well online targeting rate increases of ~500bwpd each day until target rate or pressure is reached a. Max allowed WHIP = 660psi b. Upper rate limit: 10,000bwpd c. Historic injection: 6000bwpd at 515psi WHIP d. If any repressurization beyond thermal effects is noted on the IA or OA, stop injection and notify OE. 3.SI and freeze protect well after sundry limit* is reached, or surveillance results are conclusive per OE *Hilcorp requests approval to temporarily inject into OI15 for no more than 30 days at or below 660psi WHIP, with daily rates not to exceed 10,000bwpd Attachments: 1. Current Wellbore Schematic 2. OI15 log Nikaitchuq Field Well: OI15-S4 Last Completed: 3/29/2022 PTD: 211-141 API #: 50-029-23460-00-00 Casing 20” 20" Size ID Top Btm 1 20" NA Surface 160’ 13-3/8" 12.415" Surface 2,418' 13-3/8" 9-5/8" 8.835” Surface 10,432' 4-1/2” 4.000” 10,206' 19,226' 4-1/2” 4.000" Surface 4,946' 2 4-1/2” 4.000" 4,946' 7,510' 4-1/2” 4.000" 7,510' 7,533' 3 4-1/2” 4.000" 7,533' 7,564' 4 4-1/2” 4.000" 7,564' 7,583' 5 No Top MD TVD Inc ID OD 1 2,232' 2,026' 43 3.812" 4.500" 6 3 7,573' 3,307' 83 3.725" 4.500" 4 7,574' 3,307' 83 3.958" 4.500" 7 8 6 7,799' 3,338' 81 3.725" (2.205") 5.030" 977,813' 3,340' 81 3.880" 5.880" 10 8 7,815' 3,340' 81 3.880" 5.880" 9 7,911' 3,356' 80 3.958" 8.550" 10 7,936' 3,361' 80 3.958" 5.750" 11 10,206' 3,691' 83 3.850" 8.450" 11 Zonal Isolation Packers Injection Control Devices 9-5/8"4-1/2" liner to 19,226' MD/3,616' TVD, hole TD 19,240' MD OA Sand 12.6#, L-80 Tubing (TK-15XT coated) 12.6#, L-80 Schematic Injector 3.812" X-Nipple w/uncoated pups, potential injection valve location 3.725" XN-Nipple, w/uncoated pups on either side 13-3/8" 12-1/4" hole, 12.5 ppg LiteCrete: 196 bbls. 2/23/2012 log shows TOC at 7,000' MD9-5/8" 10,450' 11.6#, L-80, Hyd 521 Item Tubing (TK-15XT coated) Production TUBING DETAIL 12.6#, L-80 Tubing (Oceanit coated) CEMENT DETAIL Cement Details Hole MD 160' 2,430' Driven 16" hole, 10.7 ppg ASL: 488 bbls, 12.5 ppg LiteCrete: 73.5 bbls, TOC at surface CASING DETAIL Wt/ Grade/ ConnType 40#, L-80, Hyd 563Intermediate Surface Conductor 68#, L-80, BTC 179#, X-65 SLZXP Liner Hanger/Packer 7,520' 3,301' 83 HAL Autofill Sub Mirage Plug with Auto-fill valve No-Go Locator Sub Fluted WLEG Tubing (Non-coated) 12.6#, L-80 JEWELRY DETAIL 12.6#, L-80 Tubing (TK-15XT coated) 2 PHL Retrievable Packer, 9-5/8" x 4-1/2" PHL Retrievable Packer, 9-5/8" x 4-1/2", w/TK-15 coated pups on either side8.450" 3.725" XN-Nipple, inserted nipple reducer 2-7/8" w/2.205" NoGo XN profile WLEG, bottom at 7,583' 3.850" 8.450"3.850"813,335'7,780'5 70 degree inclination @ X XN XN XN Min ID 2.205" @7,799' Estimated Top of cement @ 7,000' Prepared by Darci Horner 3/3/2025 OP15-S04 Schematic Revamped 3-3-2025 Page 1 1 Regg, James B (OGC) From:Lopez Keith <Keith.Lopez@eni.com> Sent:Tuesday, June 27, 2023 2:15 PM To:Wallace, Chris D (OGC); Regg, James B (OGC); Brooks, Phoebe L (OGC); DOA AOGCC Prudhoe Bay Cc:Iannucci Giorgio; Carballo Nelson; Chaudhry Amjad; Vaughan Alex; Pitzalis Francesco; Lopez Keith Subject:OI15 MIT 03/30/22 Attachments:MIT NIK OI15-S4 03-30-22.xlsx; OI06-05 As Completed Feb-21-2023.pdf; OI15 MIT A annulus.pdf Attached is the waived MIT on OI15‐S4 after setting a work string in the well on 03/30/22. Keith Lopez Senior Production Engineer Eni Petroleum, Alaska 3700 Centerpoint Drive, Suite 500 Anchorage, AK 99503 Direct 907-865-3316 Mobile 907-903-5432 Keith.Lopez@eni.com ---------------------------------------------------------------------------------------------------------------------------------------------------- -------------------- Message for the recipient only, if received in error, please notify the sender and read http://www.eni.com/disclaimer/ 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. Nikaitchuq OI15-S4PTD 2111410 Submit to: OPERATOR: FIELD / UNIT / PAD: DATE: OPERATOR REP: AOGCC REP: Well Pressures:Pretest Initial 15 Min.30 Min.45 Min.60 Min. PTD 2111410 Type Inj W Tubing 17 17 17 17 18 Type Test P Packer TVD 3303 BBL Pump IA 1600 1600 1600 1600 Interval V Test psi 1500 BBL Return OA 177 179 179 179 179 Result P Well Pressures:Pretest Initial 15 Min.30 Min.45 Min.60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Well Pressures:Pretest Initial 15 Min.30 Min.45 Min.60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Well Pressures:Pretest Initial 15 Min.30 Min.45 Min.60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Well Pressures:Pretest Initial 15 Min.30 Min.45 Min.60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Well Pressures:Pretest Initial 15 Min.30 Min.45 Min.60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Well Pressures:Pretest Initial 15 Min.30 Min.45 Min.60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Well Pressures:Pretest Initial 15 Min.30 Min.45 Min.60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result TYPE INJ Codes TYPE TEST Codes INTERVAL Codes Result Codes W = Water P = Pressure Test I = Initial Test P = Pass G = Gas O = Other (describe in Notes)4 = Four Year Cycle F = Fail S = Slurry V = Required by Variance I = Inconclusive I = Industrial Wastewater O = Other (describe in notes) N = Not Injecting Notes: Eni US Operating Co Inc Nikaitchuq - OPP Matt Martyn 03/30/22 Notes:MIT after work string was set in the well. Witness was waived. Notes: Notes: Notes: OI15-S4 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test jim.regg@alaska.gov;AOGCC.Inspectors@alaska.gov;phoebe.brooks@alaska.gov chris.wallace@alaska.gov Notes: Notes: Notes: Form 10-426 (Revised 01/2017)2022-0330_MIT_Nikaitchuq_OI15-S4 J. Regg; 8/24/2023 Eni US Operating Co, Inc WELL LOG/DATA TRANSMITTAL To: ůĂƐŬĂKŝůĂŶĚ'ĂƐŽŶƐĞƌǀĂƚŝŽŶŽŵŵŝƐƐŝŽ 333 W. 7th Ave, Anchorage, AK 99501 April 28, 2022 Well:OI15-S4 Sundry 322-173 & 322-024 PTD 211-141 LWD/MWD Logs PDF LAS DLIS Excel Mudlogs E-line logs PDF LAS DLIS Excel 9-5/8" MF Caliper logs OI15-S4_MFC24_25NOV21_Centered X X OI15-S4_MFC24_25NOV21_Unentered X X PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Edgar Pinzon Mail: edgar.pinzon@eni.com Received By: ___________________________________Date:____________ Eni US Operating Co, Inc. PTD:211-141 T36502 Kayla Junke Digitally signed by Kayla Junke Date: 2022.04.28 12:52:50 -08'00' 5HJJ-DPHV% 2*& )URP 'DYH+LOHU 'DYH+LOHU#1RUGLF&DOLVWDFRP! 6HQW 7XHVGD\0DUFK $0 7R '2$$2*&&3UXGKRH%D\ 5HJJ-DPHV% 2*& %URRNV3KRHEH/ 2*& &F %HQMDPLQ:HGLQ 6XEMHFW 1RUGLF%237HVW $WWDFKPHQWV 1RUGLF2,6[OV[ ĂǀĞ,ŝůĞƌ EŽƌĚŝĐϰZŝŐDĂŶĂŐĞƌ ϲϴϱͲϭϰϳϬKĨĨŝĐĞ ϲϳϬͲϴϲϬϯŽŐŚŽƵƐĞ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ll BOPE reports are due to the agency within 5 days of testing* SSu b m i t t o :jim.regg@alaska.gov; AOGCC.Inspectors@alaska.gov; phoebe.brooks@alaska.gov Owner/Contractor: Rig No.:4 DATE: 3/15/22 Rig Rep.: Rig Phone: 907-685-1470 Operator: Op. Phone: 907-685-0710 Rep.: E-Mail Well Name: PTD #22111410 Sundry #322-024 Operation: Drilling: Workover: X Explor.: Test: Initial: Weekly: X Bi-Weekly: Other: Rams:250/3500 Annular:250/3500 Valves:250/3500 MASP:1049 MISC. INSPECTIONS: TEST DATA FLOOR SAFETY VALVES: Test Result Test Result Quantity Test Result Location Gen.P Well Sign P Upper Kelly 1P Housekeeping P Rig P Lower Kelly 1P PTD On Location P Hazard Sec.P Ball Type 1P Standing Order Posted P Misc.NA Inside BOP 1P FSV Misc 0NA BOP STACK:Quantity Size/Type Test Result MUD SYSTEM:Visual Alarm Stripper 1NATrip Tank PP Annular Preventer 1 13 5/8"P Pit Level Indicators PP #1 Rams 1 13 5/8" BSR P Flow Indicator PP #2 Rams 1 2 7/8" x5.5" vbr P Meth Gas Detector PP #3 Rams 1 2 7/8" x5.5" vbr P H2S Gas Detector PFP #4 Rams 0NAMS Misc 0NA #5 Rams 0NA #6 Rams 0NA Quantity Test Result Choke Ln. Valves 1 3 1/8"P Inside Reel valves 0NA HCR Valves 2 3 1/8"P Kill Line Valves 1 3 1/8"P Check Valve 0NAACCUMULATOR SYSTEM: BOP Misc 0NA Time/Pressure Test Result System Pressure (psi)2900 P CHOKE MANIFOLD:Pressure After Closure (psi)1850 P Quantity Test Result 200 psi Attained (sec)21 P No. Valves 14 P Full Pressure Attained (sec)85 P Manual Chokes 1P Blind Switch Covers: All stations Yes Hydraulic Chokes 1P Nitgn. Bottles # & psi (Avg.): 4@ 2850 P CH Misc 0NA ACC Misc 0NA Test Results Number of Failures:1 Test Time:7.0 Hours Repair or replacement of equipment will be made within 0 days. Remarks: AOGCC Inspection 24 hr Notice Yes Date/Time 3/13/22 @ 13:36 Waived By Test Start Date/Time:3/14/2022 19:00 (date) (time)Witness Test Finish Date/Time:3/15/2022 2:00 BOPE Test Report Notify the AOGCC of repairs with written confirmation to: AOGCC.Inspectors@alaska.gov Matt Herrera Nordic Test was conducted with 4" and 4.5" test joint. Gas and PVT alarms tested. Shaker H2S Detector failed intial test. Replaced sensor and passed re-test Dave Hiler / Nate Sipes ENI Matt Martyn / Russ Wimmer Nikaitchuq OI15-S4 Test Pressure (psi): OPPdrilling@eni.com Form 10-424 (Revised 02/2022) 2022-0315_BOP_Nordic4_Nikaitchuq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LQVHUWHG1LSSOHUHGXFHU;16W\OH1LSSOHZLWK1R*R;13URILOH+\GULO%R[[)XOO0XOH6KRHGRZQ2,6,QMHFWRU0RQRERUHZLWK,QMHFWLRQ&RQWURO 0' 0'6/=;3/LQHU+DQJHU3DFNHUò´(FF1RVH*XLGH6KRH 0'0LUDJH3OXJZLWK$XWRILOOYDOYH 0'%RWWRPRI(QWU\*XLGHa 0'3+/5HWU3DFNHUa 79'±;1LSSOHZXQFRDWHGSXSV3RWHQWLDOLQMHFWLRQYDOYHORFDWLRQ;11LSSOHZXQFRDWHGSXSV :/(* 1 Regg, James B (OGC) From:Nordic Calista Rig 4 Tool <Rigmanager.rig4@nordic-calista.com> Sent:Tuesday, March 29, 2022 10:17 AM To:DOA AOGCC Prudhoe Bay; Brooks, Phoebe L (OGC); Regg, James B (OGC) Subject:Nordic 4 BOP test 3-28-22 Attachments:Nordic 4 3-28-22 OI15-S4.xlsx Dave Hiler Nordic 4 Rig Manager 685‐1470 Office 670‐8603 Doghouse This information is intended only for the use of the individual (s) or entity (ies) named above and may contain confidential or privileged information. Any unauthorized disclosure, copying, distribution or the taking of any action in reliance on the contents of this transmitted information is strictly prohibited. If you are not the intended recipient or have received this transmission in error, please immediately delete it and any attachments from your system and send me an email confirming that you have not disclosed, copied, or distributed this message and that you have deleted this message and any attachments from your system. 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. Nikaitchuq OI15-S4 PTD 2111410 STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION *All BOPE reports are due to the agency within 5 days of testing* Submit to:jim.regg@alaska.gov; AOGCC.Inspectors@alaska.gov; phoebe.brooks@alaska.gov Owner/Contractor:Rig No.:4 DATE:3/28/22 Rig Rep.:Rig Phone:907-685-1470 Operator:Op. Phone:907-685-0710 Rep.:E-Mail Well Name:PTD #2111410 Sundry #322-024 Operation:Drilling:Workover:X Explor.: Test:Initial:Weekly:X Bi-Weekly:Other: Rams:250/3500 Annular:250/3500 Valves:250/3500 MASP:1049 MISC. INSPECTIONS:TEST DATA FLOOR SAFETY VALVES: Test Result Test Result Quantity Test Result Location Gen.P Well Sign P Upper Kelly 1 P Housekeeping P Rig P Lower Kelly 1 P PTD On Location P Hazard Sec.P Ball Type 1 P Standing Order Posted P Misc.NA Inside BOP 1 P FSV Misc 0 NA BOP STACK:Quantity Size/Type Test Result MUD SYSTEM:Visual Alarm Stripper 1 NA Trip Tank P P Annular Preventer 1 13 5/8"P Pit Level Indicators P P #1 Rams 1 13 5/8" BSR P Flow Indicator P P #2 Rams 1 2 7/8" x5.5" vbr P Meth Gas Detector P P #3 Rams 1 2 7/8" x5.5" vbr P H2S Gas Detector P P #4 Rams 0 NA MS Misc 0 NA #5 Rams 0 NA #6 Rams 0 NA Quantity Test Result Choke Ln. Valves 1 3 1/8"P Inside Reel valves 0 NA HCR Valves 2 3 1/8"P Kill Line Valves 1 3 1/8"P Check Valve 0 NA ACCUMULATOR SYSTEM: BOP Misc 0 NA Time/Pressure Test Result System Pressure (psi)2950 P CHOKE MANIFOLD:Pressure After Closure (psi)2100 P Quantity Test Result 200 psi Attained (sec)21 P No. Valves 14 P Full Pressure Attained (sec)77 P Manual Chokes 1 P Blind Switch Covers:All stations Yes Hydraulic Chokes 1 P Nitgn. Bottles # & psi (Avg.):4@ 2900 P CH Misc 0 NA ACC Misc 0 NA Test Results Number of Failures:0 Test Time:7.0 Hours Repair or replacement of equipment will be made within 0 days. Remarks: AOGCC Inspection 24 hr Notice Yes Date/Time 3/27/22@11:07 Waived By Test Start Date/Time:3/28/2022 9:30 (date)(time)Witness Test Finish Date/Time:3/28/2022 16:00 BOPE Test Report Notify the AOGCC of repairs with written confirmation to: AOGCC.Inspectors@alaska.gov Adam Earl Nordic Test was conducted with 4.5" test joint. Gas and PVT alarms tested. Dave Hiler / Jake Henry ENI Matt Martyn / Mike Aivano Nikaitchuq OI15-S4 Test Pressure (psi): OPPdrilling@eni.com Form 10-424 (Revised 02/2022)2022-0328_BOP_Nordic4_Nikaitchuq_OI15-S4 J. Regg; 3/29/2022 From:McLellan, Bryan J (OGC) To:Vaughan Alex Cc:Roby, David S (OGC); Boyer, David L (OGC) Subject:RE: [EXTERNAL] RE: OI15-S4 Sundry#322-024 Date:Thursday, March 24, 2022 3:00:00 PM Ales, You have verbal approval to run tubing and packer as you’ve proposed, with the following conditions: 1. An MITIA to 1500 psi after setting the packer is required. Provide 24 hrs notice to AOGCC opportunity to witness this test. 2. Submit a “Change approved program” sundry by close of business Monday March 28. Include my name in box 16 of the Sundry. 3. An additional Sundry will be required before beginning any injection tests. The well is not approved for sustained injection due to the high-set packer, uncertainty of cement top outside production casing and potential production casing damage below the packer. Regards Bryan McLellan Senior Petroleum Engineer Alaska Oil & Gas Conservation Commission 333 W 7th Ave Anchorage, AK 99501 Bryan.mclellan@alaska.gov +1 (907) 250-9193 From: Vaughan Alex <Alex.Vaughan@external.eni.com> Sent: Thursday, March 24, 2022 12:27 PM To: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov> Subject: RE: [EXTERNAL] RE: OI15-S4 Sundry#322-024 Bryan, We wanted to provide an update on the OI15-S4 Sundry#322-024. There is a benefit to additional diagnostics on this well prior to determining the path forward for it. To this end Eni proposes to install a packer at the bottom of the planned kill string in order to allow additional diagnostics options and provide a more robust suspension design. (see attached schematic). Currently, the tentative plan is injection of water “Eni waterflood, water” and/or fluids to heal matrix bypass events conducted jointly with an interference test program against OP10-09 and OP14-S3. Note: Eni will apply for injection approval prior to injection of diagnostic fluids into OI15-S4. 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. Alex Vaughan Sr. Drilling & Completions Compliance Engineer III Eni US Operating Co. Inc. 3700 Centerpoint Dr. Suite 500 Anchorage, AK, 99503 (907) 748-5478 M From: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov> Sent: March 21, 2022 6:27 PM To: Vaughan Alex <Alex.Vaughan@external.eni.com> Subject: [EXTERNAL] RE: OI15-S4 Sundry#322-024 This message is from an EXTERNAL SENDER to the Eni systems: pay ATTENTION, especially with links and attachments. Alex, You have approval to run the kill string and move off as planned below. Regards Bryan McLellan Senior Petroleum Engineer Alaska Oil & Gas Conservation Commission 333 W 7th Ave Anchorage, AK 99501 Bryan.mclellan@alaska.gov +1 (907) 250-9193 From: Vaughan Alex <Alex.Vaughan@external.eni.com> Sent: Monday, March 21, 2022 1:37 PM To: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov> Subject: OI15-S4 Sundry#322-024 Bryan, Reference Approved Sundry: 322-024 API: 50-029-23460-00-00 PTD: 211-141 We have a run into a bit of trouble on the OI15-S4 pulling the 4-1/2” injection completion out of the hole. The retrievable packer has hung up inside the 9-5/8” casing at 7,780’ MD and we have been unable to jar it free. Eni proposes that we install 4-1/2” tubing or 4” DP kill string to 2000’ MD to provide time to regroup and develop a plan forward. A schematic is attached illustrating the proposed kill stirring. Alex Vaughan Sr. Drilling & Completions Compliance Engineer III Eni US Operating Co. Inc. 3700 Centerpoint Dr. Suite 500 Anchorage, AK, 99503 (907) 748-5478 M ------------------------------------------------------------------------------------------------------------------------- ----------------------------------------------- Message for the recipient only, if received in error, please notify the sender and read http://www.eni.com/disclaimer/ 13-3/8" 68 ppf Casing, 2,418' MD, 2,160' TVD, 44º Inc9-5/8" 40 ppf IntermediateCasing, 10,432' MD, 3,714' TVD, 85º Inc4-½” 12.6# L80 W563, XT-15 used coated tubing 4-½” 11.6 ppf, H521 Liner, 19,226' MD, 3,616' TVD92º IncZonal Isolation PackersInjection Control DevicesPHL Retr. Packer,Original location: 10,073' MD, 3,675' TVD, 83º IncPulled out of hole to current location of 7,780' MD ConfidentialNikaitchuq Field – Oliktok Point PadProposed Suspension03-24-202210,092' MD 3.725" XN (inserted Nipple reducer 2-7/8" 6.4# XN Style Nipple with 2.205" NoGo XN Profile 27/8" 6.4# Hydril 511 Box x Full Mule Shoe downOI15-S4 Injector Monobore with Injection Control10,206' MD, 3,690' MD, SLZXP Liner Hanger/Packer4-½” Ecc-Nose Guide Shoe 10,105' MD Mirage Plug with Auto-fill valve 10,228' MD - Bottom of Entry Guide ~7500' MD PHL Retr. Packer ~2,000' TVD– 3.812" X-Nipple, w/ uncoated pups, Potential injection valve location 3.725" XN-Nipple, w/ uncoated pups & WLEG CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:McLellan, Bryan J (OGC) To:Vaughan Alex Subject:RE: OI15-S4 Sundry#322-024 Date:Monday, March 21, 2022 6:27:00 PM Alex, You have approval to run the kill string and move off as planned below. Regards Bryan McLellan Senior Petroleum Engineer Alaska Oil & Gas Conservation Commission 333 W 7th Ave Anchorage, AK 99501 Bryan.mclellan@alaska.gov +1 (907) 250-9193 From: Vaughan Alex <Alex.Vaughan@external.eni.com> Sent: Monday, March 21, 2022 1:37 PM To: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov> Subject: OI15-S4 Sundry#322-024 Bryan, Reference Approved Sundry: 322-024 API: 50-029-23460-00-00 PTD: 211-141 We have a run into a bit of trouble on the OI15-S4 pulling the 4-1/2” injection completion out of the hole. The retrievable packer has hung up inside the 9-5/8” casing at 7,780’ MD and we have been unable to jar it free. Eni proposes that we install 4-1/2” tubing or 4” DP kill string to 2000’ MD to provide time to regroup and develop a plan forward. A schematic is attached illustrating the proposed kill stirring. Alex Vaughan Sr. Drilling & Completions Compliance Engineer III Eni US Operating Co. Inc. 3700 Centerpoint Dr. Suite 500 Anchorage, AK, 99503 (907) 748-5478 M ------------------------------------------------------------------------------------------------------------------------- ----------------------------------------------- Message for the recipient only, if received in error, please notify the sender and read http://www.eni.com/disclaimer/ 1 Regg, James B (OGC) From:Regg, James B (OGC) Sent:Wednesday, March 9, 2022 9:34 AM To:Nordic Calista Rig 4 Tool; DOA AOGCC Prudhoe Bay; Brooks, Phoebe L (OGC); Carballo Nelson; Pierfelici Stefano; Benjamin Wedin; Enipetroleum OPPDrilling; Wimmer Russ; Ashley Mark; Enipetroleum AKRigClerksDoyon15; Chaudhry Amjad Subject:RE: Nordic 4 BOP test 3-7-22 Revised our copy to add # N2 bottles (4). Please adjust your report. Jim Regg Supervisor, Inspections AOGCC 333 W. 7th Ave, Suite 100 Anchorage, AK 99501 907‐793‐1236 From: Nordic Calista Rig 4 Tool <Rigmanager.rig4@nordic‐calista.com> Sent: Tuesday, March 8, 2022 6:32 PM To: DOA AOGCC Prudhoe Bay <doa.aogcc.prudhoe.bay@alaska.gov>; Brooks, Phoebe L (OGC) <phoebe.brooks@alaska.gov>; Regg, James B (OGC) <jim.regg@alaska.gov>; Carballo Nelson <Nelson.Carballo@eni.com>; Pierfelici Stefano <Stefano.Pierfelici@eni.com>; Benjamin Wedin <Benjamin.Wedin@nordic‐calista.com>; Enipetroleum OPPDrilling <OPPDrilling@eni.com>; Wimmer Russ <Russ.Wimmer@external.eni.com>; Ashley Mark <Mark.Ashley@external.eni.com>; Enipetroleum AKRigClerksDoyon15 <AKRigClerksDoyon15@eni.com>; Nordic Calista Rig 4 Tool <Rigmanager.rig4@nordic‐calista.com>; Chaudhry Amjad <Amjad.Chaudhry@eni.com> Subject: Nordic 4 BOP test 3‐7‐22 This information is intended only for the use of the individual (s) or entity (ies) named above and may contain confidential or privileged information. Any unauthorized disclosure, copying, distribution or the taking of any action in reliance on the contents of this transmitted information is strictly prohibited. If you are not the intended recipient or have received this transmission in error, please immediately delete it and any attachments from your system and send me an email confirming that you have not disclosed, copied, or distributed this message and that you have deleted this message and any attachments from your system. Some people who received this message don't often get email from rigmanager.rig4@nordic-calista.com. Learn why this is important 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. J. Regg; 3/9/2022 STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION *All BOPE reports are due to the agency within 5 days of testing* Submit to:jim.regg@alaska.gov; AOGCC.Inspectors@alaska.gov; phoebe.brooks@alaska.gov Owner/Contractor:Rig No.:4 DATE:3/7/22 Rig Rep.:Rig Phone:907-685-1470 Operator:Op. Phone:907-685-0710 Rep.:E-Mail Well Name:PTD #2111410 Sundry #322-024 Operation:Drilling:Workover:X Explor.: Test:Initial:X Weekly:Bi-Weekly:Other: Rams:250/3500 Annular:250/3500 Valves:250/3500 MASP:1049 MISC. INSPECTIONS:TEST DATA FLOOR SAFETY VALVES: Test Result Test Result Quantity Test Result Location Gen.P Well Sign P Upper Kelly 1 P Housekeeping P Rig P Lower Kelly 1 P PTD On Location P Hazard Sec.P Ball Type 1 P Standing Order Posted P Misc.NA Inside BOP 1 P FSV Misc 0 NA BOP STACK:Quantity Size/Type Test Result MUD SYSTEM:Visual Alarm Stripper 1 NA Trip Tank P P Annular Preventer 1 13 5/8"P Pit Level Indicators P P #1 Rams 1 13 5/8" BSR P Flow Indicator P P #2 Rams 1 2 7/8" x5.5" vbr P Meth Gas Detector P P #3 Rams 1 2 7/8" x5.5" vbr P H2S Gas Detector P P #4 Rams 0 NA MS Misc 0 NA #5 Rams 0 NA #6 Rams 0 NA Quantity Test Result Choke Ln. Valves 1 3 1/8"P Inside Reel valves 0 NA HCR Valves 2 3 1/8"P Kill Line Valves 1 3 1/8"P Check Valve 0 NA ACCUMULATOR SYSTEM: BOP Misc 0 NA Time/Pressure Test Result System Pressure (psi)2950 P CHOKE MANIFOLD:Pressure After Closure (psi)1950 P Quantity Test Result 200 psi Attained (sec)11 P No. Valves 14 P Full Pressure Attained (sec)80 P Manual Chokes 1 P Blind Switch Covers:All stations Yes Hydraulic Chokes 1 P Nitgn. Bottles # & psi (Avg.):4@ 2862 P CH Misc 0 NA ACC Misc 0 NA Test Results Number of Failures:0 Test Time:9.0 Hours Repair or replacement of equipment will be made within 0 days. Remarks: AOGCC Inspection 24 hr Notice Yes Date/Time 3/6/22 11:01 Waived By Test Start Date/Time:3/7/2022 13:00 (date)(time)Witness Test Finish Date/Time:3/7/2022 22:00 BOPE Test Report Notify the AOGCC of repairs with written confirmation to: AOGCC.Inspectors@alaska.gov Adam Earl Nordic Test was conducted with 4" and 4.5" test joint. Gas and PVT alarms tested. Ron Holmes / Dave Hiler ENI Mark Ashley / Russ Wimmer Nikaitchuq OI15-S4 Test Pressure (psi): OPPdrilling@eni.com Form 10-424 (Revised 02/2022)2022-0307_BOP_Nordic4_Nikaitchuq_OI15-S4 J. 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Regg, James B (CED) Cc: Pierfelici Stefano; Morgan Michael; Zuber Joshua; Dibello Mike; Atencio Lucas; Lopez Keith Subject: 0115-54 (PTD # 211-141) Attachments: 0115-54 Well Barrior Schematic.pdf Mr. Wallace, ENI is preparing a request for an Administrative Approval to allow Nikaitchuq Schrader Bluff injection well 0115-54 (PTD 211-141) to remain in water injection service with known tubing by inner annulus communication. We would like to have an initial discussion with the AOGCC to ensure we address any potential concerns in our application. Are you available for a Microsoft Teams meeting on Monday May 17 at 11 am? If not, could you propose an alternative time early next week that might work? 0115 Background 0115 is a Schrader Bluff water injector that failed it's 4 year MIT on 3/21/21. Since the failure, ENI has conducted extensive diagnostics including a tubing caliper and acoustic leak detection log. Two patches were installed across the discovered tubing leaks but the well continued to fail a MIT. The patch installation did decrease the leak rate from 1 bpm @ 750 psi to 0.4 bpm @ 600 psi. A second acoustic leak detection log detected 3 additional leak paths. ENI is currently evaluating and planning; 1) a full workover to replace the tubing in the well, 2) installing a coil tubing string within the existing tubing, and/or 3) pressure activated chemical sealant. ENI plans to continue to progress a fix for the well to restore tubing integrity regardless of the outcome of this Administrative Approval request. Well Barrier schematic (attached) shows the presence of two positive and active barrier envelopes; injected well fluid acting as primary barrier since the 0I-15 has a negative static pressure and the integrity of production casing qualified against the annulus B and original cement bond evaluation. Currently the annulus B pressure cannot be remotely monitored as it is not tied into our SCADA system. ENI will install remote pressure monitoring of this annulus as a condition of the AA. ENI has conducted a Risk Analysis with mitigation actions and will provide this to the AOGCC as part of the AA request. Please let us know of your availability for a discussion to ensure we address any concerns the AOGCC has in our AA request. Thank you. Keith Lopez Senior Production Engineer Eni Petroleum, Alaska 3700 Centerpoint Drive, Suite 500 Anchorage, AK 99503 Direct 907-865-3316 Mobile 907-903-5432 MEMORANDUM TO: Jim Regg .) { ��r� P.1. Supervisor '`L''4q `�I IZ�-Zo-1 FROM: Matt Herrera Petroleum Inspector NON -CONFIDENTIAL State of Alaska Alaska Oil and Gas Conservation Commission DATE: Friday, April 2, 2021 SUBJECT: Mechanical Integrity Tests Ent US Operating Company Inc. 0115-S4 NQCMTCHUQ OI15-S4 Src: Inspector Reviewed By.- P.l. Supry Tiz- Comm Well Name NWAITCHUQ0115-S4 API Well Number 50-029-23460-00-00 Inspector Name: Mau Herrera Permit Number: 211-141-0 Inspection Date: 3/21/1021 ' Inap Num: mi[MFH210323081445 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 0115-S4 T e In' YP J w -TVD s6�s Tubing - - 498 525 . - PTD 2111410 - Type Test SPT Test psi son IA sz3 1500 - BBL Pumped: n - BBL Returned: OA 200 - 290 - Interval 4YRTST P�ji F Notes: MIT -IA pressure was to be tested to minimum test pressure and was obtained but could not sustain. Tubing pressure increase and continuous pumping indicated communication between IA and tubing. Integrity Test was deemed a FAIL and Operator was notified to perform well ✓ diagnostics to determine cause of integrity loss. Friday, April 2, 2021 Page I of I • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jin Begg DATE: Wednesday,December 28,2016 P.I.Supervisor (Z I&e(I G' SUBJECT: Mechanical Integrity Tests ENI US OPERATING CO INC OI15-S4 FROM: Jeff Jones NIKAITCHUQ 0115-S4 Petroleum Inspector Src: Inspector Reviewed By: P.I.Suprv.iA-- NON-CONFIDENTIAL Comm Well Name NIKAITCHUQ 0115-S4 API Well Number 50-029-23460-00-00 Inspector Name: Jeff Jones Permit Number: 211-141-0 Inspection Date: 12/9/2016 Insp Num: mitJJ161212130153 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 0115-s4 'Type Inj W`TVD 3675 Tubing 458 458 - 458 - 458 PTD 2111410 - Type Test SPT Test psi! 1500 - IA 613 1651 - 1642 1640 Interval14' TST PAF P vI OA 260 270 270 - 270 Notes: 2.5 barrels diesel pumped. 1 well inspected,no exceptions noted. -' SCANNED /APR 0 5 2017, Wednesday,December 28,2016 Page 1 of 1 O C O 9 2 0) 0 O 0) 0 0 0) 0) o c6 J N N 3 + 0 t) N J J + 1D •O. ... = (1) p)— «. «. 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O FT J 0 i- J J J J W J J J J W J 3 Z I / ' / ► i / i / ' / o O I vJ/ O• �L I O 2 n II' t0 Tr N N �1ik t VN L co Q ,0)in 2 Q O p_ O li ' Z t Q O 0 Q a 2 a) O R,- ` U U J z it I A, ' C.;?< • z / z I z } i 16 o 0 / N � / U a) IL m o LE l O Z 7a m •0. g U o' m a a m Ce o T. E WN -y p) N N U Z_ m oo � Q W § J fa Z 8 a? v) Q r O O 0 _ 7 J Q c o. v E a o U U U 1I eh o 1 o 15 i O Q Q E 0 ti o z J >- >- >- , I E 5� IA N ca 4E 1 m • M U m E • M O ~ E !TA ca Ili ��1 M _ w 7 fa '^ U �� c rn N CO ~H is 0c t, U c c O cto Q Z O• as U N Q O illi u -c Q O • O J+ E ea I z I co- /Q 1 oC /75 i CO o3 N 0 C 0) ✓ _ N oQ a) a> • a a aa)) x cc O N c ~ O N V o OlC a) • a 6 O E a E E o o '' E ", E a U d 0 iO U MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg DATE:Tuesday,May 01,2012 P.I.Supervisorkoil, - SUBJECT: Mechanical Integrity Tests ENI US OPERATING CO INC 111 0I15-S4 FROM: Jeff Jones NIKAITCHUQ 0115-S4 Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry:age-- NON-CONFIDENTIAL Comm Well Name NIKAITCHUQ 0I15-S4 API Well Number 50-029-23460-00-00 Inspector Name: Jeff Jones Permit Number: 211-141-0 Inspection Date: 4/13/2012 Insp Num: mitJJ120414150411 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well] ell 0115-S4 'Type Inj W TVD 3675 • IA 1180 1680 1679 1679 PTD 2111410 1Type Test SPT Test psi 1500 • OA 200 200 200 200 - Interval iINITAL / P/F P / Tubing 111 111 111 113 - Notes: 2 week post injection MIT. Tuesday,May 01,2012 Page 1 of 1 Schiumborger Drilling&Measurements MWD/LWD Log Product Delivery Customer ENI US Operating Co.Inc.Alaska Dispatched To: Makana Bender Well No 0115-S4 Date Dispatched: 7-May-12 Installation/Rig Nabors 245 Dispatched By: Hector Echeto Data No Of Prints No of CDs 0115-S4 1 2inMD 1 2 in TVD 1 5 in MD 1 5 in TVD 1 Received By: Please sign and return one copy to: 3800 Centerpoint Drive,Suite 300 Anchorage,Alaska 99503, Andrew Buchanan andrew.buchanan(a�enipetroleum.com LWD Log Delivery V2.1,03-06-06 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMI,SION WELL COMPLETION OR RECOMPLETION REPORT AND LOG la.Well Status: Oil❑ Gas ❑ SPLUG ❑ Other ❑ Abandoned ❑ Suspended lb.Well Class: 20AAC 25.105 20AAC 25.110 Development ❑ Exploratory❑ GINJ ❑ WINJ Q ' WAG ❑ WDSPL❑ No.of Completions: Service E Stratigraphic Test❑ 2.Operator Name: 5.Date Comp.,Sues,.,or ,SIL) 12.Permit to Drill Number: ENI US Operating Co.Inc. Aband.: • 3/+l/2012 41611 211-141 3.Address: 6.Date Spudded: 13.API Number: 3800 Centerpoint Drive,Ste.300,Anchorage,AK 99503 1/18/2012 50-029-23460-00-00 • 4a.Location of Well(Governmental Section): 7.Date TD Reached: 14.Well Name and Number: Surface: 3163.8 FSL 1639.8 FEL S5 T13N R9E UM . 2/19/2012 0115-S4 Top of Productive Horizon: 8.KB(ft above MSL): 53.2 15.Field/Pool(s): 422 FSL 5096 FEL 29 T14N R9E UM GL(ft above MSL): 12.2 • Total Depth: 9.Plug Back Depth(MD+TVD): Nikaitchuq/Schrader Bluff Oil Pool • 7 FSL 1982 FEL 24 T14N R8E UM N/A 4b.Location of Well(State Base Plane Coordinates,NAD 27): 10.Total Depth(MD+TVD): 16.Property Designation: Surface: x- 516640.37 " y- 6036516.89 • Zone- 4 - 19240'MD/3615'TVD • ADL 355024,373301,390616,391283 TPI: x- 513143.48 y- 6044327.46 Zone- 4 11.SSSV Depth(MD+TVD): 17.Land Use Permit: Total Depth: x- 505851.59 y- 6049182.56 Zone- 4 N/A ADL 417493 18.Directional Survey: Yes U No U 19.Water Depth,if Offshore: 20.Thickness of Permafrost MD/TVD: (Submit electronic and printed information per 20 AAC 25.050) N/A (ft MSL) 1898.7'MD/1773'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/RES/NEU/Den/Sonic/USIT N/A 23. CASING,LINER AND CEMENTING RECORD WT.PER SETTING DEPTH MD SETTING DEPTH TVD , AMOUNT CASING FT. GRADE TOP BOTTOM TOP BOTTOM HOLE SIZE CEMENTING RECORD PULLED 20 178.89 X-65 37 160 37 160 Driven N/A N/A 13.375 68 L-80 35 2418 35 2160 16 10.7 ppg ASL: 488 bbls N/A 12.5 ooa LiteCRETE:73.5 bbls 9.625 40 L-80 33 10435 33 3714 12.25 12.5 ppg LiteCRETE:196 bbls N/A 4.5 11.6 L-80 10206 19228 3690 3616 8.75 Blank Liner with ICD's N/A 24.Open to production or injection? Yes❑ No iii If Yes,list each 25. TUBING RECORD interval open(MD+TVD of Top&Bottom;Perforation Size and Number): SIZE DEPTH SET(MD) PACKER SET(MD/TVD) CE/V ED 4.5 10229 10073'MD/3675'TVD RE26. ACID,FRACTURE,CEMENT SQUEEZE,ETC. 60 1 LETiOft k ApR 0 9 2012 DEPTH INTERVAL(MD) AMOUNT AND KIND OF MATERIAL USED F AOGCC 27. PRODUCTION TEST Date First Production: Method of Operation(Flowing,gas lift,etc.): N/A N/A Date of Test: Hours Tested: Production for Oil-Bbl: Gas-MCF: Water-Bbl: Choke Size: Gas-Oil Ratio: N/A N/A Test Period -N/A N/A N/A N/A N/A Flow Tubing Casing Press: Calculated Oil-Bbl: Gas-MCF: Water-Bbl: Oil Gravity-API(corr): Press. N/A N/A 24-Hour Rate -► N/A N/A N/A ,N/A 28. CORE DATA Conventional Core(s)Acquired? Yes ❑ No E • Sidewall Cores Acquired? Yes ❑ No Q. 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. RBDMS APR 0 9 2012 4,0- ` Form 10-407 Revised 12/2009 CONTINUED ON REVERSE A 72712ji/Dit or'ginal only 29. GEOLOGIC MARKERS (List all formations and markers encountered): 30. FORMATION TESTS NAME MD TVD Well tested? U Yes Lilo '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 1898 1773 tiI OA sand top 10730 V 3737 Formation at total depth: OA sand 19240 3618 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 Printed Name: Maurizio Grandi Title: Well Operations Project Manager Signature: A Phone: (907)865-3338 Date: 4/2/2012 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 lb: Classification of Service wells: Gas Injection,Water Injection,Water-Alternating-Gas Injection,Salt Water Disposal,Water Supply for Injection,Observation,or Other.Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 4b: TPI(Top of Producing Interval). Item 8: The Kelly Bushing and Ground Level elevations in feet above mean sea level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 13: The API number reported to AOGCC must be 14 digits(ex:50-029-20123-00-00). Item 20: Report true vertical thickness of permafrost in Box 20. Provide MD and TVD for the top and base of permafrost in Box 28. Item 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 (U) N C ) a OU '0 w U' o a L ci 0 E N Z OW r4111 e- N co N M UM L 42 � M co •= Q Y 0 C (0 }' _ CI o N i) V U • n en gQ UD M Lel 0 4) _ n CO U1 en IN 2 r^-1 ei Q N a3 j p cf) CZ L E a_ Co in — - (n st xz xt 7* It CD J O 0 a E a a a a a > N D Xv L (0 < N W o 3 3 3 3 3 }i > cJ 4- N H N VI N C C J Q •-�-, '' 0 00 ( lir N N fV fV tV ri ri rl ri .-1 C.) U 0Z a) 2 O U 4 4. 4 h 0) D +r (0 00 0 0 •- m a X a s m c a F 0• V Y•11 c- N c co p N MI c • C \ pic. U) c o y O O (6 O ai 0. 4z, � p N a O O oTitLA Q U_ N- gt GOr 3Q 2 O ' CZ Ci L Q L C O W " . H 0 co X CD o f ca X = N p / O .N ti Op 0 0 > iik 114k ON L �,`\ CO M N N G ^ . a, v crl ri V. '''N"\ii, 2 .--1 .--1 .--1 r-i• ri %-i %-i e-iN N w 01 O -- N M 74 M lDi a. ctiV ate+ 3t 3t 3t 3t 3t 3t 3t 7x o c / V d c - 00000000 u v v u u u u u d v- O • M a_ L O YQ U _ w�/ C� M ++ M 00 Q1 1p� M rl a-I (� Q - Ce C o0 0 M (" to' ▪ 8 n 5' IN O Q co v J M 2 Tr ci 1 N- T) rMH ON Q- O N - 000- L LC) M °)- % E � M 'N +' 3t 3t 3t Yt 3t 3t 3t 3t Y CO T- ❑ ❑ ❑ ❑ ❑ ❑ ❑ ❑ r z C1 N u u u0 u u u u . p7—I) z J1—int/ MECHANICAL INTEGRITY REPORT - , . PUD DA (Ail/Z— OPER & FIELD C A I — /U, Kc.r ickt,z :IG RELEASE : ' ✓/v/zj HELL NUMBER O/I s"- Sq C � rJ .,,ELL DATA TD : .1.-DD.. TVD ; =BTD : ?D TVD ,/� Casing : Shoe : MD TVD ; DV: MD •TVA • l " - _ne_ . Shoe : MD TVD ; TOP : 1.-DD TVD tD T:�bi_''V Packer • :-a) TVD ; Set at :ole Size and ; Per-Fs to • • ECB.ANICAL INTEGRITY - PART 11 • Annulus Press Test: 71:3250o ; 15 min ; 30 min ? . Comments : 1e�0,--{T> 5 0.S :/__.6) ' 1a p ;Q. ss u....� cJ +J24-4 /'-' MECHANICAL INTEGRITY - PART #2 L' 3 � Cement Volumes :. Amt. " ; Csg 1 br 66/ DV . Cmt vol to cover perfs AI/,4 `Al ' .5:41,2a r c.Q„e OA 3-4•1J D l..L_ • r.� /4-• Zsl S w (11 b-N_ t..-./ Slo/4"`i2 6€. t t Theoretical TOC -770° 140 4 -?(..) 7' X- Cement Bond Loge.srNo) • ; In AOGCC File CBL Evaluation, zone above perfs Production Log: Type M/f ; Evaluation 1 CONCLUSIONS : Part 11 : ivi(-1-__ 04- o ri :rSV 014- • Mail ii.); ;sd0 I417 -/jfc . art T 2 : V1 l- _ / cQ- ta.J i . re-e-4"'As C 4I" i � (C- rerife-6404i Eni E&P D!Vfs!On I Well Name:0115-S4 EN!Petroleum Co.Inc. Daily Report Well Code:26195 • Field Name:NIKAITCHUQ • 2^nrillkil Date:1/14/2012 - Report#: 1 API/UW1:50-029-23460-00-00 II II II page 1 of 1 Wellbore name: 0115-S4 Well Header Permit/Concession N' Operator ENI Share(%) Well Configuration type 402100 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(m) Ground Level(m) Water Depth(m) RKB-Base Flange(m) RKB-Tubing Spool(m) 16.22 3.72 11.37 Rig Information Contractor Rig Name Rig Type NABORS ALASKA NABORS 245 E 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) 0115-54 DRILLING 1/18/2012 5,848.81 1,092.64 5,864.35 185.75 31.6 -3.71 Daily Information End Depth(mKB) End Depth(TVD)(... Depth Progress(m) Drilling Hours(hr) Avg ROP(m/hr) FOB Temperature(°C) Weather Wind 0.00 79.0 -35.0 Mostly Clear WC-57` SW @ 13 MPH Daily summary operation 24h Summary Prep for rig move.Jack up modules and install crib blocks.Split modules and move utility west and drill east.P/U rig mats and herculite and back drag and level pad.Set new herculite and rig mats.Spot sub and utility modules on 0115-S4. Operation at 07.00 Finish Moving Rig 24h Forecast Move utility module and marry up with drill module.Connect all lines and inner connects.Install stairways,build berms and finalize pre-spud checklist.N/U Vetco starter head and test seals.Load shed with 5"DPs.Spot CCB Lithology Shows MAASP(kgf/cm2) Mud Weight(gIL) Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00:00 10:30 10.50 10.50 MOB A 1 P Prep for move blow down all lines.disconnect inner connects.Jack modules and install crib blocks. 10:30 11:30 1.00 11.50 MOB A 2 P Split modules move utility to west 40'.drill module to east 40'. 11:30 15:00 3.50 15.00 MOB A 1 P P/U ng mats&hurculite,back drag and level pad. 15:00 21:00 6.00 21.00 MOB A 1 P Place well house access cover on 0113-03.Pull cover on 0115-S4.Set new herculite and mats. 21:00 23:00 2.00 23.00 MOB A 2 P Spot sub module on 0115-S4.Shim with ply wood,pull crib blocks,set sub on mats and check level:Ok. 23:00 00:00 1.00 24.00 MOB A 2 P Move utility module to sub. Daily Contacts Position Contact Name Company Title E-mail Office Mobile Eni representative Frank Cormier Eni Petroleum Sr.Dug.Spur. 907-685-1493 337-277-1809 Eni representative Ben Perry Eni Petroleum Sr.Dug,Spur. 907-685-1493 Eni representative Angelo Lamarina Eni Petroleum Drlg Spur. angelo.lamanna@enipetroleum.com 907-685-1493 907-903-7269 Eni representative Sach Bowe Eni Petroleum Materal Coordinator 907-685-1491 907-299-0531 Eni representative Alvin Criswell Eni Petroleum Expediter 907-980-7545 Eni representative Mitch Billington Eni Petroleum Rig Clerk 907-670-8601 Eni representative Steve Millea ENI Petroleum HSE 907-685-1496 Tool Push Bruce Simonson Nabors Alaska Drilling Tool Pusher 907-670-1492 Tool Push Matt Vanhoose Nabors Alaska Drilling Tour Pusher 907-670-1492 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(mKB) Bottom(mKB) Run Date CONDUCTOR 20 18.250 X-65 0.00 48.77 1/15/2012 Last Leakoff Test Depth(mKB) TVD(mKB) Fluid Type Fluid Density(gIL) P Surf Applied(kgflcm2) Eq.Mud Weight(gIL) P LeakOff(kgf/cm2) 1111* * Eni E&P Division I Well Name:0115-54 ENI Petroleum Co.Inc. Daily Report Well Code:26195 Field Name:NIKAITCHUQ • API/t1Wl:50-029-23460-00-00 2 nil Date:1115/2012 - Report#: 2 II II n page 1 of 1 Wellbore name: 0115-S4 Well Header PermiVConcession N' Operator ENI Share(%) Well Configuration type 402100 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(m) Ground Level(m) Water Depth(m) RKB-Base Flange(m) RKB-Tubing Spool(m) 16.22 3.72 11.37 Rig Information Contractor Rig Name Rig Type NABORS ALASKA NABORS 245 E 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) 0115-S4 DRILLING 1/18/2012 5,848,81 1,092.64 5,864.35 185.75 31.6 -2.71 Daily Information End Depth(mKB) End Depth(TVD)(... Depth Progress(m) Drilling Hours(hr) Avg ROP(mlhr) •POB Temperature('C) Weather Wind 0.00 79.0 -29.4 Light Blowing Snow SW @ 23 MPH WC-51` Daily summary operation 24h Summary Ultimate rig move operations.Load pipe shead with 5"DP.Install and test starter head and nipple up drilling riser.Service rig.Downtime due to pipe skate.P/U,M/U and R/B 33 stands of 5"DP. Operation at 07.00 Pick up Drill Pipe 24h Forecast Pick up 330 joint of 5"DP and rack in derrick.Pre spud safety meeting.P/U BHA.Spud well 0115-S4. Lithology Shows MAASP(kgflcm') Mud Weight(gIL) Time Log Start End Cum Time _ Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 0000 01:00 1.00- 1.00 MOB A 2 P Mate up utility module.Shim and Jack down on rig mats 01.00 04.30 3.50- 4.50'MOB A 1 P R/U flow lines,degasser lines.N/U interconnects.Set cellar box down.Drop curtains around Lampson and cellar.Secure walkways throughout ng.Bring Steam/Water on-line throughout ng.Secure beaming around rig. 04.30 10.00 5.50' 10.00 DRILL C 5 P Vetco Gray installed starter head and pressure test to 500 psi x 10 min:Ok.N/U dolling user,flow&fill-up lines.Install Katch-Kan.Measurements:37.29'to load shoulder and 41.00'to ground level. 10:00 .12100 2.00 12.00 DRILL E 5 P Prepare Cellar for spud.P/U mouse hole and set in rotary bushings 12100 14.30 2.50- 14.50 DRILL E 20 P Grease crown,blocks,drawworks and top drive.Service pipe skate.Spot cuttings box and CCB.Calibrate H2S sensors, gas.comb and test.Install 5"elevators while loading 5"DPs in the shed. 14:30 18:30 4.00' 18.50 DRILL E 25 TR99 DOWNTIME:Repair cable tray and pinched cable on pipe skate. 18.30 00.00 5.50' 24.00 DRILL E 5 P P/U,M/U&R/B 33 stands of 5"DP.Drift on skate and strap on derrick.Continue spot CCB and cutting box with MI-Swaco. Daily Contacts • Position Contact Name Company Tithe _ E-mail Office - Mobile Eni representative -Frank Cormier -Eni Petroleum Sr.Ddg.Spur. '907-685-1493 ,337-277-1809 Eni representative Ben Perry Eni Petroleum Sr.Ddg.Spur. 907-685-1493 Eni representative Angelo Lamarina Eni Petroleum Ddg Spvr. angelo.lamarina@enipetroleum.com 907-685-1493 907-903-7269 Eni representative Sach Bowe Eni Petroleum Materal Coordinator 907-685-1491 907-299-0531 Eni representative Alvin Criswell Eni Petroleum Expediter 907-980-7545 Eni representative Mitch Billington Eni Petroleum Rig Clerk 907-670-8601 Eni representative Steve Millea ENI Petroleum HSE 907-685-1496 Tool Push Bruce Simonson Nabors Alaska Drilling Tool Pusher 907-670-1492 Tool Push Matt Vanhoose Nabors Alaska Drilling Tour Pusher 907-670-1492 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(mKB) Bottom(mKB) Run Date CONDUCTOR 20 18.250 X-65 0.00 48.77 1/15/2012 Last Leakoff Test Depth(mKB) TVD(mKB) Fluid Type Fluid Density(gIL) P Surf Applied(kgflcm') Eq.Mud Weight(gIL) P LeakOff(kgflcm') 1 11* Eni E&P Division I Well Name: 0115-S4 ENI Petroleum Co.Inc. Daily Report Well Code:26195 Field Name: NIKAITCHUO � API/UWI:50-029-23460-00-00 2^n Date:1/16/2012 - Report#: 3 II II II page 1 of 1 Wellbore name: 0115-S4 Well Header Permit/Concession N° Operator ENI Share(%) Well Configuration type 402100 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(m) Ground Level(m) Water Depth(in) RKB-Base Flange(m) RKB-Tubing Spool(m) 16.22 3.72 11.37 Rig Information Contractor Rig Name Rig Type NABORS ALASKA NABORS 245 E 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) 0115-S4 DRILLING 1/18/2012 5,848.81 1.092.64 5,864.35 185.75 31.6 -1.71 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 89.0 -26.7 Blowing Snow WC- W @ 26 MPH 46" Daily summary operation _ 24h Summary Pick up 5"DP,drift,strap and rack in derrick.Prepare to spud. Operation at 07.00 Operations at 04:00 Hours. Rig maintenance - 24h Forecast Finish R/U CCB.P/U BHA#1,Spud in well. Lithology Shows MAASP(kgflcm') Mud Weight(gIL) t. 1042.5 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 E 5 P Continue picking up 5"DP.drift and strap,rack in derrick. 02:00- 04:00 2.00 4.00 DRILL E '25 TR99 'Downtime:replaced TQ cylinder on iron roughneck per mechanic. 04:00 13:00 9.00 13.00 DRILL E 5 P Continue picking up 5"DP,drift and strap,rack in demck.Mix spud mud. 13:00 13:30 0.50 13.50 DRILL E '1 P Transfer 5"HWDP to long side pipe shed.Load Schlumberger BHA in short side. 13:30 21:00 7.50 21.00 DRILL "E '5 P Continue picking up 5"DP.drift and strap,rack in demck.Pull mouse hole.RIH and tag @ 72'.Continue mixing spud mud. 21:00- '00:00 ' 3.00 24.00 DRILL 'E -1 P Clean rig floor,flood surface lines,charge pumps and mud pumps,while waiting to complete CT job on disposal well OP26- DSP02. Daily Contacts Position Contact Name Company Title E-mail Office Mobile -Eni representative Frank Cormier Eni Petroleum Sr.Drtg.Spur. 907-685-1493 '337-277-1809 Eni representative Ben Perry Eni Petroleum Sr.Drip.Spur. 907-685-1493 • Eni representative Angelo Lamanna Eni Petroleum Drlg Spur. angelo.lamanna@enipetrcleum.com 907-685-1493 907-903-7269 Eni representative Sach Bowe Eni Petroleum Materal Coordinator 907-685-1491 907-299-0531 Eni representative Alvin Caswell Eni Petroleum Expediter 907-980-7545 Eni representative Mitch Billington Eni Petroleum Rig Clerk 907-670-8601 Eni representative Steve Millea ENI Petroleum HSE 907-685-1496 Tool Push Bruce Simonson Nabors Alaska Dulling Tool Pusher 907-670-1492 Tool Push Matt Vanhoose Nabors Alaska Drilling Tour Pusher 907-670-1492 Tool Push Math Turcotte Nabors Alaska Drilling Tour Pusher 907-670-1492 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(mKB) Bottom(mKB) Run Date CONDUCTOR 20 18.250 X-65 0.00 48.77 1/15/2012 Last Leakoff Test Depth(mKB) TVD(mKB) Fluid Type Fluid Density(gIL) P Surf Applied(kgflcm') Eq.Mud Weight(g/L) P LeakOff(kgflcm') 111* Eni E&P Division 'Well Name:0115-S4 ENI Petroleum Co.Inc. Daily Report Well Code:26195 Field Name:NIKAITCHUQ • Date:1/17/2012 - Report#: 4 APIIUWI:50-029-23460-00-00 zi ill page 1 of 1 Wellbore name: 0115-S4 Well Header Permit/Concession N° Operator ENI Share)%) Well Configuration type 402100 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(m) Ground Level(m) Water Depth(m) RKB-Base Flange(m) RKB-Tubing Spool(m) 16.22 3.72 11.37 Rig Information Contractor Rig Name Rig Type NABORS ALASKA NABORS 245 E 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) 0115-S4 DRILLING 1/18/2012 5,848.81 1,092.64 5,864.35 185.75 31.6 -0.71 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 89.0 -25.6 Blowing Snow WC- WSW @ 24 MPH 43' Daily summary operation 24h Summary Rig maintenance while coil tubing completes work on disposal well-R/U CCB and cuttings tank. Operation at 07.00 Spud well and drilling as per well plan 24h Forecast Spud well 0115-S4-Directional drill to 2411'as per well plan. Lithology Shows MAASP(kgflcm') Mud Weight(g/L) 1042.5 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 15 P Remove old Lampson curtains around rig and replace with new.Steam/Drain sumps in pipeshed.0/0 topdrive oil filter. Grease and service Canrig top drive and drawworks.CTU continues workover of disposal well. 06:00 12:00 6.00 12.00 DRILL 'E '15 P 0/0 man riders lines.0/0 drill floor hydraulic filter.Clean/scrub thoughout ng.Prepare motor room for 399 gen set removal with crane.Clean/rinse out cave tank.CTU continues workover of disposal well. 12:00 18:00 6.00 18.00 DRILL r E 5 P Assist spotting and rigging up CCB lines,install cuttings tank while coil tubing completes work on disposal well @ 1800. 18:00 21:00 3.00 21.00 DRILL 5 5 P Continue to assist spotting and rigging up CCB and berm.Load pipe shed with 50 joints 9 5/8"casing.Fill conductor and surface lines with spud mud and check for leaks:Ok.P/U BHA#1 for conductor clean out.WIF restart fluid injection into well OP26-DSPO2 @ 19:00 hrs. 21:00 00'.00 3.00 24.00 DRILL •E .25 TS99 While function testing CCB,noticed it was not working properly.Troubleshoot same.it was a faulty selenoid.New selenoid was installed and CCB Funtion test completed. Daily Contacts Position _ Contact Name Company Title E-mail Office Mobile • En:representative Frank Cormier Eni Petroleum Sr.Ddg.Spur. 907-685-1493 337-277-1809 Eni representative Sach Bowe Eni Petroleum Materal Coordinator 907-685-1491 907-299-0531 Eni representative Angelo Lamarina Eni Petroleum Ddg Spur. angelo.lamanna@enipetroleum.com 907-685-1493 907-903-7269 Eni representative Sach Bowe Eni Petroleum Materal Coordinator 907-685-1491 907-299-0531 Eni representative Alvin Caswell Eni Petroleum Expediter 907-980-7545 Eni representative Mitch Billington Eni Petroleum Rig Clerk 907-670-8601 Eni representative Steve Millea ENI Petroleum HSE 907-685-1496 Tool Push Bruce Simonson Nabors Alaska Drilling Tool Pusher 907-670-1492 Tool Push Man Vanhoose Nabors Alaska Drilling Tour Pusher 907-670-1492 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(mKB) Bottom(mKB) Run Date CONDUCTOR 20 18.250 X-65 0.00 48.77 1/15/2012 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') 01111441 Eni E&P Division I Well Name:0115-54 EN!Petroleum Co.Inc. Daily Report Well Code:26195 Field Name: NIKAITCHUO • API/UWI:50-029-23460-00-00 2�,,t Date:1/18/2012 - Report#: 5 II II II page 1 of 1 Wellbore name: 0115-S4 Well Header Permit/Concession N' Operator ENI Share)%) Well Configuration type 402100 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(m) Ground Level(m) Water Depth(m) RKB-Base Flange(m) RKB-Tubing Spool(m) 16.22 3.72 11.37 Rig Information Contractor Rig Name Rig Type NABORS ALASKA NABORS 245 E 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) 0115-S4 DRILLING 1/18/2012 5,848.81 1.09264 5864.35 185.75 316 0.29 Daily Information End Depth(mKB) End Depth(TVD)(... Depth Progress(m) Drilling Hours(hr) Avg ROP(m/hr) POB Temperature(`C) Weather Wind 114.30 114.29 114.30 3.32 34.4 89.0 -27.2 Mostly Cloudy WC- W @ 9 MPH 36' Daily summary operation 24h Summary Finish testing CCB-Wash and ream 20"C.P.down to 160'-P/U BHA#2-Had problems with Gyro tool.MWD and ARC tools.Replaced with back-up-Finally M/U BHA and Spud well @ 17.00- Rotary/Slide Drilling 16"section to 375'. _ Operation at 07.00 Gyro tools gave 2 different good surveys at 480'.POOH one stand and repeat survey at different depth to evaluate funcionality of gyro collar. 24h Forecast Drill 16"section as per well plan. Lithology Shows MAASP(kgf/cm') Mud Weight(gIL) 1066.5 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 5 TS99 While function testing CCB,noticed it was not working property.Troubleshoot same:it was a faulty selenoid.New selenoid was installed and CCB Funtion test completed good @ 1:00 a.m. 01:30 03:00 1.50 3.00 DRILL E 6 P Wash and ream 20"C.P.from surface to 160'@ 500 gpm/450 psi/60 rpm/1.3K TO.POOH BHA#1 racking back 2 stands 5"DP. 03:00 '04:00 1.00 4.00 DRILL E 5 P Held PJSM.P/U BHA#2 with new 0 16"MT bit Hughes s/n 5202657,3x 20!32"+10 16/32"nozzles(TFA=1.12). 04:00 05:00 1.00 5.00 DRILL E 25 TR04 Found damaged hose on Canrrg top drive.Replaced with new one. 05:00 09:00 4.00 9.00 DRILL E 5 TD01 Continue picking up BHA#2.P/U gyro tools,had issue with plug and sleeve not lining up.L/D collar with gyro tool and reload new gyro tool in pipesheed. Note:Al 08:15 Gyro hand fell trying to get on casing to work on gyro tool. 09:00 10:00 1.00 10.00 DRILL E 21 TD01 Safety stand down with crew'discussed incident,rescue and hazard recognition.Rig crew assisted and evacuated injured man from ng floor level to ground and leaded into ambulance. 10:00 13:30 3.50 13.50 DRILL E 5 P Continue P/U and M/U BHA#2.Perform shallow test 600 gpm/780 psi and 500 gpm/590 psi:No good,ARC tool and MWD not functioning properly real time connection between MWD-ARC faded. 13:30 15:00 1.50 15.00 DRILL E 5 TD01 B/D Top Drive,stand back 5"HWDPs,UD NMDC,stab.ARC and MWD. 15:00 17:00 2.00 17.00 DRILL E 5 TD01 Change out ARC tool and P/U BHA#3:bit 0 16"(s/n 5202657)+PDM 1.83 bend(s/n962-7200)+NM stabilizer+2x NMXO i. +Gyro Pulse collar(s/n E1906)+8"PowerPulse MWD(E3097)+ARC 825(E5292)+NM Stabilizer+NMDC+XO. Perform shallow test 500 gpm/550 psi:Ok. 17:00 20:30 3.50 20.50 DRILL E 3 P Spyd well 0115-S4/0 1700 hrs Drill rotary,yith mod rrntnr ritarr-71338_-Pump 500 gpm @ 700 psi-WOB=15-20 K-Up wt 65K-Dn wt 60K-Mud wt=8.8 ppg.Record Survey Gyro Data as needed.Monitor for leaks&conductor breaching:Ok. 20:30 22:30 2.00 22.50 DRILL E 5 P P/U and R/B 02 St HWDP-P/U and M/U 02 NM Flex DCs+Saver sub+Jar(Smith s/n 42203D)+XO. 22:30 00:00 1.50 24.00 DRILL E -3 P Drilling Rotary/Sliding 0 16"section f/338'11375'\500 gpm @ 687 psi\40 rpm 5 1.5.2k Ribs\WOB=10-15k lb I Up wt= 78k lb-Dw wt=70k lb-Rot wt=70k lb\Mud wt.8,9 ppg-Take survey as needed. Daily ADT=2.32 hrs TART=1.7-AST=0.62 hrs).Jars=53.3hrs. Daily Contacts Position Contact Name Company Title E-mail Office Mobile Em representative Frank Cormier Eni Petroleum Sr.Drip.Spur. 907-685-1493 337-277-1809 Eni representative Ben Perry Eni Petroleum Sr.DrIg.Spur, 907-685-1493 Eni representative Angelo Lamarina Eni Petroleum Drip Spvr. angelo.lamarina@enipetroleum.com 907-685-1493 907-903-7269 Eni representative Sach Bowe Eni Petroleum Materal Coordinator 907-685-1491 907-299-0531 Eni representative Greg Parker Eni Petroleum Expediter 907-980-7545 Eni representative Mitch Billington Eni Petroleum Rig Clerk 907-670-8601 Eni representative Steve Milea ENI Petroleum HSE 907-685-1496 Tool Push Bruce Simonson Nabors Alaska Drilling Tool Pusher 907-670-1492 Tool Push Mattt Turcotte Nabors Alaska Drilling Tour Pusher 907-670-1492 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(mKB) Bottom(mKB) Run Date CONDUCTOR 20 18.250 X-65 0.00 48.77 1/15/2012 Last Leakoff Test Depth(mKB) TVD(mKB) Fluid Type Fluid Density(g/L) P Surf Applied(kgflcm') Eq.Mud Weight(gIL) P LeakOff(kgflcm') fl* Eni E&P Division I Well Name:0115-S4 ENI Petroleum Co.Inc. Daily Report Well Code:26195 Field Name:NIKAITCHUQ • API/UWI:50-029-23460-00-00 2 o n Date:1/19/2012 - Report#: 6 II II I' page 1 of 1 Wellbore name: 0115-S4 Well Header Permit/Concession N° Operator ENI Share(%) Well Configuration type 402100 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(m) Ground Level(m) Water Depth(m) RKB-Base Flange(m) RKB-Tubing Spool(m) 16.22 3.72 11.37 Rig Information Contractor Rig Name Rig Type NABORS ALASKA NABORS 245 E 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) 0115-54 DRILLING 1/18/2012 5,848.81 1,092.64 5,864.35 185.75 316 1.29 Daily Information End Depth(mKB) End Depth(TVD)(... Depth Progress(m) •Drilling Hours(hr) Avg ROP(m/hr) POB Temperature(°C) Weather Wind 370.33 361.48 256.03 11.33 22.6 86.0 -17.2 Light Snow WC-21" W @ 21 MPH Daily summary operation 24h Summary Drill 16"section t/375'5/1.215'. Operation at 07.00 Drill 16"section as per well plan. 24h Forecast Drill 16"section to planned TD @ 2,411'-Circulate B/U. 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 0330 3.50 3.50 DRILL E 3 -P -Drilling Rotary/Sliding 0 16"section-/375'1/497'1600 gpm @ 700 psi 140 rpm @ 1.5.2k ft-lbs I WOB=10-25k lb\Up wt= 77k lb-Dw wt=75k lb-Rot wt=75k lb\Mud wt=9.0 ppg-Take Gyro survey every 30'. 03.30 05:30 2.00 5.50 DRILL E 11 TD01 At 480'Gyro gave 2 different good surveys(-12 degrees difference in azimuth).POOH 8/497't1375'taking survey every 30' to confirm same:Ok.RIH back to bottom and check last survey:2.5 degrees difference.Gyro operator consulting with town:Ok,tool is good. 05.30 12 00 6.50 12.00 DRILL E 3 P Drilling Rotary/Sliding 0 16"section-/497'V734'1600 gpm @ 650 psi 140 rpm @ 2k ft-lbs\WOB=10-25k lb I Up wt=80k lb-Dw wt=78k lb-Rot wt=78k lb I Mud wt=9.0 ppg-Take Gyro survey every 30'. 12.00 00:00 12.00' 24.00 DRILL E 3 'P Drilling Rotary/Sliding 0 16"section f/734'V1,215'1550 gpm @ 780 psi\40 rpm @ 4k ft-lbs\W06=15-25k lb\Up wt=97k lb-Dw wt=91k lb-Rot wt=92k lb I Mud wt=9.0 ppg-Take Gyro survey as needed.SPR @ 1055'•Pump#1 3 bpm/64 psi -4 bpm/85 psi&Pump#2 3 bpm/68 psi-4 bpm/86 psi. Daily ADT=11.33 hrs(ART=2.82-AST=8.51 hrs).Jars=64.7 hrs. Daily Contacts Position Contact Name Company Title E-mail _ Office Mobile Eni representative Frank Cormier Eni Petroleum Sr.Dig.Spvr. 907.685-1493 337-277-1809 Eni representative Ben Perry Eni Petroleum Sr.Ddg.Spvr. 907-685-1493 Eni representative Angelo Lamanna Eni Petroleum Drlg Spvr. angelo.lamanna@enipetroleum.com 907-685-1493 907-903-7269 Eni representative Sach Bowe Eni Petroleum Meters!Coordinator 907-685-1491 907-299-0531 Eni representative Greg Parker Eni Petroleum Expediter 907-980-7545 Eni representative Mitch Billington Eni Petroleum Rig Clerk 907-670-8601 Eni representative Steve Millea ENI Petroleum HSE 907-685-1496 Tool Push Bruce Simonson Nabors Alaska Dulling Tool Pusher 907-670-1492 Tool Push Mattt Turcotte Nabors Alaska Dnlling Tour Pusher 907-670-1492 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(mKB) Bottom(mKB) Run Date CONDUCTOR 20 18.250 X-65 0.00 48.77 1/15/2012 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') Eni E&P Division I Well Name:0115-S4 ENI Petroleum Co.Inc. Daily Report Well Code:26195 Field Name:NIKAITCHUO $1* • APIIUWI:50-029-23460-00-00 2�IIII, Date:1/20/2012 - Report#: 7 page 1 of 1 Wellbore name: 0115-S4 Well Header Permit/Concession N° Operator ENI Share(10) Well Configuration type 402100 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(m) Ground Level(m) Water Depth(m) RKB-Base Flange(m) RKB-Tubing Spool(m) 16.22 3.72 11.37 Rig Information Contractor Rig Name Rig Type NABORS ALASKA NABORS 245 E 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) 0115-04 DRILLING 1/18/2012 5,848.81 1,092.64 5,864.35 185.75 31.6 2.29 Daily Information End Depth(mKB) End Depth(TVD)(... Depth Progress(m) Drilling Hours(hr) Avg ROP(m/hr) POB Temperature(°C) Weather Wind 740.66 661.13 370.33 13.66 27.1 88.0 -18.9 Light Snow WC-19' WSW @ 10 MPH Daily summary operation 24h Summary Drill 16"section(/1,215'to TD @ 2,430'(2,173'TVD).-Circulate 2x B/U-BROOH to 2,019'. Operation at 07.00 BROOH. 24h Forecast BROOH-@ HWDP circulate till shakers clean-POOH and L/D BHA#3-Dummy run with csg hanger-Prepare and RIH 13 3/8"casing-Cement Job. Lithology Shows MAASP(kgf/cm') Mud Weight(gIL) 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 i E 3 P Drilling Rotary/Sliding 0 16"section 61,215'51,585'1554 gpm @ 860 psi\40 rpm @ 1.8+3.5k ft'Ibs\WOB=10-30k lb\Up w1=98k lb-Dw wt=88k lb-Rot wt=95k lb\Mud wt=9.1 ppg-Take MWD survey as needed. '06,00 12:00 6.00 12.00 DRILL E 3 P Drilling Rotary/Sliding 0 16"section f/1,585'V1,898'1554 gpm @ 900 psi\40 rpm @ 4+5k ft-lbs\WOB=10-35k lb\Up wt= 105k lb-Dw wt=90k lb-Rot wt=100k lb\Mud wt=9.2 ppg-Take MWD survey as needed. 12:00 21:00 i 9.00 21.00'DRILL 'E 3 P Drilling Rotary/Sliding 0 16"section(/1898'to TD @ 2,430'(2.173'TVD)\550 gpm @ 1000 psi\40 rpm @ 4-5k ft'lbs I WOB=15-20k lb\Up wt=100k Ib-Dwwt=95k lb-Rot wt=100k lb\Mud wt=9.2 ppg-Take MWD survey as needed. Daily ADT=13.66 hrs[ART=5.15-AST=8.51 hrs].Jars=78.36 hrs. 21:00 23:00 ' 2.00 23.00 DRILL "E 7 P Circulate 2x B/U while backreaming one stand very slowly f/2,430'62,211'@ 550 gpm/950 psi/80 rpm/4k ftib.Rack back one stand each bottom up. 2300 00:00 i 1.00 24.00 DRILL E 6 P BROOH(/2.211'V2,019'@ 650 gpm/1000 psi/80 rpm/4k ftib. Daily Contacts Position Contact Name Company Title E-mail Office Mobile Eni representative Frank Cormier Eni Petroleum Sr.Dig.Spvr. 907-685-1493 1337-277-1809 Eni representative Ben Perry Eni Petroleum Sr.Dig.Spvr. 907-685-1493 Eni representative Angelo Lamarina Eni Petroleum DrIg Spvr. angelo.lamarina@enipetroleum.com 907-685-1493 907-903-7269 Eni representative Sach Bowe Eni Petroleum Materal Coordinator 907-685-1491 907-299-0531 Eni representative Greg Parker Eni Petroleum Expediter 907-980-7545 Eni representative Mitch Billington Eni Petroleum Rig Clerk 907-670-8601 Eni representative Steve Millea ENI Petroleum HSE 907-685-1496 Tool Push Bruce Simonson Nabors Alaska Drilling Tool Pusher 907-670-1492 Tool Push Mattt Turcotte Nabors Alaska Drilling Tour Pusher 907-670-1492 Last Casing seat Can.Type OD(in) ID(in) Grade Top(mKB) Bottom(mKB) Run Date CONDUCTOR 20 18.250 X-65 0.00 48.77 1/15/2012 Last Leakoff Test Depth(mKB) TVD(mKB) Fluid Type Fluid Density(gIL) P Surf Applied(kgf/cm') Eq.Mud Weight(gIL) P LeakOff(kgflcm') Eni E&P Division I Well Name:0115-S4 EN!Petroleum Co.Inc. Daily Report Well Code:26195 Field Name:NIKAITCHUO $11)* • API/UWI:50-029-23460-00-00 2^ Date:1/21/2012 - Report#: 8 I� II page 1 of 1 wellbore name: 0115-S4 • Well Header Permit/Concession N° Operator ENI Share(%( Well Configuration type 402100 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(m) Ground Level(m) Water Depth(m) RKB-Base Flange(m) RKB-Tubing Spool(m) 16.22 3.72 11.37 Rig Information Contractor Rig Name Rig Type NABORS ALASKA NABORS 245 E 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) 0115-S4 DRILLING 1/18/2012 5,848.81 1,092.64 5,864.35 185.75 31.6 3.29 Daily Information End Depth(mKB) End Depth(TVD)(... Depth Progress(m) Drilling Hours(hr) Avg ROP(m/hr) POB Temperature(°C) Weather Wind 740.66 661.13 0.00 88.0 -35.0 Partly Cloudy WC- SW @ 12 MPH 56" Daily summary operation 24h Summary BROOH-©HWDP circulate till shakers clean-POOH and L/D BHA#3-Dummy run with csg hanger-Prepare and RIH 13 3/8"casing to 2,418'-Circulate for cement Job. Operation at 07.00 Cement job in progress. 24h Forecast Cement Job-LID Riser and install Vetco Wellhead and BOPs-Test BOPS as per AOGCC requirements. Lithology Shows MAASP(kgflcm') Mud Weight(g/L) 1108.4 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00:00 07.30 7.50 7.50 DRILL E 6 P BROOH 5-10 minutes per stand(/2.019'1/679'@ 645 gpm/80 rpm/3.5-5.5k ftlb.Consistant torque,No tightspots. BROOH slowly @ 1,630'till shakers clean up. 07:30 08:00 0.50' 8.00 DRILL E 7 P Circulate 2x B/U @ 679'while backreaming slowly 1 stand 5"HWDP.Circulation till shakers clean. 08:00 12:00 4.00 12.00 DRILL E 5 P Held PJSM.POOH and L/D BHA#3.[Bit Dull 1-1-WT-A-X-0-ER-TD). 12:00 13:00 1.00' 13.00 DRILL G 1 P Make dummy run with 13 3/8"csg hanger and landing joint. 13:00 15:30 2.50 15.50 DRILL G 5 P R/U GBR casing tools and power tongue.R/U Franks casing fill up tool. 15:30 -21'00 5.50 21.00 DRILL G 4 P P/U,M/U Shoe track wf Baker Lock-Check float equipment:Ok-P/U,M/U&RIH Casing 13 3/8"68#L80 BTC(10k B lbs M/U torque)5/1,907. 21:00 22:00 1.00 22.00 DRILL G 7 P Circulate 1x B/U @ 1,907.Break circulation slowly at 42 gpm up to 140 gmp/120 psi. 22:00 23:30 1.50 23.50 DRILL G 4 P Continue to Run 13 3/8'Casing(/1.907'112,418'-M/U Hanger and Landing Jt-Remove casing slip and land hanger. [Shoe @ 2,418'-Float Collar @ 2,334'-Up wt 190k lbs,Dwwt 140k Ibsj. 23:30 00:00 0.50 24.00 DRILL H 7 P Break circulation to condition mud for cement job(1.5 bpm @ 180 psi).Reciprocate pipe 5'-7'. Daily Contacts Position Contact Name Company Title E-mail Office Mobile Eni representative Frank Cormier -Eni Petroleum Sr.Dig.Spvr. '907-685-1493 337-277-1809 Eni representative Ben Perry Eni Petroleum Sr.Drig.Spvr. 907-685-1493 Eni representative Angelo Lamarina Eni Petroleum Dug Spvr. angelo.lamarina@enipetroleum.com 907-685-1493 907-903-7269 Eni representative Sach Bowe Eni Petroleum Materal Coordinator 907-685-1491 907-299-0531 Eni representative Greg Parker Eni Petroleum Expediter 907-980-7545 Eni representative Mitch Billington Eni Petroleum Rig Clerk 907-670-8601 Eni representative Steve Millea ENI Petroleum HSE 907-685-1496 Tool Push Bruce Simonson Nabors Alaska Drilling Tool Pusher 907-670-1492 Tool Push Mattt Turcotte Nabors Alaska Drilling Tour Pusher 907-670-1492 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(mKB) Bottom(mKB) Run Date CASING 133/8 12.415 L80 0.01 737.01 1/21/2012 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:0115-S4 ENI Petroleum Co.Inc. Daily Report Well Code:26195 Field Name:NIKAITCHUO Iffil* � API/UWI:50-029-23460-00-00 2^,t Date:1/22/2012 - Report#: 9 II II II page 1 of 1 Wellbore name: 0115-S4 Well Header PermitlConcession N° Operator ENI Share)%) Well Configuration type 402100 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(m) Ground Level(m) Water Depth(m) RKB-Base Flange(m) RKB-Tubing Spool(m) 16.22 3.72 11.37 Rig Information Contractor Rig Name Rig Type NABORS ALASKA NABORS 245 E 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) 0115-S4 DRILLING 1/18/2012 5,848.81 1,092.64 5,864.35 185.75 31.6 4.29 Daily Information End Depth(mKB) End Depth(TVD)(... Depth Progress(m) Drilling Hours(hr) Avg ROP(m/hr) POB Temperature("C) Weather Wind 740.66 661.13 0.00 86.0 -45.0 Mostly Clear WC-72` WSW @ 7 MPH Daily summary operation 24h Summary Circulate and condition mud for cement job-Perform Cement Job-N/D Riser-N/U Wellhead and BOPS. Operation at 07.00 Test BOP 24h Forecast Test BOPs as per AOGCC requirements-Install Wear Bushing-P/U,M/U and rih B1-1A#4-Perform Casing pressure integrity test-Displace to FazePro-Drill out float equipments.cement and 20'new hole-Perform FIT/LOT-Drill 12 1/4"section as per well plan. Lithology Shows MAASP(kgflcm') Mud Weight(g/L) 1108.4 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 0000 02.30 2.50 2.50 DRILL H 7 P Continue to circulate to condition mud for cement job(3->7 bpm©120->315 psi)YP=16-No losses. 02.30 03:30 1.00 3.50 DRILL H 5 P L/D Franks fill up tool-R/U cement head and load with two plugs(witness by ENI and SLB rep)-Held PJSM. 03.30 05.30 2.00 5.50 DRILL H 1 TS03 Attempt to mix in batch mixer 100 bbls Mud Push II 10.1 ppg:negative.The Schlumberger batch mixer did not function properly.Prepare to mix and pump Mud Push II on fly while continue to circulate @ 7 bpm/240 psi. 0530 09.30 4.00 9.50 DRILL H 9 P Cement 13 3/8"surface casing as per program.SLB pump 5 bbl Mud Push II and test lines to 2500 psi-SLB pump 95 bbl C IhT Mud Push II @ 10.1 ppg(5 bpm @ 150 psi)-Drop Bottom Plug-SLB mix and pump 488 bbls Lead Slurry @ 10.7 ppg F [Class Attic Sea Lite 1081 sacks,2.49 Yield.mix fluid 11.928 gal/skj-Followed by 73.5 bbl Tail Slurry @ 12.5 ppg 5A-r [DeepCRETE 254 sacks,1.57 Yield.mix fluid 5.495 gaVsk]-Drop Top Plug-SLB pump 10 bbls water-Switch to Rig C Sri Pump and Displace with 339 bbls of mud(6 bpm @ 250->450 psi)-[Bump plug @ 09:30]-Pressure casing up to 1000 psi v (500 psi over FCP)-Release pressure and check float equipment:Ok-No losses during job-Recovered ?166 bbls lead slurry on surface. -i 09:30 12:00 2.50 12.00 DRILL H 5 P R/D and LID cement head-Back out and UD Landing Jt-R/D Casing handling and cementing equipment. 12:00 17:30 5.50 17.50 DRILL C 5 P R/D Katch Kan,mouse hole,flow lines-N/D Riser and starting head. 17:30 22:00 4.50 22.00 DRILL C 5 P N/U Wellhead and valves-Pressure test Wellhead/Csg Hanger 5k psi x 10 minutes:Ok. 22:00 00:00 2.00 24.00 DRILL C 5 P N/U 13 5/8"Riser and BOP Stack-Install Bell nipple&Flow line. Daily Contacts Position Contact Name Company Title E-mail Office Mobile Eni representative Frank Cormier Eni Petroleum Sr.Ddg.Spvr. 907-685-1493 337-277-1809 Eni representative Ben Perry Eni Petroleum Sr.Ddg.Spvr. 907-685-1493 Eni representative Angelo Lamarina Eni Petroleum Drlg Spvr. angelo.lamanna@enipetroleum.com 907-685-1493 907-903-7269 Eni representative Sach Bowe Eni Petroleum Materal Coordinator 907-685-1491 907-299-0531 Eni representative Greg Parker Eni Petroleum Expediter 907-980-7545 Eni representative Mitch Billington Eni Petroleum Rig Clerk 907-670-8601 Eni representative Steve Millea ENI Petroleum HSE 907-685-1496 Tool Push Bruce Simonson Nabors Alaska Drilling Tool Pusher 907-670-1492 Tool Push Mattt Turcotte Nabors Alaska Drilling Tour Pusher 907-670-1492 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(mKB) Bottom(mKB) Run Date CASING 133/8 12.415 L80 0.01 737.01 1/21/2012 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°) fitt* Eni E&P Division .. [Well Name:0115-S4 EN!Petroleum Co.Inc. Daily Report Well Code:26195 Field Name:NIKAITCHUO • APIIUWI:50-029-23460-00-00 2�,r, Date:1/23/2012 - Report#: 10 i i ii page 1 of 1 Wellbore name: 0115-S4 Well Header Permit/Concession N° Operator ENI Share)%) Well Configuration type 402100 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(m) Ground Level(m) Water Depth(m) RKB-Base Flange(m) RKB-Tubing Spool(m) 16.22 3.72 11.37 Rig Information Contractor Rig Name Rig Type NABORS ALASKA NABORS 245 E 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) 0115-S4 DRILLING 1/18/2012 5,848.81 1.092.64 5,864.35 185.75 31.6 5.29 Daily Information End Depth(mKB) End Depth(TVD)(... Depth Progress(m) Drilling Hours(hr) Avg ROP(m/hr) POB Temperature(°C) Weather Wind 740.66 661.13 0.00 84.0 -42.8 Mostly Clear WC-71' W @ 9 MPH Daily summary operation 24h Summary N/U and Test BOPS as per AOGCC requirements-Install Wear Bushing-UD 5"HWDP-Wait on weather-P/U,M/U and RIH BHA#4-Had problem with MWD tools. Operation at 07.00 L/D BHA#4 to C/O MWD tools. 24h Forecast POOH BHA#4 and CIO MWD tool-RIH BHA and Perform Casing pressure integrity test-Finish to clean pits and trasfer mud from Ugnu tanks to rig pits-Displace to FazePro-Drill out float equipments, cement and 20'new hole-Perform FIT/LOT-Drill 12 1/4"section as per well plan. Lithology Shows MAASP(kgflcm') Mud Weight(gIL) 1114.4 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Disci'. 00.00 02:00 2.00 2.00 DRILL C 5 P N/U Ketch Kan.P/U and install mouse hole.Clean/clear cellar. 02:00 02:30 0.50 2.50 DRILL C 5 P P/U one stand 5"and L/D 2 singles for test joint. 02.30 04:30 2.00 4.50 DRILL C 5 P P/U test plug,M/U 5"testing joint and install as per Vetco indications.Fluid pack BOPS&choke lines with water. 04:30 09:30 5.00 9.50 DRILL C 12 P 1 f/Test Bop as per AOGCC requirements.Test rams&all valves 250 psi Iowl3,500 psi high and annular 250 psi low/2,500 psi (�\ high.All test held per 5 min and charted.AOGCC reps.John Crisp waived to witness the test©10:30 hrs 01/22/2012. 09:30 11:00 1.50 11.00 DRILL C 5 P Pull test plug and L/D test tool.Install Wear Bushing.Drain BOP stack.B/D choke/kill lines&test pump. 11:00 13:00 2.00 13.00 DRILL E 5 P P/U,M/U&R/B one stand 5"DP.RIH with 4 stands 5"HWDP and UD joints in pipeshed. 1300 17:00 4.00 17.00 DRILL E 22 TWO1 Shut down operations due to trucks freezing up with the-50 F temperature and not being able to finish cleaning mud pits and transfer mud from Ugnu storage tanks to rig tanks.Prepare BHA tools for intermediate section.Rig service while wading on weather 17:00 21:30 4.50 21.50 DRILL E 5 P P/U BHA#4.M/U bit 0 12 1/4"+Xceed 900 and had problem to RIH same:riser between wellhead and BOPS froze up.R/U steam lines to well head:Ok,well free.Continue to P/U BHA#4 as per Schlumberger DD/MWD indications. 21:30 23:30 2.00 23.50 DRILL E 4 P RIH BHA#4 with 5"DP to 1,243'.Installed Ghost Reamer after 8 stands 5"DP. 23:30 00:00 0.50 24.00 DRILL E 12 TD01 At 1,240'performed shallow test Schlumberger equipments @ 650 gpm/675 psi:having trouble to get signal from MWD tools.Repeated test @ 710 gpm/750 psi:still no signal. Note:@ 24:00 hrs still not possible transfer mud from Ugnu tank to ng pits due to bad weather conditions(-45 F).WIF is shutted down.Not possible to operate forklifts and work with Vac/Water trucks. Daily Contacts Position Contact Name _ Company Title E-mail Office Mobile Eni representative Frank Cormier Eni Petroleum Sr.Ddg.Spvr. 907-685-1493 337-277-1809 Eni representative Ben Perry Eni Petroleum Sr.Ddg.Spvr 907-685-1493 Eni representative Angelo Lamarina Eni Petroleum Ddg Spvr. angelo.Iamanna@enipetroleum.com 907-685-1493 907-903-7269 Eni representative Sach Bowe Eni Petroleum Materal Coordinator 907-685-1491 907-299-0531 Eni representative Greg Parker Eni Petroleum Expediter 907-980-7545 Eni representative Mitch Billington Eni Petroleum Rig Clerk 907-670-8601 Eni representative Steve Millea ENI Petroleum HSE 907-685-1496 Tool Push Bruce Simonson Nabors Alaska Drilling Tool Pusher 907-670-1492 Tool Push Mattt Turcotte Nabors Alaska Drilling Tour Pusher 907-670-1492 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(mKB) Bottom(mKB) Run Date CASING 133/8 12.415 L80 0.01 737.01 1/21/2012 Last Leakoff Test Depth(mKB) ND(mKB) Fluid Type Fluid Density(gIL) P Surf Applied(kgf/cm') Eq.Mud Weight(gIL) P LeakOff(kgflcm') • 1111)* Eni E&P Division (Well Name:0115-S4 EN/Petroleum Co.Inc. Daily Report Well Code: 26195 Field Name: NIKAITCHUQ a API/UWI:50-029-23460-00-00 2^n Date:1/24/2012 - Report#: 11 " II II page 1 of 1 Wellbore name: 0115-S4 Well Header PermitiConcession N° Operator ENI Share(%) Well Configuration type 402100 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(m) Ground Level(m) Water Depth(m) RKB-Base Flange(m) RKB-Tubing Spool(m) 16.22 3.72 11.37 Rig Information Contractor Rig Name Rig Type NABORS ALASKA NABORS 245E 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) 0115-S4 DRILLING 1/18/2012 5.848.61 1.092.64 5,864.35 185.75 31.6 6.25 Daily Information End Depth(mKB) End Depth(TVD)(... Depth Progress(m) Drilling Hours(hr) Avg ROP(m/hr) POB Temperature(°C) Weather Wind 740.66 661.13 0.00 84.0 -46.1 Cloudy,Fog.WC- 225"SW @ 12 MPH 82' Daily summary operation 24h Summary Attempt to get signal from MWD tools-POOH and L/D BHA#4-P/U,M/U and RIH BHA#5 with new Schlumberger tools-Test tools good-RIH and tag cement @ 2,330'-Perform pressure Integrity test of 13 3/8"csg to 2500 psi-Continue cleaning pits and prepare for mud displacement-WOW. Operation at 07.00 W.O.W. 24h Forecast Finish to clean pits and trasfer mud from Ugnu tanks to rig pits-Displace to FazePro-Drill out float equipments,cement and 20'new hole-Perform FIT/LOT-Drill 12 1/4"section as per well plan. Lithology Shows MAASP(kgflem') Mud Weight(gIL) ' 1120.4 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 12 TD01 Attempt to get MWD tools working trying different gpm's:No success,tools didn't get signal. 01:30 '05:00 3.50 5.00 DRILL E 5 TD01 POOH BHA#4 and L/D. 05:00 08:30 3.50 8.50 DRILL E 5 TD01 P/U B1-1A#5:Hughes VM-3 bit 0 12 1/4"+Xceed 900(s/n 115)+ARC 825(s/n E5619)+NM Stab+8"PowerPulse MWD (s/n E8023)+NM Stabilizer+NMDC+2x NM Flex DC+Float sub+•"Hydraulic Jar(s/n 42203D)+XO+2x 5"HWDP. Total length=279.70'. 08:30 09:00 0.50 9.00 DRILL E 12 TD01 Performed shallow test MWD tools @ 373'to 700 gpm/680 psi:Ok,good tests. 09:00 10:30 1.50 10.50 DRILL E 4 P RIH BHA#5 with 5"DP and tag cement @ 2,330'. 10:30 13:00 2.50 13.00 DRILL E 7 P 'R/U head pin,circulating hose and chart recorder.Circulate and condition mud for casing integrity test @ 500-740 gpm/ 1050-2000 psi. --.1.1 13:00 14:00 1.00 14.00 DRILL E 12 P Pressure test 13 3/8"Csg @ 2500 psi for 30 min(chart record):Ok. 14:00 20:00 6.00 20.00 DRILL E 1 P Continue cleaning pits for mud displacement.Transfer mud from Ugnu tanks to rig pits.Operations slowed down due to bad weather condition. 20:00 00:00 4.00 24.00 DRILL E 22 TWO1 Shut down operations due to Vac truck froze up and not being able to finish cleaning active mud pits and transfer mud to the trucks.Super Sucker froze up off loading at WIF.Slowly continue to transfer mud from Ugnu storage tanks to rig Raw mud tanks.Circulate @ 620 gpm/700 psi,rotate A.work every 30 minutes and ng service while waiting on weather. Weather status:INCREASING CLOUDS.AREAS OF FOG.LOWS 50 TO 55 BELOW.SOUTHWEST WINDS 5 TO 15 MPH.WINDCHILL LOWS 70 to 80 BELOW. Daily Contacts Position Contact Name Company Title E-mail Office Mobile • Eni representative Frank Cormier Eni Petroleum Sr.Drip.Spvr. 907-685-1493 337-277-1809 Eni representative Ben Perry Eni Petroleum Sr.Ddg.Spvr. 907-685-1493 Eni representative Angelo Lamarina Eni Petroleum Drip Spvr. angelo.lamanna@enipetroleum.com 907-685-1493 907-903-7269 Eni representative Sach Bowe Eni Petroleum Materal Coordinator 907-685-1491 907-299-0531 Eni representative Greg Parker Eni Petroleum Expediter 907-980-7545 Eni representative Bernie Leas Eni Petroleum Rig Clerk 907-670-8601 907-575-9427 Eni representative Steve Millea ENI Petroleum HSE 907-685-1496 Tool Push Bruce Simonson Nabors Alaska Drilling Tool Pusher 907-670-1492 Tool Push Mattt Turcotte Nabors Alaska Drilling Tour Pusher 907-670-1492 Last Casing seat Cas.Type OD(In) ID(in) Grade Top(mKB) Bottom(mKB) Run Date CASING 133/8 12.415 L80 0.01 737.01 1/21/2012 Last Leakoff Test Depth(mKB) TVD(mKB) Fluid Type Fluid Density(gIL) P Surf Applied(kgflcm') Eq.Mud Weight(gIL) P LeakOff(kgflcm') fifi* Eni E&P Division [Well Name:0115-S4 ENI Petroleum Co.Inc. Daily Report Well Code:26195 Field Name: NIKAITCHUQ • API/UWI:50-029-23460-00-00 2�,rt Date:1/25/2012 - Report#: 12 l "II page 1 of 1 Wellbore name: 0115-S4 Well Header Permit/Concession N° Operator ENI Share(%) Well Configuration type 402100 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(m) Ground Level(m) Water Depth(m) RKB-Base Flange(m) RKB-Tubing Spool(m) 16.22 3.72 11.37 Rig Information Contractor Rig Name Rig Type NABORS ALASKA NABORS 245 E 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) 0115-S4 DRILLING 1/18/2012 5,848.81 1,092.64 5,864.35 185.75 31.6 7.29 Daily Information End Depth(mKB) End Depth(TVD)(... Depth Progress(m) Drilling Hours(hr) Avg ROP(m/hr) FOB Temperature(°C) Weather Wind 740.66 661.13 0.00 84.0 42.8 Cloudy,Patchy Fog, 235°WSW @ I3 WC-70" mph Daily summary operation 24h Summary W.O.W. Operation at 07.00 Weather status:INCREASING CLOUDS.PATCHY ICE FOG.LOWS 50 TO 55 BELOW.SOUTHWEST WINDS 10 TO 20 MPH...STRONGEST NEAR THE COAST.WIND CHILL TO 85 BELOW NEAR THE COAST. 24h Forecast Finish to clean pits and trasfer mud from Ugnu tanks to rig pits-Displace to FazePro-Drill out float equipments,cement and 20'new hole-Perform FIT/LOT-Drill 12 1/4"section as per well plan. 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 00.00 24.00 24.00 DRILL E 22 TWO1 W.O.W.Circulating at reduced rate,600 GPM/700 psi to keep DH tools working off generator and saving batteries. Housekeeping and rig maintance. Checking lines for freezing. Weather status:INCREASING CLOUDS.PATCHY ICE FOG.LOWS 50 TO 55 BELOW.SOUTHWEST WINDS 10 TO 20 MPH...STRONGEST NEAR THE COAST.WIND CHILL TO 85 BELOW NEAR THE COAST. NOTE SAFETY ALERT: AT THESE WIND CHILLS EXPOSED FLESH WILL FREEZE IN LESS THAN TEN MINUTES RESULTING IN SEVERE FROSTBITE. Weather Forecast. Thursday...Mostly cloudy.Patchy ice fog.Highs 40 to 45 below.West winds 10 to 20 mph.Wind chill to 85 below in the morning along the coast. Thursday Night...Mostly cloudy.Scattered flurries in the evening.Patchy fog through the night.Lows 40 to 45 below.West winds around 15 mph.Wind chill to 70 below. Friday...Mostly cloudy.Patchy fog.Highs 30 to 35 below.Southwest winds around 15 mph. Friday Night...Mostly cloudy.Lows 40 to 45 below.Southwest winds around 15 mph. Daily Contacts Position Contact Name Company Title E-mail Office Mobile Eni representative Frank Cormier Eni Petroleum Sr.Ddg.Spvr. 907-685-1493 337-277-1809 Eni representative Ben Perry Eni Petroleum Sr.Ddg.Spur. 907-685-1493 Eni representative Angelo Lamanna Eni Petroleum DrIg Spvr. angelo.lamanna@enipetroleum.com 907-685-1493 907-903-7269 Eni representative Sach Bowe Eni Petroleum Materal Coordinator 907-685-1491 907-299-0531 Eni representative Greg Parker Eni Petroleum Expediter 907-980-7545 Eni representative Bernie Leas Eni Petroleum Rig Clerk 907-670-8601 907-575-9427 Eni representative Steve Millea ENI Petroleum HSE 907-685-1496 Tool Push Mike Williams Nabors Alaska Dolling Tool Pusher 907-670-1492 Tool Push Mattt Turcotte Nabors Alaska Dolling Tour Pusher 907-670-1492 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(mKB) Bottom(mKB) Run Date CASING 133/8 12.415 L80 0.01 737.01 1/21/2012 Last Leakoff Test Depth(mKB) ND(mKB) Fluid Type Fluid Density(g/L) P Surf Applied(kgf/cm') Eq.Mud Weight(g/L) P LeakOff(kgf/cm') Eni E&P Division I Well Name:0115-S4 ENI Petroleum Co.Inc. Daily Report Well Code: 26195 Field Name: NIKAITCHUQ a API/UW1:50-029-23460-00-00 �,r, Date:1/26/2012 - Report#: 13 (s I' II II page 1 of 1 Wellbore name: 0115-S4 Well Header Permit/Concession N° Operator ENI Share(%) Well Configuration type 402100 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(m) Ground Level(m) Water Depth(m) RKB-Base Flange(m) RKB-Tubing Spool(m) 16.22 3.72 11.37 Rig Information Contractor Rig Name Rig Type NABORS ALASKA NABORS 245 E 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) 0115-54 DRILLING 1/18/2012 5.848.81 1.092.64 5,864.35 185.75 31.6 8.29 Daily Information End Depth(mKB) End Depth(TVD)(... Depth Progress(m) Drilling Hours(hr) Avg ROP(m/hr) POB Temperature(°C) Weather Wind 740.66 661.13 0.00 84.0 -41.1 Cloudy,Patchy Fog, 225"WSW @ 14 WC-72" mph Daily summary operation 24h Summary W.O.W.(-50 F ambient/-80 F Windchill)-Slip and cut 60'drilling line-Rig maintenance-Finish cleaning active pits for mud displacement-Transfer OBM from Ugnu tanks to rig active pits-Thaw out and empty cuttings box. Operation at 07.00 Prepare and displace well to FazePro. 24h Forecast Finish cleaning pits and transfer mud from Ugnu tanks to rig pits-Displace to FazePro-Drill out float equipment,cement and 20'new hole-Perform FIT/LOT-DnII 12 1/4"section as per well plan. 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 06:00 6.00 6.00 DRILL E 22 TWO1 W.O.W.Circulating at reduced rate©2.290'with 600 GPM/700 psi to keep DH tools working off generator and saving batteries. Continue housekeeping and rig maintance. Cold weather-50 F ambient/-80 F Windchill. 06:00 10:00 4.00 10.00 DRILL E 25 P 'Slip and cut 60'drilling line.Inspect brakes.Calibrate crown saver.Service rig and top drive. 10:00 00:00 14.00 24.00 DRILL E 1 P 'Cleaning mud pits using warm water 80 F from FW pits:90%completed at 23:00 hrs(only pit 7 left,will be cleaned after mud displacement).Using heaters and steam lines to thaw out cuttings box and empty same with super sucker.Taking all fluids to WIF for disposal.Onloaded 285 bbls of OBM from Ugnu tank into the active pits.Continue circulate 600 gpm/700 psi and rotate BHA every 1.5 hrs @ 40 rpm/3700 frlbs TQ. Note:Slow operations due to extreme weather conditions-40 F to-45 F ambient I-70 F to-75 F Windchill. Daily Contacts Position _ Contact Name Company _ Title E-mail Office Mobile Eni representative Frank Cormier Eni Petroleum Sr.Drig.Spvr. 907-685-1493 337-277-1809 Eni representative Ben Perry Eni Petroleum Sr.Drlg.Spvr. 907-685-1493 Eni representative Angelo Lamarina Eni Petroleum Ddg Spvr. angelo.lamanna@enipetroleum.com 907-685-1493 907-903-7269 Eni representative Sach Bowe Eni Petroleum Materal Coordinator 907-685-1491 907-299-0531 Eni representative Greg Parker Eni Petroleum Expediter 907-980-7545 Eni representative Bemie Leas Eni Petroleum Rig Clerk 907-670-8601 907-575-9427 Eni representative Steve Milieu ENI Petroleum HSE 907-685-1496 Tool Push Mike Williams Nabors Alaska Drilling Tool Pusher 907-670-1492 Tool Push Mattt Turcotte Nabors Alaska Drilling Tour Pusher 907-670-1492 Last Casing seat I Cas.Type OD(in) ID(in) Grade Top(mKB( Bottom(mKB) Run Date CASING 133/8 12.415 L80 0.01 737.01 1/21/2012 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') 11* Eni E&P Division I Well Name:0115-S4 EN!Petroleum Co.Inc. Daily Report Well Code:26195 Field Name: NIKAITCHUO � API/UWI:50-029-23460-00-00 2^o Date:1/27/2012 - Report#: 14 II IIpage 1 of 1 Wellbore name: 0115-S4 Well Header Permit/Concession N° Operator ENI Share(%) Well Configuration type 402100 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(m) Ground Level(m) Water Depth(m) RKB-Base Flange(m) RKB-Tubing Spool(m) 16.22 3.72 11.37 Rig Information Contractor Rig Name Rig Type NABORS ALASKA NABORS 245 E 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) 0115-S4 DRILLING 1/18/2012 5,848.81 1,092.64 5.864.35 165.75. 31.6 9.29 Daily Information End Depth(mKB) End Depth(TVD)(... Depth Progress(m) Drilling Hours(hr) Avg ROP(m/hr) POB Temperature(`C) Weather Wind 740.66 661.13 0.00 84.0 -34.4 Mostly Cloudy.WC- 225"SW @ 15 mph 57' Gusts to 24 mph Daily summary operation 24h Summary Finish cleaning pits and prepare for mud displacement-Displace to FazePro-Circulate and condition for next interval-Drill out collar,plugs and cement down to 2,416'-Downtime:failure on TDS. Operation at 07.00 Working on TDS to replace cable in service loop. 24h Forecast Drill out shoe,rat hole and 20'new hole down to 2,450'-Perform FIT/LOT-Drill 12 1/4"section as per well plan. 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 06:00 6.00 6.00 DRILL E 1 P Circulating at reduced rate @ 2,290'with 600 gpm/700 psi while preparing for OBM displacement.Onload FazePro from Ugnu tanks.Suck out 120 bbls of WBM from pit 7 for displacement returns and tranfer to the WIF:hose froze up while transferring.Changed hose and resume offloading mud at the WIF:Ok.Wait on truck to retum at rig and stage it for displacement. 06 00 09:30 3.50 9.50 DRILL E 9 P 'Held PJSM.Displace well to 9.6 ppg FazePro @ 7 bpm/275 psi while reciprocate/rotate at 35 rpm/2K flubs TO.When good mud retumed,shut pumps down and blow down lines.Clean under shakers,pit 87 and possum belly. 09.30 16:30 7.00 16.50 DRILL E 7 P Circulate and condition FazePro mud from 9.6 ppg to 9.2+ppg @ 600 gpm/1030 psi. 16.30 22:00 5.50 22.00 DRILL E 6 P Drill out plugs+float collar+cement from 2,330'to 2,416'@ 650 gpm/1000 psi/60 rpm/3k flubs TO/1-10 Klbs WOB/ Up W1=102 K/Rot Wt=98 k/Dw Wl=95 k/MW=9.2+ppg.Float collar©2,334'and shoe @ 2,416'. 22.00 00:00 2.00 24.00 DRILL E 25 TRO4 Downtime:Top Drive blower shut off.Electrician troubleshoot same:need to replace cable in service bop.R/U and circulate©350 gpm/260 psi while repairing TDS(the shoe has not been drilled out yet). Daily Contacts Position Contact Name Company Title E-mail Office Mobile Eni representative Rodney McCoy Eni Petroleum Sr.Ddg.Spvr. 907-685-1493 Eni representative Angelo Lamarina Eni Petroleum Drtg Spvr. angelo.lamarina@enipetroleum.com 907-685-1493 907-903-7269 Eni representative Sach Bowe Eni Petroleum Materal Coordinator 907-685-1491 907-299-0531 Eni representative Greg Parker Eni Petroleum Expediter 907-980-7545 Eni representative Bernie Leas Eni Petroleum Rig Clerk 907-670-8601 907-575-9427 Eni representative Steve Millea ENI Petroleum HSE 907-685-1496 Tool Push Mike Williams Nabors Alaska Dolling Tool Pusher 907-670-1492 Tool Push Matt Turcotte Nabors Alaska Drilling Tour Pusher 907-670-1492 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(mKB) Bottom(mKB) Run Date CASING 133/8 12.415 L80 0.01 737.01 1/21/2012 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') 746.76 665.49 OBM 1102.4 24.6 1472.2, 97.9 0 1 Eni E&P Division I Well Name:0115-S4 EN!Petroleum Co.Inc. Daily Report Well Code:26195 Field Name: NIKAITCHUO • 2^rt Date:1/28/2012 - Report#: 15 II APIIUWI:50-029-23460-00-00 II II page 1 of 1 Wellbore name: 0115-S4 Well Header PermitConcession N° Operator ENI Share(%) Well Configuration type 402100 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(m) Ground Level(m) Water Depth(m) RKB-Base Flange(m) RKB-Tubing Spool(m) 16.22 3.72 11.37 Rig Information Contractor Rig Name Rig Type NABORS ALASKA NABORS 245E 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) DES(days) 0115-S4 DRILLING 1/18/2012 5.848.81 1092.64 5,864.35 185.75 31.6 10.29 Daily Information End Depth(mKB) End Depth(TVD)(... Depth Progress(m) Drilling Hours(hr) Avg ROP(m/hr) POB Temperature(°C) Weather Wind 936.96 782.89 196.29 9.98 19.7 85.0 -30.0 Cloudy,WC-41' 190°S @ 8 mph Daily summary operation 24h Summary Repair TDS-Drill out shoe,rat hole and 20'new formation down to 2.450'-CBU-Performed LOT-EMW=12.3 ppg-Drill 12 1/4"section 1/2,450'03,074'(2,610'TVD). Operation at 07.00 Drill 12 1/4"section as per well plan.Current depth 3,187'. 24h Forecast Doll 12 1/4"section as per well plan. Lithology Shows MAASP(kgflcm') Mud Weight(gIL) 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 25 TR04 Downtime:Top Drive blower shut off.Electrician troubleshoot same,need to replace cable in service loop.Circulate @ 350 gpm/260 psi while repairing TDS(the shoe has not been drilled out yet)running new wire for blower motor. 06:00 0730 1.50 7.50 DRILL E 3 P ' Drill out shoe,rat hole and 20'of new 1 2 1/4"hole f/2,430'02,450'@ 650 gpm/1000 psi/60 rpm/36 ft°Ibs TO/5-10 Klbs c" WOO/Up Wt=100 K/Rot Wt=90k/Dw Wt=95k/MW=9.2+ppg. 07.30 08.00 0.50 8.00 DRILL E 7 P Circulate B/U and condition FazePro mud fror LOT/FIT @ 650 gpm/1088 psi/60 rpm/3k ft'Ibs TO/Mud Weight In&Out =9.2 ppg/10 min Gel=10 lb/1001e. 0800 09.00 1.00 9.00 DRILL E 11 P Rig up lines and perform LOT with 9.2 ppg FazePro OBM-Max surface pressure of 400 psi-Leak off pressure=350 psi- EMW"=12.3 ppg-R/D testing equipment. 09.00 12:00 3.00 12.00 DRILL E 3 P Drill rotary 0 12 G"new hole(/2,450'02,585'1650 gym @ 1190 psi 160 rpm @ 3.4k(fibs\WOB=15+25k lb\Up w1= 105k lb-Dw wt=96k lb-Rot wt=97k lb\Mud wt=9.2+ppg-Take survey as needed-Ream and wash 30'every connection. 12:00 00:00 12.00 24.00 DRILL E 3 P Drill rotary 0 12'/."new hole f/2,585'0/3,074'(2,610'TVD)1750 qpm @ 1480 psi 1120 rpm @ 3.4k Ribs\WOB=15+40k lb\Up wt=107k Ib-Dw wt=97k lb-Rot w1=102k Ib\Mud wt=9.2+ppg-ECD=9.8 ppg\Take survey every stand- Ream and wash 30'every connection.Encountered very hard spot @ 2,700'8 2.810'. Daily ADT=9.98 hrs-Cumulative ADT=9.98 hrs/JAR=188.3 Hrs. Daily Contacts Position Contact Name Company Title E-mail Office Mobile Eni representative Rodney McCoy Eni Petroleum Sr.DrIg.Spur. 907-685-1493 Eni representative Angelo Lamarina Eni Petroleum Drtg Spvr. angelo.Iamarina@enipetroleum.com 907-685-1493 907-903-7269 Eni representative Sach Bowe Eni Petroleum Materal Coordinator 907-685-1491 907-299-0531 Eni representative Greg Parker Eni Petroleum Expediter 907-980-7545 Eni representative Bernie Leas Eni Petroleum Rig Clerk 907-670-8601 907-575-9427 Eni representative Steve Millea ENI Petroleum HSE 907-685-1496 Tool Push Mike Williams Nabors Alaska Drilling Tool Pusher 907-670-1492 Tool Push Mattt Turcotte Nabors Alaska Drilling Tour Pusher 907-670-1492 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(mKB) Bottom(mKB) Run Date CASING 133/8 12.415 L80 0.01 737.01 1/21/2012 Last Leakoff Test Depth(mKB) TVD(mKB) Fluid Type Fluid Density(gIL) P Surf Applied(kgflcm') Eq.Mud Weight(gIL) P LeakOff(kgflcm') 746.76 665.49 OBM 1102.4 24.6 1472.2 97.9 Eni E&P Division I Well Name:0115-S4 ENI Petroleum Co.Inc. Daily Report Well Code:26195 Field Name:NIKAITCHUO ri* • APIIUWI:50-029-23460-00-00 2 n rt Date:1/29/2012 - Report#: 16 'I �I II page 1 of 1 Wellbore name: 0115-S4 Well Header Permit/Concession N' Operator ENI Share(%) Well Configuration type 402100 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(m) Ground Level(m) Water Depth(m) RKB-Base Flange(m) RKB-Tubing Spool(m) 16.22 3.72 11.37 Rig Information Contractor Rig Name Rig Type NABORS ALASKA NABORS 245 E 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) 0115-54 DRILLING 1/18/2012 5,848.81 1,092.64 5,864.35 185.75 31.6 11.29 Daily Information End Depth(mKB) End Depth(TVD)(... Depth Progress(m) Drilling Hours(hr) Avg ROP(m/hr) POB Temperature(CC) Weather Wind 1,108.25 840.35 171.30 15.38 11.1 85.0 -32.8 Cloudy,WC-27' Winds Calm Daily summary operation 24h Summary Drill 12 1/4"section 1/3,074'03,636'(2,755'TVD). Operation at 07.00 Drill 12 1/4"section as per well plan.Current depth 4,020'. 24h Forecast Drill 12 1/4"section as per well plan. Lithology Shows MAASP(kgflcm') Mud Weight(gIL) 1108.4 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00'00 09.30 9.50 9.50 DRILL E 3 P Drill rotary 0 12 G`new hole 1/3.074'03,261'1750-900 gpm @ 1550-2050 psi 180-120 rpm @ 5+7k ftlbs\WOB=10+40k lb\Up wt=105k lb-Dw wt=90k lb-Rot wt=101k lb\Mud w1=9.2+ppg-ECD=9.8 ppg I Take survey every stand. Encountered very hard spot @ 3,14U-3,160'8.3.180'-3,210'. 09:30 11:00 1.50 11.00 DRILL E '21 TW03 Circulate and Wait on DD @ 650 gpm/1250 psi/60 rpm. 11:00 18:00 7.00 18.00 DRILL E 3 P Drill rotary 0 12''/."new hole 1/3,261'03,385'1650 gpm @ 1280 psi\60-120 rpm @ 5+7k ftlbs\WOB=25.35k lb\Up wt= 105k lb-Dwwt=90k lb-Rot wt=102k lb\Mud wt=9.2+ppg-ECD=9.7 ppg\Take survey every stand.Encountered very hard spot 8 3,280'0 3,340'. 18.00 00:00 6.00 24.00 DRILL E '3 P Drill rotary 0 12 G"new hole f/3,385'1/3,636'(2,757'TVD)1900 gpm @ 2230 psi\120 rpm @ 4+5k fllbs\WOB=20+30k lb\Up w1=112k lb-Dw wt=91k lb-Rot wt=101k lb\Mud w1=9.2+ppg-ECD=9.82 ppg\Take survey every stand- Ream and wash 30'every connection.Encountered very hard spot @ 3,47g-3.480'. Daily ADT=15.38 hrs-Cumulative ADT=25.36 hrs/JAR=203.7 Hrs. Daily Contacts Position Contact Name Company Title E-mail Office Mobile Eni representative Rodney McCoy Eni Petroleum Sr.Drlg.Spvr. 907-685-1493 Eni representative Angelo Lamarina Eni Petroleum Drlg Spvr. angelo.lamanna@enipetroleum.com 907-685-1493 907-903-7269 Eni representative Sach Bowe Eni Petroleum Materal Coordinator 907-685-1491 907-299-0531 Eni representative Greg Parker Em Petroleum Expediter 907-980-7545 Eni representative Bernie Leas Eni Petroleum Rig Clerk 907-670-8601 907-575-9427 Eni representative Steve Millea ENI Petroleum HSE 907-685-1496 Tool Push Mike Williams Nabors Alaska Drilling Tool Pusher 907-670-1492 Tool Push Mattt Turcotte Nabors Alaska Drilling Tour Pusher 907-670-1492 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(mKB) Bottom(mKB) Run Date CASING 133/8 12.415 L80 0.01 737.01 1/21/2012 - Last Leakoff Test Depth(mKB) TVD(mKB) Fluid Type Fluid Density(gIL) P Surf Applied(kgflcm') Eq.Mud Weight(gIL) P LeakOff(kgf/cm') 746.76 665.49 OBM 1102.4 24.6 1472.2 97.9 fi* Eni E&P Division 'Well Name:0115-S4 ENI Petroleum Co.Inc. Daily Report Well Code:26195 Field Name:NIKAITCHUO � API/UWI:50-029-23460-00-00 2^ Date:1/30/2012 - Report#: 17 II II page 1 of 1 Wellbore name. Ol15-S4 Well Header PermitiConcession N° Operator ENI Share(%) Well Configuration type 402100 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(m) Ground Level(m) Water Depth(m) RKB-Base Flange(m) RKB-Tubing Spool(m) 16.22 3.72 11.37 Rig Information Contractor Rig Name Rig Type NABORS ALASKA NABORS 245 E 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) 0115-S4 DRILLING 1/18/2012 5,848,81 1,092.64 5,864.35 185.75 31.6 12.29 Daily Information End Depth(mKB) End Depth(TVD)(... Depth Progress(m) Drilling Hours(hr) Avg ROP(m/hr) POB Temperature(°C) Weather Wind 1,663.90 914.97 555.65 15.78 35.2 85.0 -41.7 Partly Cloudy.WC- 225'WSW @ 8 mph 65' Daily summary operation 24h Summary Drill 12 1/4"section 1/3,636't/5,459'(3,002'TVD). Operation at 07.00 Drill 12 1/4"section as per well plan.Current depth @ 05:00 hrs 6,037'. 24h Forecast Drill 12 1/4"section as per well plan. Lithology Shows MAASP(kgflcm2) Mud Weight(g/L) - 1108,4 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 rotary 0 12 Y. new hole(/3,636'1/4,200'\900 qpm @ 2350 psi 1120 rpm @ 4.5k ft.lbs\WOB=10+25k lb\Up wt= 110k Ib-Dw wt=90k lb-Rot wt=98k lb\Mud wt=9.2+ppg-ECD=10.03 ppg\Take survey every stand-Ream and wash 30'every connection. 06.00 12:00 6.00 12.00 DRILL E 3 P Drill rotary 0 12 7."new hole(/4,200'614,692'(850 gpm @ 2290 psi\120 rpm @ 4.5k Nibs\WOB=10+25k lb\Up wt= 110k Ib-Dw wt=90k lb-Rot wt=98k lb I Mud wt=9.2+ppg-ECD=10.03 ppg\Take survey every stand-Ream and wash 30'every connection. 12:00 18:00 6.00 18.00 DRILL E 3 P Drill rotary 0 12 W new hole(/4,692'1/5,090'\875 gpm @ 2472 psi 1120 rpm @ 4.5k Nibs\WOB=25.30k lb\Up wt= 120k lb-Dw wt=90k lb-Rot wt=100k lb\Mud wt=9.2+ppg-ECD=9.8 ppg\Take survey every stand-Ream and wash 30'every connection. 18.00 00.00 6.00 24.00 DRILL E 3 P Drill rotary 0 12''Al"new hole f/5,090'1/5,459'(3,002'TVD)1 850 gpm @ 2420 psi 1120 rpm @ 5.6k ft-lbs\WOB=15+25k lb\Up wt=120k lb-Dw w1=90k lb-Rot wt=100k lb\Mud wt=9.2+ppg-ECD=9.92 ppg\Take survey every stand- Ream and wash 30'every connection.Encountered very hard spot @ 5,090-5,110'.Schlumberge Xceed TF bad while drilling hard spot.No problem once we passed trough. Daily ADT=15.78 hrs-Cumulative ADT=41.14 hrs/JAR=219.5 Hrs. Daily Contacts Position Contact Name Company Tide E-mail Office I Mobil. Eni representative Rodney McCoy Eni Petroleum Sr.Ddg.Spvr. 907-685-1493 Eni representative Angelo Lamarina Eni Petroleum Drlg Spur. angelo.lamanna@enipetroleum.com 907-685-1493 907-903-7269 Eni representative Sach Bowe Eni Petroleum Materal Coordinator 907-685-1491 907-299-0531 / Eni representative Greg Parker Eni Petroleum Expediter 907-980-7545 Eni representative Bernie Leas Eni Petroleum Rig Clerk 907-670-8601 907-575-9427 Eni representative Steve Millea ENI Petroleum HSE 907-685-1496 Tool Push Mike Williams Nabors Alaska Drilling Tool Pusher 907-670-1492 Tool Push Mattt Turcotte Nabors Alaska Drilling Tour Pusher 907-670-1492 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(mKB) Bottom(mKB) Run Date CASING 133/8 12.415 L80 0.01 737.01 1/21/2012 Last Leakoff Test Depth(mKB) TVD(mKB) Fluid Type Fluid Density(gIL) P Surf Applied(kgflcm2) Eq.Mud Weight(g/L) P LeakOff(kgflcm.) 746.76 665.49 OBM 1102.4 24.6 1472.2 97.9 i 1� En!E&P Division . well Name:0115-S4 ENI Petroleum Co.Inc. Daily Report` Well Code:26195 Field Name:NIKAITCHUO • API/UWI:50-029-23460-00-00 2^n Date:1/31/2012 - Report#: 18 I' II I� page 1 of 1 Wellbore name: O)15-S4 Well Header Permit/Concession N° Operator ENI Share(%) Well Configuration type 402100 .ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(m) Ground Level(m) Water Depth(m) RKB-Base Flange(m) RKB-Tubing Spool(m) 16.22 3.72 11.37 Rig Information Contractor Rig Name Rig Type NABORS ALASKA NABORS 245 E 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) 0115-04 DRILLING 1/18/2012 5,848.81 1,092.64 5,864.35 185.75 31.6 13.29 Daily Information End Depth(mKB) End Depth(TVD)(... Depth Progress(m) Drilling Hours(hr) Avg ROP(m/hr) POB Temperature(°C) Weather Wind 2.061.36 972.74 397.46 10.22 38.9 85.0 -46.1 Mostly Cloudy, 225°SW @ 9 mph Patchy Fog,WC-78' Daily summary operation 24h Summary Drill 12 1/4"section f/5,459'(/6,763'(3,144'ND)-Xceed tool unable to keep good TF:decided to POOH-Circulate-BROOH 05,555'. Operation at 07.00 BROOH @ 4,961. 24h Forecast BROOH-Circulate tit shakers clean-POOH and L/D BHA-BOP test-P/U and RIH BHA#6. Lithology Shows MAASP(kgf/cm') Mud Weight(g/L) 1108.4 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 rotary 0 12 7."new hole f/5,459'(16,140'\850 gpm @ 2500 psi\120 rpm @ 5+6k ftlbs\WOB=10+25k lb\Up wt= 122k lb-Dw wt=90k lb-Rot wt=100k lb\Mud wt=9.2+ppg-ECD=9.8 ppg\Take survey every stand-Ream and wash 30'every connection. 06:00 12:00 6.00' 12.00 DRILL E 3 'P Drill rotary 0 12 W new hole f/6,140'(/6,608'\850 gpm @ 2900 psi\120 rpm @ 6+8k fllbs\WOB=10+25k lb\Up wt= 125k lb-Dw wt=90k lb-Rot wt=100k lb\Mud wt=9.2+ppg-ECD=9.8 ppg\Take survey every stand-Ream and wash 30'every connection. 12:00 18:00 6.00 18.00 DRILL E 3 P Drill rotary 0 12 7."new hole f/6,608'V6,763'(3,191'ND)\850-900 gpm @ 2900 psi\120 rpm @ 6+7k fhlbs\WOB= 10+20k lb\Up wt=130k lb-Ow wt=88k lb-Rot wt=104k lb\Mud wt=9.3 ppg-ECD=9.9 ppg\Take survey every stand -Ream and wash 30'every connection.Encountered hard spot @ 6,690-6,700'8.6,750'-6,760'. While drilling hard spot @ 6,762'Schlumberger Xceed not able to keep correct TF.Attempt to communicate with tool and change parameters(RPM and Flow In):TF still bad.Decided to POOH and change out tools. Daily ADT=10.22 hrs-Cumulative ADT=51.36 hrs/JAR=229.7 Hrs. 18:00 19:30 1.50' 19.50'DRILL E 7 TD01 Circulate 2x B/U while rotating and reciprocating pipes f/6,763 1/6,417'(R/B one stand every B/U)@ 900 gpm/2800 psi/ 120 rpm/6+7k S'lbs TQ. 19:30 00:00 4.50 24.00 DRILL E 6 TD01 BROOH f/6,417'(/5,555'@ 900 gpm/2800 psi/120 rpm/6+7k ft'lbs TO. Daily Contacts Position Contact Name Company Title E-mail _ Office Mobile Eni representative Rodney McCoy Eni Petroleum Sr.Ddg.Spvr. 907-685-1493 Eni representative Angelo Lamarina Eni Petroleum Ddg Spvr. angelo.lamarina@enipetroleum.com 907-685-1493 907-903-7269 Eni representative Bernie Leas Eni Petroleum Rig Clerk 907-670-8601 907-575-9427 Eni representative Tom Klein Eni Petroleum Material Coordinator 907-685-1491 Eni representative Mike Nelson Eni Petroleum HSE 907-685-1496 Eni representative Greg Parker Eni Petroleum Expediter 907-980-7545 Tool Push Mike Williams Nabors Alaska Drilling Tool Pusher 907-670-1492 Tool Push Matt Turcotte Nabors Alaska Drilling Tour Pusher 907-670-1492 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(mKB) Bottom(mKB) Run Date CASING 133/8 12.415 L80 0.01 737.01 1/21/2012 Last Leakoff Test Depth(mKB) ND(mKB) Fluid Type Fluid Density(gIL) P Surf Applied(kgflcm') Eq.Mud Weight(gIL) P LeakOff(kgf/cm') 746.76 665.49 OBM 1102.4 24.6 1472.2 97.9 1111* Eni E&P Division [Well Name:0)15-54 ENI Petroleum Co.Inc. Daily Report Well Code:26195 Field Name: NIKAITCHUO • API/t1Wl:50-029-23460-00-00 2^111 r,II Date:2/1/2012 - Report#: 19 page 1 of 1 Wellbore name: 0115-S4 Well Header Permit/Concession N. Operator ENI Share(%) Well Configuration type 402100 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(m) Ground Level(m) Water Depth(m) RKB-Base Flange(m) RKB-Tubing Spool(m) 16.22 3.72 11.37 Rig Information Contractor Rig Name Rig Type NABORS ALASKA NABORS 245E 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) 0115-S4 DRILLING 1/18/2012 5,848.81 1,092.64 5,864.35 185.75 31.6 14.29 Daily Information End Depth(mKB) End Depth(TVD)(... Depth Progress(m) Drilling Hours(hr) Avg ROP(m/hr) POB Temperature(°C) Weather Wind 2,061.36 972.74 0.00 85.0 -32.8 Cloudy,WC-55" 45°NE @ 16 mph Daily summary operation 24h Summary BROOH-Circulate hole clean @ 13 3/8"shoe depth-POOH and L/D 5"DPs w/bad hard band-POOH and L/D BHA#5 Operation at 07.00 BOP test 24h Forecast Complete to POOH and UD BHA#5-BOP test-M/U and RIH BHA#6 Lithology Shows MAASP(kgf/cm') Mud Weight(gIL) 1108.4 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 0000 02:00 2.00 2.00 DRILL E 4 TD01 BROOH U5555'1/4961'(900 gpm @ 2600 psi-120 rpm @ 6k ft-lbs) 02:00 09:00 7.00 9.00 DRILL E 25 TRO2 Replace 4"valve on mud pump 09:00 17:00 8.00 17.00 DRILL E 4 TD01 BROOH f/4961'112393'(900 gpm @ 2600?1900 psi-120 rpm @ 3.4.4k ft'lbs) 17:00 1830 1.50 18.50 DRILL E 7 TD01 Circulate x5 BU till hole clean(900 gpm @ 1900?1700 psi-120 rpm @ 2.8k fttbs)-Flow check 10'-Pump Slug pill 18:30 22:00 3.50 22.00 DRILL E 4 TD01 POOH on elevator 1/2393'1/218'-UD 30 Jt 5"DP w/bad hard band 22:00 00:00 2.00 24.00 DRILL E 5 TD01 POOH and UD BHA#5(in progress) Daily Contacts Position Contact Name Company Title E-mail Office Mobile Eni representative Rodney McCoy Em Petroleum Sr.Ddg.Spur. 907-685-1493 Eni representative Mirko Musumeci Eni Petroleum Ddg Spur. 907-685-1493 907-903-7269 Eni representative Bemie Leas Eni Petroleum Rig Clerk 907-670-8601 907-575-9427 Em representative Tom Klein Em Petroleum Material Coordinator 907-685-1491 Em representative Mike Nelson Em Petroleum HSE 907-685-1496 Eni representative Greg Parker Eni Petroleum Expediter 907-980-7545 Tool Push Mike Williams Nabors Alaska Drilling Tool Pusher 907-670-1492 Tool Push Matt Vanhoose Nabors Alaska Drilling Tour Pusher 907-670-1492 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(mKB) Bottom(mKB) Run Date CASING 133/8 12.415 L80 0.01 737.01 1/21/2012 Last Leakoff Test Depth(mKB) ND(mKB) Fluid Type Fluid Density(gIL) P Surf Applied(kgflcm') Eq.Mud Weight(g/L) P LeakOtf(kgf/cm') 746.76 665.49 OBM 1102.4 24.6 1472.2 97.9 fill* Eni E&P Division I Well Name:0115-S4 ENI Petroleum Co.Inc. Daily Report Well Code:26195 Field Name:NIKAITCHUQ • APIIUWM:50-029-23460-00-00 2�,r, Date:2/2/2012 - Report#: 20 II II II page 1 of 1 Wellbore name: 0115-S4 Well Header Permit/Concession N° Operator ENI Share(%) Well Configuration type 402100 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(m) Ground Level(m) Water Depth(m) RKB-Base Flange(m) RKB-Tubing Spool(m) 16.22 3.72 11.37 Rig Information Contractor Rig Name Rig Type NABORS ALASKA NABORS 245 E 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) 0115-S4 DRILLING 1/18/2012 5.848.81 1.092.64 5.864.35 185.75 31.6 15.29 Daily Information End Depth(mKB) End Depth(TVD)(... Depth Progress(m) Drilling Hours(hr) Avg ROP(mlhr) POB Temperature(•C) Weather Wind 2 154.63 987.82 93.27 4.50 20.7 85.0 -32.2 Mostly Cloudy,WC- 45"NE @ 12 mph 50° Daily summary operation 24h Summary Complete to POOH and L/D BHA#5-BOP test-M/U and RIH BHA#6-Drill ahead 12'/."section V676311/6894' Operation at 07.00 Drill ahead 12'/."section as per wellplan @ 7,278'MD 24h Forecast Drill ahead 12'/."section to planned TD 10480' Lithology Shows MAASP(kgflcm') Mud Weight(gIL) 1114.4 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 5 TD01 'POOH and L/D BHA#5(Bit Dull:3-5-WT-A-E-3-BT-PR)-Download MWD tools 01:00 03.00 2.00 3.00 DRILL C 1 P Pull wear ring-Set test plug-Fill Stack and lines wl water-Purge air out of system-R/U BOP test equipment 03.00 07:30 4.50 7.50 DRILL C 12 P -Test BOP as per AOGCC requirements-Annular @ 250?2500 psi-Rams,choke manifold,floor and top drive valves @ 25073500 psi-Chart record-BOP test witness waived by AOGCC rep.Lou Grimaldi 07.30 08:30 1.00 8.50 DRILL C 5 P Pull test plug-Set wear ring 08:30 13:00 4.50 13.00 DRILL E 5 TDO/ R/U Handling equipment-Held PJSM-P/U,M/U and RIH BHA#6[B0 12'%"Smith GF15-BVCPS TFA:1.116(s/n PW1083)+Xceed900 w1 float+ARC 825+NM Stab+PowerPulse+NM Stab+x3 NM Flex DC+Float Sub+8"Jar(s/n 42203D)+XO+x2 5"H W DP+5"DP+12 7."Gost Reamer]-Fill pipe-Shallow test-Down link Xceed 13:00 19:30 6.50 19.50 DRILL E 4 TD01 RIH 86763'replacing 5"DP culled[hole instability @ 29001-L/D 11 Jt 5"DP w/bad hard band(total 41 Jt) 19:30 00:00 4.50 24.00 DRILL E 3 P Drill rotary 0 12 W section 1/6763'0/6894'\850+900 gpm @ 3000 psi\120 rpm©6+7k nibs I WOB=30k lb\Up wt=132k lb-Dw wt=88k lb-Rot wt=103k lb\Mud wt=9.3 ppg-Take survey as needed-Ream and wash one Jt every connection Daily ADT=2.91 hrs [ADT=2.91-JAR=233.1 hrs] Daily Contacts Position Contact Name Company Title I E-mail Office Mobile Eni representative Rodney McCoy Eni Petroleum Sr.Ddg.Spvr. 907-685-1493 Eni representative Mirka Musumeci Eni Petroleum Drlg Spvr. 907-685-1493 907-903-7269 Eni representative Bernie Leas Eni Petroleum Rig Clerk 907-670-8601 907-575-9427 Eni representative Tom Klein Eni Petroleum Material Coordinator 907-685-1491 Eni representative Mike Nelson Eni Petroleum HSE 907-685-1496 Eni representative Greg Parker Eni Petroleum Expediter 907-980-7545 Tool Push Mike Williams Nabors Alaska Dolling Tool Pusher 907-670-1492 Tool Push Matt Vanhoose Nabors Alaska Drilling Tour Pusher 907-670-1492 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(mKB) Bottom(mKB) Run Date CASING 133/8 12.415 L80 0.01 737.01 1/21/2012 Last Leakoff Test Depth(mKB) TVD(mKB) Fluid Type Fluid Density(gIL) P Surf Applied(kgflcm') Eq.Mud Weight(gIL) P LeakOff(kgflcm') 746.76 665.49 OBM 1102.4 24.6 1472.2 97.9 Eni E&P Division I Well Name:0115-S4 11111* ENI Petroleum Co.Inc. Daily Report Well Code:26195 Field Name: NIKAITCHUO • APIIUWI:50-029-23460-00-00 enil Date:2/3/2012 - Report#: 21 II I' page 1 of 1 Wellbore name: 0115-S4 Well Header Permit/Concession N° Operator ENI Share(%) Well Configuration type 402100 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(m) Ground Level(m) Water Depth(m) RKB-Base Flange(m) RKB-Tubing Spool(m) 16.22 3.72 11.37 Rig Information Contractor Rig Name Rig Type NABORS ALASKA NABORS 245 E 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) 0115-04 DRILLING 11812012 5.848.81 1,092.64 5,864.35 185.75 31.6 16.29 Daily Information End Depth(mKB) End Depth(TVD)(... Depth Progress(m) Drilling Hours(hr) Avg ROP(m/hr) POB Temperature(°C) Weather Wind 2,685.59 1,065.67 530.96 15.03 35.3 84.0 -30.0 Mostly Cloudy.WC- 270"W @ 14 mph 47° Daily summary operation 24h Summary Drill ahead 12''/."section V6894'1/8808' Operation at 07.00 Drill ahead 12''A"section as per wellplan @ 9,060'MD 24h Forecast Drill ahead 12''/.`section to planned TD 10480'-Clean up cycles-BROOH Lithology Shows MAASP(kgflcm') Mud Weight(gIL) 1114.4 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 rotary 0 12 W section(/6894'1/7560'\900?850 gpm @ 3000 psi\120 rpm @ 8+10k nibs\WOB=5+30k lb\ECD= 9.77710.05 ppg\Up wt=135k lb-Dw wt=80k lb-Rot wt=103k lb\Mud wt=9.2+ppg-Take survey as needed-Ream and wash one Jt every connection 06:00 12:00 6.00' 12.00-DRILL E 3 P 'Drill rotary 0 12 7."section 1/7560'1!7992'\850 gpm @ 3000?3150 psi/120 rpm @ 8+10k ft'lbs\WOB=5+30k lb\ECD= 10.0579.87 ppg\Up wt=135k lb-Dw w1=80k lb-Rot wt=110k lb\Mud wt=9.2+ppg-Take survey as needed-Ream and wash one Jt every connection 12:00 18:00 6.00. 18.00 DRILL E 3 P Drill rotary 0 12'1/4"section 1/7992'1/8523'1 850 gpm @ 3150?3180 psi\60+120 rpm @ 7+11k ft'bs\WOB=3+30k Ib\ ECD=9.87?10.18 ppg\Up wt=160k lb-Dw wt=80k lb-Rot wt=110k lb\Mud wt=9.3 ppg-Take survey as needed- Ream and wash one Jt every connection 1800 00:00 6.00' 24.00 DRILL E _ P -Drill rotary 0 12 W section(/8523'8/8808'\850 gpm @ 3180?3220 psi\80+120 rpm @ 8+12k&lbs\WOB=5+30k lb\ ECD=10.1879.77 ppg\Up wt=195k lb-Dw wt=80k lb-Rot wt=110k lb\Mud wt=9.3 ppg-Take survey as needed- Ream and wash one Jt every connection Daily ADT=16.5 hrs [ADT=19.53-JAR=249.6 hrs) Daily Contacts Position Contact Name Company Title E-mail Office Mobile Eni representative -Rodney McCoy Eni Petroleum Sr.Orig.Spur. '907-685-1493 V Eni representative Mirko Musumeci Eni Petroleum Ddg Spvr. 907-685-1493 907-903-7269 Eni representative Bernie Leas Eni Petroleum Rig Clerk 907-670-8601 907-575-9427 Eni representative Tom Klein Eni Petroleum Material Coordinator 907-685-1491 Eni representative Mike Nelson Eni Petroleum HSE 907-685-1496 Eni representative Greg Parker Eni Petroleum Expediter 907-980-7545 Tool Push Mike Williams Nabors Alaska Drilling Tool Pusher 907-670-1492 Tool Push Man Vanhoose Nabors Alaska Drilling Tour Pusher 907-670-1492 i Last Casing seat Cas.Type OD(in) ID(in) Grade Top(mKB) Bottom(mKB) Run Date CASING 133/8 12.415 L80 0.01 737.01 1/21/2012 Last Leakoff Test - Depth(mKB) TVD(mKB) Fluid Type Fluid Density(gIL) P Surf Applied(kgflcm') Eq.Mud Weight(gIL) P LeakOff(kgflcm') 746.76 665.49 OBM 1102.4 24.6 1472.2 97.9 i If* Eni E&P Division 'Well Name:0115-54 ENI Petroleum Co.Inc. Daily Report Well Code:26195 Field Name:NIKAITCHUO • APIIUWI:50-029-23460-00-00 2^g Date:2/4/2012 - Report#: 22 II II page 1 of 1 Wellbore name: 0115-S4 Well Header Permit/Concession N° Operator ENI Share)%) Well Configuration type 402100 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(m) Ground Level(m) Water Depth(m) RKB-Base Flange(m) RKB-Tubing Spool(m) 16.22 3.72 11.37 Rig Information Contractor Rig Name Rig Type NABORS ALASKA NABORS 245 E 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) 0115-S4 DRILLING 1/18/2012 5,848.81 1,092.64 5,864.35 185.75 31.6 17.29 Daily Information End Depth)mKB) End Depth(TVD)(... Depth Progress(m) Drilling Hours)hr) Avg ROP(m/hr) POB Temperature(°C) Weather Wind 3,123.29 1.126.43 437.69 16.14 27.1 88.0 -17.2 Party Cloudy.WC-5' 190°S @ 5 mph Daily summary operation 24h Summary Drill ahead 12%"section 1/8808'910,247' • Operation at 07.00 Drill ahead 12 1/4"section at 10,380'MD. 24h Forecast Drill ahead 12W section to planned TD 10480'-Clean up cycles-BROOH 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 06.00 6.00 6.00 DRILL E 3 P Drill rotary 0 12%"section 1/8808'99195'1 8507870 gpm @ 3220?3410 psi 1120 rpm @ 7+12k f91bs\WOB=17+30k lb\ ECD=9.77?9.87 ppg\Up wt=165k lb-Ow wt=80k lb-Rot wt=110k lb\Mud wt=9.3+ppg-Take survey as needed- Ream and wash one Jt every connection 06:00 12:00 6.00 12.00 DRILL E 3 P Drill rotary 0 12%"section 1/9195'99725'\8702860 gpm @ 341073540 psi\120 rpm @ 8+14k ft.lbs\WOB=22+30k lb\ ECD=9.87 ppg\Up wt=170k lb-Dw wt=82k lb-Rot wt=110k lb\Mud wt=9.3+ppg-Take survey as needed-Ream and wash one Jt every connection 12:00 18:00 6.00 18.00 DRILL E 3 P Drill rotary 0 12%"section 1/9725'99943'\860 gpm @ 3540?3580 psi\60+120 rpm @ 5+10k fflbs\WOB=20+30k lb\ ECD=9.87710.6 ppg\Up wt=170k lb-Dwwt=82k lb-Rot w1=110k lb\Mud wt=9.4 ppg-Take survey as needed- Ream and wash one Jt every connection 18:00 00:00 6.00 24.00 DRILL E 3 P Drill rotary 0 12%"section 1/9943'910235'\860?850 gpm @ 3580?3590 psi 1120 rpm @ 8.5+9.5k fhlbs\WOB=24+30k lb\ECD=10.6?10.15 ppg\Up wt=170k lb-Dw wt=82k lb-Rot wt=110k lb\Mud wt=9.4 ppg-Take survey as needed- • Ream and wash one Jt every connection Daily ADT=15.65 hrs [ADT=35.18-JAR=265.4 hrs] Daily Contacts Position Contact Name Company Title E-mail Office Mobile Eni representative Rodney McCoy Eni Petroleum Sr.Ddg.Spur. 907-685-1493 Eni representative Mirko Musumeci Eni Petroleum Ddg Spur. 907-685-1493 907-903-7269 Eni representative Bernie Leas Eni Petroleum Rig Clerk 907-670-8601 907-575-9427 Eni representative Tom Klein Eni Petroleum Material Coordinator 907-685-1491 Eni representative Mike Nelson Eni Petroleum HSE 907-685-1496 Eni representative Greg Parker Eni Petroleum Expediter 907-980-7545 Tool Push Mike Williams Nabors Alaska Dulling Tool Pusher 907-670-1492 Tool Push Mari Vanhoose Nabors Alaska Drilling Tour Pusher 907-670-1492 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(mKB) Bottom(mKB) Run Date CASING 133/8 12.415 L80 0.01 737.01 1/21/2012 Last Leakoff Test Depth(mKB) ND(mKB) Fluid Type Fluid Density(gIL) P Surf Applied(kgflcm") Eq.Mud Weight(gIL) P LeakOff(kgflcm") 746.76 665.49 OBM 1102.4 24.6 1472.2 97.9 Eni E&P Division I Well Name:0115-S4 rig* ENI Petroleum Co.Inc. Daily Report Well Code:26195 Field Name: NIKAITCHUQ • API/UWI:50-029-23460-00-00 2^o Date:2/5/2012 - Report#: 23 II 'I page 1 of 1 Wellbore name: 0115-S4 Well Header Permit/Concession N° Operator ENI Share(%) Well Configuration type 402100 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(m) Ground Level(m) Water Depth(m) RKB-Base Flange(m) RKB-Tubing Spool(m) 16.22 3.72 11.37 Rig Information Contractor Rig Name Rig Type NABORS ALASKA NABORS 245 E 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) 0115-54 DRILLING 1/18/2012 5,848.81 1.092.64 5,864.35 185.75 31.6 18.29 Daily Information End Depth(mKB) End Depth(TVD)(... Depth Progress(m) Drilling Hours(hr) Avg ROP(m/hr) POB Temperature(°C) Weather Wind 3,185.16 1,132.79 61.87 4.21 14.7 89.0 -20.0 Mostly Clear,WC- 90"E @ 10 mph 21` Daily summary'operation " ==�� 24h Summary q Dr. ahead 12 G"section to TD 10450'-Clean up cycles-BROOH l era on at 07 B H BR H @ 5,879'9' MD. 24h For t BROOH until 2 teHrotet can-POOH on elevators and UD BHA#6-C/O rams ad 9 5/8"-R/U 9 5/8'Csg running equipment Lithology Shows MAASP(kgf/cm') Mud Weight(g/L) 1132.4 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 DRILL E 3 P Drill rotary 0 12 7."section f/10235't/TD(10450'MD-3716'ND-3663'SS)/850 gpm @ 3590?3650 psi 1120 rpm @ .11 8.5+11k ft-lbs/WOB=28+30k lb I ECD=10.15 ppg 1 Up wt=165k lb-Dw wt=82k lb-Rot wt=110k lb I Mud wt=9.3+ppg- Take survey as needed-Ream and wash one Jt every connection ..-- Daily ADT=4.21 hrs [ADT=39.39-JAR=304.79 hrs] 1 I 06:30 12:00 5.50 12.00 DRILL E 7 P Circulate x4 BU(870 gpm @ 3700?3690 psi-120 rpm @ 8?7.5k ft'Ibs)Rack back x1 Std each BU(/10450'1/10085' 12:00 18:00 6.00 18.00 DRILL E 7 'P Circulate 4x BU(8707880 gpm @ 3690?3580 psi-120 rpm @ 7.5?7k ft-lbs)rack back x2 Std every BU(/10085'59271' 14-4 18:00 00:00 ' 6.00' 24.00'DRILL E 6 P BROOH(/9271'57000'(880?900 gpm @ 3580?3175 psi-120 rpm @ 7k Ribs-7+8 min/Std)-No tight spot encountered Daily Contacts ' Position Contact Name Company Title E-mail Office Mobile Eni representative Rodney McCoy Eni Petroleum -Sr.Ddg.Spvr. 907-685-1493 Eni representative Mirko Musumeci Eni Petroleum Ddg Spvr. 907-685-1493 907-903-7269 Eni representative Bernie Leas Eni Petroleum Rig Clerk 907-670-8601 907-575-9427 Eni representative Tom Klein Eni Petroleum Matenal Coordinator 907-685-1491 Eni representative Mike Nelson Eni Petroleum •HSE 907-685-1496 Eni representative Greg Parker Eni Petroleum Expediter 907-980-7545 Tool Push Mike Williams Nabors Alaska Drilling Tool Pusher 907-670-1492 Tool Push Matt Vanhoose Nabors Alaska Dolling Tour Pusher 907-670-1492 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(mKB) Bottom(mKB) Run Date CASING 133/8 12.415 L80 0.01 737.01 1/21/2012 Last Leakoff Test Depth(mKB) ND(mKB) Fluid Type Fluid Density(gIL) P Surf Applied(kgflcm') Eq.Mud Weight(gIL) P LeakOff(kgflcm') 746.76 665.49 OBM 1102.4 24.6 1472.2 97.9 If* Eni E&P Division I Well Name:0115-S4 ENI Petroleum Co.Inc. Daily Report Well Code:26195 Field Name: NIKAITCHUQ • APIIUWI:50-029-23460-00-00 2^n Date:2/6/2012 - Report#: 24 II II�I page 1 of 1 Wellbore name: OI15-S4 Well Header Permit/Concession N° Operator ENI Share(%) Well Configuration type 402100 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(m) Ground Level(m) Water Depth(m) RKB-Base Flange(m) RKB-Tubing Spool(m) 16.22 3.72 11.37 Rig Information Contractor Rig Name Rig Type NABORS ALASKA NABORS 245 E 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) 0115-S4 DRILLING 1/18/2012 5,848.81 1,092.64 5,864.35 185.75 31.6 19.29 Daily Information End Depth(mKB) End Depth(TVD)(... Depth Progress(m) Drilling Hours(hr) Avg ROP(m/hr) POB Temperature(°C) Weather Wind 3,185.16 1,132.79 0.00 89.0 -20.6 Mostly Clear,WC- 90"E @ 12 mph 24" Daily summary operation 24h Summary BROOH U 13 3/8"Shoe-Circulate hole clean-Slip and Cut drilling line-TDS service and Rig maintenance-POOH and L/D BHA#6 Operation at 07.00 C/O rams w/9 5/8" 24h Forecast Complete to BROOH BHA#6-CIO rams w/9 5/8"-R/U 9 5/8"Csg running equipment-9 5/8"Csg job Lithology Shows MAASP(kgflcm') Mud Weight(gIL) 1114.4 Time Log Start End Cum Time Time _Dur(hr)_Dur(hr) Phase Opr. _ Act. Plan Oper.Descr. 00:00 15:00 15.00 15.00 DRILL E 6 P Continue to BROOH f/7000'512396'(900 gpm @ 3175?1950 psi-120 rpm @ 7?3.5k ft'lbs-7.8 min/Std)-Work through a tight spot @ 5107'(2958'VD) 15:00 1630 1.50 16.50 DRILL E 7 P Circulate x4 BU reciprocating up/down(900 qpm @ 1950?1900 psi-120 rpm @ 3.572.7k ft-lbs)-Flow check 10'-Pump slug pill-Blow down TDS 16:30 17:30 1.00' 17.50 DRILL E 25 P Blow down TDS-Slip and cut 74'drilling line -17:30 20:00 2.50 20.00 DRILL E 25 P Draw works and TDS service-CIO grease zens and drum clutch 20:00 22:30 2.50" 22.50 DRILL E 4 P 'Circulate x3 BU reciprocating up/down(900 gpm @ 1900 psi-120 rpm @ 2.7k ftlbs)-POOH f/2696'1/2496'-Blow down TDS-POOH on elevators(/2496'1/287'(Top BHA) 22:30 00:00 1.50 24.00 DRILL 'E 5 P "POOH and L/D BHA#6 in progress Daily Contacts Position Contact Name Company Title E-mail Office Mobile Eni representative 'Rodney McCoy 'Eni Petroleum Sr.DrIg.Spur. • 907-685-1493 Eni representative Mirko Musumeci Eni Petroleum Ddg Spur. 907-685-1493 907-903-7269 Eni representative Bernie Leas Eni Petroleum Rig Clerk 907-670-8601 907-575-9427 Eni representative Tom Klein Eni Petroleum Material Coordinator 907-685-1491 Eni representative Mike Nelson Eni Petroleum HSE 907-685-1496 Eni representative Greg Parker Eni Petroleum Expediter 907-980-7545 Tool Push Mike Williams Nabors Alaska Drilling Tool Pusher 907-670-1492 Tool Push Mari Vanhoose Nabors Alaska Drilling Tour Pusher 907-670-1492 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(mKB) Bottom(mKB) Run n Date_ CASING 133/8 12.415 L80 0.01 737.01 1/21/2012 Last Leakoff Test Depth(mKB) TVD(mKB) Fluid Type Fluid Density(g/L) P Surf Applied(kgflcm') Eq.Mud Weight(gIL) P LeakOff(kgf/cm') 746.76 665.49 OBM 1102.4 24.6 1472.2 97.9 f� Eni E&P Division 'Well Name:0115-S4 ENI Petroleum Co.Inc. Daily Report Well Code:26195 Field Name: NIKAITCHUQ • APIIUWI:50-029-23460-00-00 2^n Date:2/7/2012 - Report#: 25 II II II page 1 of 1 Wellbore name: 0115-S4 Well Header Permit/Concession N° Operator ENI Share(%) Well Configuration type 402100 ENI PETROLEUM 100,00 HORIZONTAL Rotary Table Elevation(m) Ground Level(m) Water Depth(m) RKB-Base Flange(m) RKB-Tubing Spool(m) 16.22 3.72 11.37 Rig Information Contractor Rig Name Rig Type NABORS ALASKA NABORS 245 E 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) 0115-54 DRILLING 1/18/2012 5,848.81 1,092.64 5,864.35 185.75 31.6 20.29 Daily Information End Depth(mKB) End Depth(TVD)(... Depth Progress(m) Drilling Hours(hr) Avg ROP(rnlhr) POB Temperature(°C) Weather Wind 3,185.16 1,132.79 0.00, 91.0 -22.2 Mostly Clear WC-25` E @ 9 MPH Daily summary operation 24h Summary Complete to BOOH BHA#6-CIO rams w/9 5/8"-R/U 9 5/8"Csg running equipment-9 5/8"Csg job Operation at 07.00 Running 9 5/8"Csg @ 9,455 at report time 24h Forecast Complete to running 9 5/8"Csg-R/D Tesco tools-R/U cement head-Fill up Csg-R/U cementing equipments-9 5/8"Cement job-R/D cement equipments-Injectivity test Lithology Shows MAASP(kgflcm') Mud Weight(gIL) 1114.4 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00:00 03:00 3.00 3.00 DRILL E 5 P LID BHA#6(Bit Dull.2-2-LT-A-E-1-BT-TD)-Download MWD tools 03:00 06:00 3.00' 6.00'DRILL C 12 P Remove long wear bushing-Install test plug-C/O top rams f/4'''A"x 7"variable U 9 5/8"-Fill BOP-Test 9 5/e"top rams 250/3500 psi 10 min on chart 06:00 07:00 1.00 7.00 DRILL C 5 P Pull test plug-Install shod wear bushing-L/D running and testing tool 07:00 10:00 3.00 10.00 DRILL G 2 P R/U Tesco casing running tools-Function test equipment 10:00 19:00 9.00' 19.00 DRILL G 5 P PJSM-P/U 9 5/8"csg(400/L-80/Hydril 563/Special drift 8.75")Floating-Fill shoe track and check float equipment- RIH 115067'(1/1.5 min/Jt-Av.MUT 15k ft-Ibs) 19:00 00:00 - 5.00- 24.00 DRILL G 5 P P/U 9 5/8"csg(400/L-80/Hydril 563/Special drift 8.75")Floating-RIH rotating 65067'117460'(40750 rpm @ 2.8k?4.2k ft'lbs-HKLD 56k?52k lbs-1/1.5 min/Jt-Av.MUT 15k ft'lbs) Daily Contacts Position _ Contact Name Company Title E-mail Office Mobile • Eni representative Rodney McCoy Eni Petroleum Sr.Ddg.Spvr. -907-685-1493 Eni representative Mirko Musumeci Eni Petroleum Dig Spvr. 907-685-1493 907-903-7269 Eni representative Mitch Billington Eni Petroleum Rig Clerk 907-670-8601 Eni representative Tom Klein Eni Petroleum Material Coordinator 907-685-1491 Eni representative Mike Nelson Eni Petroleum HSE 907-685-1496 Eni representative Greg Parker Eni Petroleum Expediter 907-980-7545 Tool Push Mike Williams Nabors Alaska Drilling Tool Pusher 907-670-1492 Tool Push Matt Vanhoose Nabors Alaska Drilling Tour Pusher 907-670-1492 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(mKB) Bottom(mKB) Run Date CASING 133/8 12.415 L80 0.01 737.01 1/21/2012 Last Leakoff Test Depth(mKB) ND(mKB) Fluid Type Fluid Density(gIL) P Surf Applied(kgflcm') Eq.Mud Weight(gIL) P LeakOff(kgflcm') 746.76 665.49 OBM 1102.4 24.6 1472.2 97.9 ...* Eni E&P Division Well Name:0115-54 EN/Petroleum Co.Inc. Daily Report Well Code:26195 Field Name: NIKAITCHUQ • APIIIW I:50-029-23460-00-00 2^�I n Date:2/8/2012 - Report#: 26 II II page 1 of 1 wellbore name: 0115-S4 Well Header Permit/Concession N° Operator ENI Share(%) Well Configuration type 402100 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(m) Ground Level(m) Water Depth(m) RKB-Base Flange(m) RKB-Tubing Spool(m) 16.22 3.72 11.37 Rig Information Contractor Rig Name Rig Type NABORS ALASKA NABORS 245 E 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) 0115-S4 DRILLING 1/18/2012 5,848.81 1,092.64 5,864.35 185.75 31.6 21.29 Daily Information End Depth(mKB) End Depth(TVD)(... Depth Progress(m) Drilling Hours(hr) Avg ROP(m/hr) POB Temperature(°C) Weather Wind 3,185.16 1.132.79 0.00 89.0 -21.1 Partly Cloudy WC- SW @ 8 MPH 21' Daily summary operation 24h Summary Complete to running 9 5/8"Csg-R/D Tesco tools-R/U cement head-Fill up Csg-R/U cementing equipments-9 5/8"Cement job Operation at 07.00 WOC-Prepare to lift BOP Stack 24h Forecast Injectivity test-R/D cement equipment-Freeze protect annulus-WOC-Set 9 5/8"Csg slip and cut 9 5/8"casing 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 05:30 5.50 5.50 DRILL G 5 P P/U 9 5/8"csg(409/L-80/Hydril 563/Special drift 8.75")Floating-RIH rotating f/7460'1/10435'(50760 rpm @ 4.2k?5.6k ft-lbs-HKLD 52k?45k lbs-1/1.5 min/Jt-Av.MUT 15k ft-lbs) 05:30 08,00 2.50 8.00 DRILL G 2 P R/D Tesco tool and running equipment-M/U cement head and lines to fill 9 5/8"csg with FazePro OBM 08:00 14:00 6.00 14.00 DRILL H 19 P Fill 9 5/8"csg with FazePro OB M bleeding ajctrvugll choke_(2lt.55Is'pumped) 14:00 15:00 1.00 15.00 DRILL H 2 P Lo ,ce aetheed in7Rrtrlo plugs(witness by ENI and SLB rep)-R/U-unat,for cement job L 1500 20:00 5.00 20.00 DRILL H 7 P ontinue to R/U cement equipment-Break circulation @ 1/2 bpm and stage rare up to 8 bpm_ ._88e' • W • Condition mud for cement job(8 bpm @ 880?720 psi)YP=15 MW=9.3+ppg 20:00 00:00 4.00' 24.00 DRILL H 9 P Held PJSM-SLB pump 5 bbl Citric pill and test lines to 600/3300 psi+30 bbl Citric pill @ 9.5 ppg(5 bpm @ 540 psi)+85 � bbl Mud Push @ 10.5 ppg(5 bpm @ 470?370 psi)-Drop Bottom Plug-SLB mix and pump 196 bbl Slurry @ 12.5 ppg t [LiteCrete 707 sacks,1.57 Yield,mix fluid 5.494 gal/skj(5 bpm @ 700 psi)-Drop Top Plug-SLB pump 10 bbl water- C' Switch to Rig Pump and Displace with 775 bbl mud @ 9.3+ppg(7 bpm @ 550)[Bump plug @ 0015]-No losses during job [Shoe @ 10435'MD(3715'VD)-Collar @ 10345'] Daily Contacts =1/4_ --"`- - Position Contact Name Company `�7 ,/ d ice Mobile -Eni representative Rodney McCoy Eni Petroleum Sr.Dag.Spvr. 907-685-1493 Eni representative Mirka Musumeci Eni Petroleum Dag Spvr. 907-685-1493 907-903-7269 Eni representative Mitch Billington Eni Petroleum Rig Clerk 907-670-8601 • Eni representative Tom Klein Eni Petroleum Material Coordinator 907-685-1491 Eni representative Mike Nelson Eni Petroleum HSE 907-685-1496 Eni representative Alvin Criswell Eni Petroleum Expediter 907-980-7545 Tool Push Bruce Simonson Nabors Alaska Drilling Tool Pusher 907-670-1492 Tool Push Matt Vanhoose Nabors Alaska Drilling Tour Pusher 907-670-1492 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(mKB) Bottom(mKB) Run Date CASING 95/8 L-80 0.00 3,180.59 2/8/2012 Last Leakoff Test Depth(mKB) TVD(mKB) Fluid Type Fluid Density(gIL) P Surf Applied(kgflcm') Eq.Mud Weight(gIL) P LeakOff(kgtIcm') 746.76 665.49 OBM 1102.4 24.6 1472.2 97.9 1* Eni E&P Division I Well Name:0115-S4 ENI Petroleum Co.Inc. Daily Report Well Code:26195 Field Name:NIKAITCHUO � APIIUWI:50-029-23460-00-00 2 �I^rl Date:2/9/2012 - Report#: 27 fI I) page 1 of 1 Wellbore name: 0115-S4 Well Header PermitlConcession N' Operator ENI Share(%) Well Configuration type 402100 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(m) Ground Level(m) Water Depth(m) RKB-Base Flange(m) RKB-Tubing Spool(m) 16.22 3.72 11.37 Rig Information Contractor Rig Name Rig Type NABORS ALASKA NABORS 245 E 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) 0115-S4 DRILLING 1/18/2012 5.848.81 1,092.64 5,864.35 185.75 31.6 22.29 Daily Information End Depth(mKB) End Depth(TVD)(... Depth Progress(m) Drilling Hours(hr) Avg ROP(m/hr) POB Temperature('C) Weather Wind 3.185.16 1,132.79 0.00 87.0 -20.6 Mostly Cloudy WC- ESE @ 3 MPH 5' Daily summary operation 24h Summary Injectivity test-R/D cement equipment-WOC-N/D BOP Stack-Set 9 5/8"Csg slip and cut 9/8"Csg-N/U BOP Stack-CIO rams-TIH 5"DPs Std Operation at 07.00 POOH w/5"DPs installing E CD subs 24h Forecast TIH 5`DPs Std-Freeze protect annulus-POOH installing E CD subs-P/U and M/U in Std 4 W DPs-BOP test 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 01:00 1.00 1.00 DRILL H 9 P W.O.C.-Pressure up casing to 1000 psi(500 psi over FCP)-Release pressure and check float equipment-Perform 20 bbl injectivity test down 13 3/8"x 9 5/8"annulus(1.5 bpm @ max pressure 520 psi)-Bled back 2 bbls 01:00 09:00 8.00 9.00 DRILL C 5 P W.O.C.-R/D running casing equipment-RIH x1 Std 5"DP and displace 9 5/8"casing-Blow down lines-R/D Katch Kan- L/D mouse hole-Hookup lifting cylinders and secondary slings-Prepare to lift BOP Stack 09:00 14:00 5.00 14.00 DRILL C 5 P Raise BOP stack and Multi Bowl-Pull 9 5/8"csg to 153k lbs-Set emergency slips(100k lbs on slip)-R/U casing tagger- Cut csg and L/D-Dress stump-Pull wear ring-Install pack off-Test pack off @ 2470 psi 10 min 14:00 18:30 4.50 18.50 DRILL C 5 P N/U BOP Stack and Multi Bowl-Install flow line-Hook up Kill and Choke lines-Install Katch Kan pollution pan 18:30 20:00 1.50 20.00'DRILL C 5 P C/O Top rams from 9 5/8"fixed to 4%"x 7"variable-Function test-Install wear nng ID=9 1/8"-L/D running tool 7,-- 20:00 00:00 4.00- 24.00 DRILL E 4 P MN5"mile shoe and TIH 515605' Daily Contacts Position Contact Name Company Title E-mail Office Mobile Eni representative Rodney McCoy Em Petroleum -Sr.DrIg.Spur. 907-685-1493 Eni representative Mirko Musumeci Em Petroleum DrIg Spvr. 907-685-1493 907-903-7269 Eni representative Mitch Billington Eni Petroleum Rig Clerk 907-670-8601 Eni representative Tom Klein Eni Petroleum Material Coordinator 907-685-1491 Eni representative Mike Nelson Eni Petroleum HSE 907-685-1496 Eni representative Alvin Caswell Eni Petroleum Expediter 907-980-7545 Tool Push Bruce Simonson Nabors Alaska Drilling Tool Pusher 907-670-1492 Tool Push Matt Vanhoose Nabors Alaska Dulling Tour Pusher 907-670-1492 Last Casing seat Can.Type OD(in) ID(in) Grade Top(mKB) Bottom(mKB) Run Date CASING 9 5/8 L-80 0.00 3.180.59 2/8/2012 Last Leakoff Test Depth(mKB) ND(mKB) Fluid Type Fluid Density(gIL) P Surf Applied(kgf/cm') Eq.Mud Weight(gIL) P LeakOff(kgflcm') 746.76 665.49 OBM 1102.4 24.6 1472.2 97.9 If* Eni E&P Division (Well Name:0115-S4 ENI Petroleum Co.Inc. Daily Report Well Code:26195 Field Name:NIKAITCHUO • API/UWI:50-029-23460-00-00 2^ Date:2/10/2012 - Report#: 28 II IIpage 1 of 1 wellbore name: 0115-S4 Well Header PermitlConcession N' Operator ENI Share(%) Well Configuration type 402100 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(m) Ground Level(m) Water Depth(m) RKB-Base Flange(m) RKB-Tubing Spool(m) 16.22 3.72 11.37 Rig Information Contractor Rig Name Rig Type NABORS ALASKA NABORS 245 E 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) 0115-S4 DRILLING 1/18/2012 5.848.81 1.092.64 5,864.35 165.75 31.6 23.29 Daily Information End Depth(mKB) End Depth(TVD)(... Depth Progress(m) Drilling Hours(hr) Avg ROP(mlhr) POB Temperature('C) Weather Wind 3,185.16 1,132.79 0.00 88.0 -12.2 Light Snow WC 1" NNW @ 6 MPH Daily summary operation 24h Summary TIH 5"DPs Old-Freeze protect annulus-POOH installing E CD subs-P/U and M/U in Std 4 W DPs Operation at 07.00 POOH 4WDPs in Std 24h Forecast Continue to M/U 4'/"DPs in Std-BOP test-P/U and M/U BHA#7-RIH w14 W DPs recording sonic log 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 Continue TIH w/5"DPs f/5605'1/10246' 03.30 15:00 11.50 15.00 DRILL E 5 P TOOH w/5"DPs installing E CD subs[91 Std 5"DPs w/E CD subs-15 Std 5"DPsJ-Freeze protect well w/165 bbls diesel (1.9?1.5 bpm @ 550?1250 psi) 15.00 15:30 0.50 15.50 DRILL E 5 P C/O Elevators and slips 1530 00:00 8.50 24.00 DRILL E 5 P M/U 5"mule shoe+XO and TIH picking up Jt 4 W DPs 1/6080' Daily Contacts Position Contact Name Company Title E-mail Office Mobile Eni representative Rodney McCoy Eni Petroleum Sr.DrIg.Spvr. '907-685-1493 Eni representative Mirko Musumeci Eni Petroleum Drlg Spvr. 907-685-1493 907-903-7269 Eni representative Mitch Billington Eni Petroleum Rig Clerk 907-670-8601 Eni representative Tom Klein Eni Petroleum Material Coordinator 907-685-1491 Eni representative Mike Nelson Eni Petroleum HSE 907-685-1496 Eni representative Alvin Criswell Eni Petroleum Expediter 907-980-7545 Tool Push Bruce Simonson Nabors Alaska Drilling Tool Pusher 907-670-1492 Tool Push Man Vanhoose Nabors Alaska Drilling Tour Pusher 907-670-1492 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(mKB) Bottom(mKB) Run Date CASING 95/6 L-80 0.00 3,180.59 2/8/2012 Last Leakoff Test Depth(mKB) TVD(mKB) Fluid Type Fluid Density(gIL) P Surf Applied(kgflcm') Eq.Mud Weight(gIL) P LeakOff(kgflcm') 746.76 665.49 08M 1102.4 24.6 1472.2 97.9 Eni E&P Division I Well Name:0115-S4 ENI Petroleum Co.Inc. Daily Report Well Code:26195 Field Name: NIKAITCHUO r91* � APIIUWI:50-029-23460-00-00 2^ Date:2/11/2012 - Report#: 29 II II page 1 of 1 Wellbore name. 0115-S4 Well Header Permit/Concession N° Operator ENI Share(e) Well Configuration type 402100 ENI PETROLEUM 100,00 HORIZONTAL Rotary Table Elevation(m) Ground Level(m) Water Depth(m) RKB-Base Flange(m) RKB-Tubing Spool(m) 16.22 3.72 11.37 Rig Information Contractor Rig Name Rig Type NABORS ALASKA NABORS 245 E 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) 0115-S4 DRILLING 1/18/2012 5,848.81 1,092.64 5,664.35 185.75 31.6 24.29 Daily Information End Depth(mKB) End Depth(TVD)(... Depth Progress(m) Drilling Hours(hr) Avg ROP(m/hr) POB Temperature('C) Weather Wind 3,185.16 1 132.79 0.00 88.0 -17.2 Light Snow WC-13` NE @ 8 MPH Daily summary operation 24h Summary Complete to M/U 4 W DPs in Std-BOP test-P/U and M/U BHA#7 Operation at 07.00 P/U and M/U BHA#7 24h Forecast Complete to P/U and M/U BHA#7-RIH BHA#7 w/4'G°DPs recording sonic log 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 05:00 5.00 5.00 DRILL E 5 P -TIH picking up Jt 4'''A"DPs 1/6080'68808' 05:00 09:30 4.50 9.50 DRILL E '5 -P POOH w/4 W DPs[93 Stds]-B/O Mule shoe and XO 09:30 10:30 1.00 10.50 DRILL E 25 P CIO saver sub on TDS 10:30 12:00 1.50 12.00 DRILL C ‘5 P Pull wear ring-Set test plug-Fill Stack and lines w/water-Purge air out of system-R/U BOP test equipment 12:00 14:30 2.50 14.50 DRILL C 25 TRO5 Body test BOP and lines 3500 psi-Found leak on choke line and ram door-CIO API ring on choke line and tightened ram door 14:30 20:30 6.00 20.50 DRILL C 12 P Test BOP as per AOGCC requirements wl 5'and 4%"test Jt-Annular @ 25072500 psi-Rams,choke manifold.floor and top drive valves @ 250?3500 psi-Chart record-BOP test witness by AOGCC rep.John Crisp 20:30 21:30 1.00 21.50 DRILL C '5 .P Pull test plug-Set wear ring ID=91/8" 21:30 22:30 1.00 22.50 DRILL E '12 'P P/U E CD hose-Pressure test E CD manifold 5k psi 22:30 23:00 0.50 23.00 DRILL E 2 P R/D BOP test equipment-Blow down Stand pipe and E CD manifold 23:00 00:00 1,00 24.00 DRILL E 5 P R/U Handling equipment-Held PJSM-P/U,M/U and RIH BHA#7[Bit 8 V."Hycalog SKH616M TFA..902(s/n E150506)+ Xceed675 w/float+Periscope 675+Telescope 675+NM Stab+LWD sonicVISION+AND 675+NM Stab+x3 NM Flex DC+Float Sub+6 W Jar(s/n 1416-1573)+02 5"H WDP+XO)-In progress Daily Contacts Position Contact Name Company Title E-mail Office Mobile • Eni representative Rodney McCoy Eni Petroleum Sr.Drig.Spvr. 907-685-1493 Eni representative Mirk,Musumeci Eni Petroleum Drlg Spvr. 907-685-1493 907-903-7269 Eni representative Mitch Billington Eni Petroleum Rig Clerk 907-670-8601 Eni representative Tom Klein Eni Petroleum Material Coordinator 907-685-1491 Eni representative Mike Nelson Eni Petroleum HSE 907-685-1496 Eni representative Alvin Criswell Eni Petroleum Expediter 907-980-7545 Tool Push Bruce Simonson Nabors Alaska Drilling Tool Pusher 907-670-1492 Tool Push Matt Vanhoose Nabors Alaska Drilling Tour Pusher 907-670-1492 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(mKB) Bottom(mKB) Run Date CASING 95/8 L-80 0.00 3,180.59 2/8/2012 Last Leakoff Test Depth(mKB) TVD(mKB) Fluid Type Fluid Density(gIL) P Surf Applied(kgf/cm') Eq.Mud Weight(gIL) P LeakOff(kgflcm'( 746.76 665.49 OBM 1102.4 24.6 1472.2 97.9 Eni E&P Division I Well Name:0115-S4 ENI Petroleum Co.Inc. Daily Report Well Code:26195 Field Name: NIKAITCHUO 0111#1 • APIIUWI:50-029-23460-00-00 2 II^n Date:2/12/2012 - Report#: 30 II II page 1 of 1 Wellbore name: 0115-S4 Well Header Permit/Concession N° Operator ENI Share(%) Well Configuration type 402100 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(m) Ground Level(m) Water Depth(m) RKB-Base Flange(m) RKB-Tubing Spool(m) 16.22 3.72 11.37 Rig Information Contractor Rig Name Rig Type NABORS ALASKA NABORS 245E 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) 0l15-S4 DRILLING 1/18/2012 5,848.81 1,092.64 5,864.35 185.75 31.6 25.29 Daily Information End Depth(mKB) End Depth(TVD)(... Depth Progress(m) Drilling Hours(hr) Avg ROP(m/hr) POB Temperature(°C) Weather Wind 3.185.16 1,132.79 0.00 89.0 -18.3 Cloudy WC-18` ENE @ 12 MPH Daily summary operation 24h Summary Complete to P/U and M/U BHA#7 RIH BHA#7 w/4'''A"DPs recording sonic log Operation at 07.00 Displace well to new FazePro OBM 24h Forecast 9 5/8'Csg test-Displace w/new FazePro-Slip and cut DL-Drill out cmt,plugs and float equipment-LOT-Drill ahead 8'/."section as per wellplan 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 05:00 5.00 5.00 DRILL E 5 P Continue to P/U,WU and RIH BHA#7[Bit 8"A"Hycalog SKH616M TFA:.902(s/n E150506)+Xceed675 w/float+ Periscope 675+Telescope 675+NM Stab+LWD sonicVISION+AND 675+NM Stab+x3 NM Flex DC+Float Sub+6 % Jar(s/n 1416-1573)+x25"HWDP+XO)-Fill pipe-Shallow test 05:00 06:30 1.50 6.50 DRILL E 4 P RIH BHA#7 1/2400'w14 W DPs-Fill pipe and shallow test 06:30 21:00 14.50 21.00 DRILL E 11 P Continue RIH BHA#7(/2400'V9164'w/4%"DP recording CBL log @ 800 fph-Fill pipe every 2000' 21.00 00:00 3.00 24.00 DRILL E 11 P C/O elevator and slip f/4 W 85"-P/U and M/U XO-Continue to RIH BHA#7(/9164'V10363'(Tag cmt)w/5"DP recording CBL log @ 800 fph-Fill pipe every 2000' Daily Contacts Position _ Contact Name Company -Sr. Title E-mail Office Mobile Eni representative Rodney McCoy -Eni Petroleum Dig.Spvr. 907-685-1493 - Eni representative Mirko Musumeci Eni Petroleum Ddg Spvr. 907-685-1493 907-903-7269 Eni representative Mitch Billington Eni Petroleum Rig Clerk 907-670-8601 Eni representative Tom Klein Eni Petroleum Material Coordinator 907-685-1491 Eni representative Mike Nelson Eni Petroleum HSE 907-685-1496 Eni representative Alvin Criswell Eni Petroleum Expediter 907-980-7545 Tool Push Bruce Simonson Nabors Alaska Dolling Tool Pusher 907-670-1492 Tool Push Matt Vanhoose Nabors Alaska Drilling Tour Pusher 907-670-1492 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(mKB) Bottom(mKB) Run Date CASING 95/8 L-80 0.00 3,180.59 2/8/2012 Last Leakoff Test Depth(mKB) TVD(mKB) Fluid Type Fluid Density(gIL) P Surf Applied(kgflcm°) Eq.Mud Weight(g/L) P LeakOff(kgflcm') 746.76 665.49 OBM 1102.4 24.6 1472.2 97.9 fift* Eni E&P Division } 'Well Name:0115-S4 ENI Petroleum Co.Inc. Daily Re M O 1.. Well Code:26195 Field Name: NIKAITCHUC aAPIIUWI:50-029-23460-00-00 2 If II�, Date:2/13/2012 - Report#: 31 page 1 of 1 Wellbore name: 0115-S4 Well Header Permit/Concession N° Operator ENI Share)%) Well Configuration type 402100 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(m) Ground Level(m) Water Depth(m) RKB-Base Flange(m) RKB-Tubing Spool(m) 16.22 3.72 11.37 Rig Information Contractor Rig Name Rig Type NABORS ALASKA NABORS 245 E 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) 0115-04 DRILLING 1/18/2012 5.848.81 1,092.64 5,864.35 185.75 31.6 26.29 Daily Information End Depth(mKB) End Depth(TVD)(... Depth Progress(m) Drilling Hours(hr) Avg ROP(m/hr) POB Temperature(°C) Weather Wind 3,400.04 1,148.06 214.88 5.29 40.6 90.0 -17.2 Cloudy WC-20" NE©18 MPH Daily summary operation 24h Summary 9 5/8`casing pressure test-Displace new FazePro 9.2-Slip and Cut DL-Drill out plugs,cement and 20'new formation-LOT-Drill ahead 8 3"section 1111157' Operation at 07.00 Dulling ahead,@ 11.491'@ report time 24h Forecast Drill ahead 8'/"section as per wellplan Lithology Shows MAASP(kgflcm') Mud Weight(gIL) 1108.4 Time Log Start End Cum Time Time Dur(hr) Our(hr) Phase Opr. Act. Plan Oper.Descr. 00:00 01:30 1.50 1.50-DRILL G 11 P Circulate BU(500 gpm @ 3200 psi)-Pressure test 9 5/8"Csg @ 3000 psi for 30 min(chart record) 01:30 05:30 4.00 5.50 DRILL E 7 P PJSM-Empty active pits-Displace well to new FazePro 9.2 ppg OBM pumping 30 bbl LVT spacer+727 bbl FazePro(400 gpm @ 950 psi,35 pm @ 6k Ribs)-Clean shakers and trough pits 05:30 08:30 3.00 8.50 DRILL E 25 P Slip and cut 59'drilling line-Service Draw works and TDS-Calibrate block height-Set and check crown-o-matic 08:30 11:30 3.00 11.50'DRILL E 14 P Drill out plugs,float equipment,shoe and cement 1110363'810450'(450 gpm @ 2200 psi,60 rpm @ 5+7k 9-lbs,WOB= 5+6k lbs,MW=9.2 ppg)-Continue with same pattern 810470'(8%"new hole) 11:30 12:30 1.00 12.50 DRILL E 7 P POOH into shoe-Circulate BU MW 9.2 ppg in/out(520 gpm @ 2720 psi) 12:30 14:30 2.00 14.50 DRILL E 11 P Rig up lines and perform LOT with 9.2+ppg FazePro OBM-EMW=12.6 ppg(First attempt failed,possible surface leak- Reconfigured test manifold and repeat good test)-R/D testing equipment 14:30 18:00 3.50 18.00 DRILL E 3 P Drilling Rotary Steerable 0 8'/."section(/10470'810637'\500 gpm @ 2650 psi\80+120 rpm @ 7.5+8.36 ft-lbs\WOB= 3+10k lb\Up wt=134k lb-Dn wt=82k lbs-Rot wt=100k lb I Mud wt=9.2 ppg-Take survey as needed-Ream and wash 15'every connection-Controlled maximum ROP @ 250 fph building curve 18.00 00:00 6.00 24.00'DRILL E 3 P Drilling Rotary Steerable 0 8'/."section 1/10637'1/11157'1500 gpm @ 2650 psi 180+120 rpm @ 8.12k fobs I WOB= 3+10k lb I Up wt=150k lb-Dn wt=60k lbs-Rot w1=100k lb\Mud wt=9.2 ppg-Take survey as needed-Ream and wash 15'every connection-Controlled maximum ROP @ 250 fph building curve Daily ADT=4.92 hrs [ADT=4.92-JAR=5.3 hrsl Daily Contacts Position Contact Name Company Title E-mail Office Mobile • Eni representative Rodney McCoy Eni Petroleum Sr.Ddg.Spur. 907-685-1493 Eni representative Mirko Musumeci Eni Petroleum Ddg Spur. 907-685-1493 907-903-7269 Eni representative Mitch Billington Eni Petroleum Rig Clerk 907-670-8601 Eni representative Tom Klein Eni Petroleum Material Coordinator 907-685-1491 Eni representative Mike Nelson Eni Petroleum HSE 907-685-1496 Ell representative Alvin Criswell Eni Petroleum Expediter 907-980-7545 Tool Push Bruce Simonson Nabors Alaska Dulling Tool Pusher 907-670-1492 Tool Push Mari Vanhoose Nabors Alaska Drilling Tour Pusher 907-670-1492 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(mKB) Bottom(mKB) Run Date CASING 95/8 L-80 0.00 3,180.59 2/8/2012 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') 3.191.26 1,133.29 OBM 1102.4 45.7 1505.7 170.6 Eni E&P Division I Well Name:0115-S4 Olt* ENI Petroleum Co.Inc. Daily Report Well Code:26195 Field Name:NIKAITCHUO • APIIUWI:50-029-23460-00-00 2^rl Date:2/14/2012 - Report#: 32 I� II II page 1 of 1 Wellbore name: 0115-S4 Well Header Permit/Concession N° Operator ENI Share(%) Well Configuration type 402100 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(m) Ground Level(m) Water Depth(m) RKB-Base Flange(m) RKB-Tubing Spool(m) 16.22 3,72 11.37 Rig Information Contractor Rig Name Rig Type NABORS ALASKA NABORS 245E 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) 0115-S4 DRILLING 1/18/2012 5,848.81 1,092.64 5,864,35 185.75 31.6 27.29 Daily Information End Depth(mKB) End Depth(TVD)(... Depth Progress(m) Drilling Hours(hr) Avg ROP(mlhr) POB Temperature(°C) Weather Wind 3,952.95 1,141.45 552.91 13.82 40.0 88.0 -22.2 Mostly Cloudy WC- Calm 22" Daily summary operation 24h Summary Drill ahead 8 G°section 1/11157'1/12964' Operation at 07.00 Drill ahead 8%'section as per wellplan @ 13,361 at report time 24h Forecast Drill ahead 8''section to planned TD 19190' Lithology Shows MAASP(kgflcm') Mud Weight(g/L) 1108.4 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 Drilling Rotary Steerable 0 8"section(/11157'511787'\500?550 gpm @ 2650?3230 psi\80+120 rpm @ 9.11k ft-lbs\ WOB=2+14k lb\ECD=10.41 ppg\Up wt=148k lb-NO S/O-Rot wt=100k lb\Mud wt=9.2 ppg-Take survey as needed -Ream and wash one JI every connection 06.00 12.00 6.00' 12.00 DRILL 'E '3 'P Drilling Rotary Steerable 0 8'%"section 1/11787'012174'\550 gym @ 3230?3260 psi\80+120 rpm @ 10+12k ft-lbs\ WOB=2+12k lb\ECD=10.41?10.65 ppg\Up wt=143k lb-NO 8/0-Rot wt=100k lb\Mud wt=9.2 ppg-Take survey as needed-Ream and wash one Jt every connection 1200 18.00 6.00 18.00 DRILL E 3 P Dulling Rotary Steerable 0 8%"section 1/12174'U12479'\550 gpm @ 3260?3340 psi\80+120 rpm @ 9=12k ft-lbs\ WOB=3+12k lb\ECD=10.65710.91 ppg\Up wt=145k lb-NO S/O-Rot wt=103k lb\Mud wt=9.2+ppg-Take survey as needed-Ream and wash one JI every connection NOTE:DLS 9.11"@ 12215' 18:00 00:00 6.00 24.00'DRILL E 3 'P 'Drilling Rotary Steerable 0 8%"section U12174'1/12964'\550 gpm @ 334073480 psi\60+120 rpm @ 11+13k Ribs\ WOB=4+10k lb\ECD=10.65?10.14 ppg\Up w1=145k lb-NO 8/0-Rot wt=103k lb\Mud wt=9.2+ppg-Take survey as needed-Ream and wash one Jt every connection Daily ADT=13.36 hrs [ADT=18.28-JAR=18.66 hrs) Daily Contacts Position Contact Name Company Title E-mail Office Mobile Eni representative Rodney McCoy 'Eni Petroleum Sr.Ddg.Spvr. '907-685-1493 Eni representative Mirka Musumeci Eni Petroleum Ddg Spvr, 907-685-1493 907-903-7269 Eni representative Mitch Billington Eni Petroleum Rig Clerk 907-670-8601 Eni representative Sach Bowe Eni Petroleum Materal Coordinator 907-685-1491 907-299-0531 Eni representative Mike Nelson Eni Petroleum HSE 907-685-1496 Eni representative Alvin Criswell Eni Petroleum Expediter 907-980-7545 Tool Push Bruce Simonson Nabors Alaska Drilling Tool Pusher 907-670-1492 Tool Push Matt Vanhoose Nabors Alaska Drilling Tour Pusher 907-670-1492 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(mKB) Bottom(mKB) Run Date CASING 9 5/8 L-80 0.00 3.180.59 2/8/2012 Last Leakoff Test Depth(mKB) ND(mKB) Fluid Type Fluid Density(gIL) P Surf Applied(kgflcm') Eq.Mud Weight(g/L) P LeakOff(kgf/cm') 3;191.26 1,133.29 OBM 1102.4 45.7 1505.7 170.6 14 Eni E&P Division `Well Name:0115-04 ENI Petroleum Co.Inc. Daily Report Well Code:26195 Field Name:NIKAITCHUO Date:2/15/2012 - Report#: 33 APIIUWI:50-029-23460-00-00 a i ii page 1 of 1 Wellbore name: 0115-S4 Well Header PermiVConcession N° Operator ENI Share(%) Well Configuration type 402100 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(m) Ground Level(m) Water Depth(m) RKB-Base Flange(m) RKB-Tubing Spool(m) 16.22 3.72 11.37 Rig Information Contractor Rig Name Rig Type NABORS ALASKA NABORS 245E 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) 0115-04 DRILLING 1/18/2012 5.848.81 1.092.64 5.864.35 185.75 31.6 28.29 Daily Information End Depth(mKB) End Depth(TVD)(... Depth Progress(m) Drilling Hours(hr) Avg ROP(m/hr) POB Temperature(°C) Weather Wind 4,514.09, 1,136.63 561.14 12.05 46.6 86.0 -17.2 Cloudy WC-12` NE @ 8 MPH Daily summary operation 24h Summary Drill ahead 8 W section 1/12964'8/14836' Operation at 07.00 Drill ahead 8%"section as per wellplan @ 15,231'at report time. 24h Forecast Drill ahead 8%"section to planned TD 19190' Lithology Shows MAASP(kgflcm') Mud Weight(gIL) 1108.4 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 0000 06.00 6.00 6.00 DRILL E 3 P Drilling Rotary Steerable 0 8%"section(/12964'V13650'\550 gpm @ 3480?3610 psi\120 rpm @ 11.12k Ribs\WOB= ' 2.13k lb\ECD=10.14711.16 ppg\Up wt=160k lb-NO 8/0-Rot wt=100k Ib\Mud wt=9.2+ppg-Take survey as needed-Ream and wash one Jt every connection 06.00 12:00 6.00 12.00 DRILL E 3 P Drilling Rotary Steerable 0 8%"section 1/13650'1114160'1 550 gpm @ 3610?3680 psi\80+120 rpm @ 11.15k Ribs\ WOB=2.13k lb\ECD=11.16?11.20 ppg I Up wt=170k lb-NO S/O-Rot wt=100k lb\Mud wt=9.2+ppg-Take survey as needed-Ream and wash one Jt every connection 12:00 18:00 6.00 18.00 DRILL E 3 P Drilling Rotary Steerable 0 8%"section(/14160'8/14521'\550?500 gpm @ 368013200 psi\80.120 rpm @ 12.156 Ribs\ WOB=4.16k Ib\ECD=11.20711.14 ppg\Up wt=175k lb-NO 5/0-Rot wt=100k lb\Mud wt=9.2+ppg-Take survey as needed-Ream and wash one Jt every connection NOTES: -From 14160'start to loss mud(60 bph),reduced flow rate to 500 gpm and pumped 30+50 bbl SafeCarb pills(30/50). 18:00 0000 6.00 24.00 DRILL E 3 P Drilling Rotary Steerable 0 8%"section(/14521'V14836'1500 gpm @ 3200 psi\60+120 rpm @ 14.16k Ribs\WOB= 2+16k lb\ECD=11.14711.43 ppg\Up wt=175k lb-NO 5/0-Rot wt=105k lb\Mud wt=9.2+ppg-Take survey as needed-Ream and wash one Jt every connection NOTES. -Average mud losses 7-10 bph going down -Operation slowed due to directional tools unable to get down-link while drilling Daily ADT=12.51 hrs [ADT=30.79-JAR=31.17 hrs] Daily mud loss 240 bbl Daily Contacts Position Contact Name Company Title E-mail Office Mobile Eni representative Rodney McCoy Eni Petroleum Sr.Ddg.Spvr. 907-685-1493 Eni representative Mirko Musurneci Eni Petroleum Drdg Spvr. 907-685-1493 907-903-7269 Eni representative Mitch Billington Eni Petroleum Rig Clerk 907-670-8601 Eni representative Sach Bowe Eni Petroleum Materal Coordinator 907-685-1491 907-299-0531 Eni representative Mike Nelson Eni Petroleum HSE 907-685-1496 Eni representative Alvin Criswell Eni Petroleum Expediter 907-980-7545 Tool Push Bruce Simonson Nabors Alaska Drilling Tool Pusher 907-670-1492 Tool Push Matti Turcotte Nabors Alaska Drilling Tour Pusher 907-670-1492 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(mKB) Bottom(mKB) Run Date CASING 9 5/8 L-80 0.00 3.180.59 2/8/2012 Last Leakoff Test Depth(mKB) TVD(mKB) Fluid Type Fluid Density(gIL) P Surf Applied(kgflcm') Eq.Mud Weight(gIL) P LeakOff(kgflcm') 3.191.26 1,133.29 OBM 1102.4 45.7 1505.7 170.6 0141. En/E&P Division /Well Name:0115-S4 I ENI Petroleum Co.Inc. Daily Report Well Code:26195 Field Name:NIKAITCHUO • APIIUWI:50-029-23460-00-00 enII Date:2/16/2012 - Report#: 34 " �)n page 1 of 1 Wellbore name: 0115-S4 Well Header Permit/Concession N° Operator ENI Share(%) Well Configuration type 402100 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(m) Ground Level(m) Water Depth(m) RKB-Base Flange(m) RKB-Tubing Spool(m) 16.22 3.72 11.37 Rig Information Contractor Rig Name Rig Type ' NABORS ALASKA NABORS 245E 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) 0115-04 DRILLING 1/18/2012 5,848.81 1,092.64 5,864.35 185.75 31.6 29.29 Daily Information End Depth(mKB) End Depth(TVD)(... Depth Progress(m) Drilling Hours(hr) Avg ROP(m/hr) POB Temperature(°C) Weather Wind 5,032.25 1,121.48 518.16 14.30 36.2 90.0 -22.8 Mostly Cloudy WC- Calm 9° Daily summary operation 24h Summary Drill ahead 8'A"section U14836'1/16505' Operation at 07.00 Drill ahead 8%"section as per wellplan @ 16731' 24h Forecast Drill ahead 8%"section to planned TD 19190' Lithology Shows MAASP(kgf/cm') Mud Weight(gIL) 1108.4 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 Drilling Rotary Steerable 0 8'A"section(/14836'515429'\500?475 gpm @ 3200?3030 psi\80+120 rpm @ 14+16k Nibs\ WOB=2+14k lb\ECD=11.43?11.58 ppg\Up wt=153k lb-NO S/O-Rot wt=100k lb\Mud wt=9.2+ppg-Take survey as needed-Ream and wash one Jt every connection 06:00 12:00 6.00 12.00 DRILL E 3 P Drilling Rotary Steerable 0 8'A"section 1/15429'1/15865'\475 gpm @ 3030?3070 psi\80+120 rpm @ 13+16k f51bs\ WOB=2+14k Ib\ECD=11.58?11.21 ppg\Up wt=170k lb-NO S/O-Rot wt=100k lb\Mud wt=9.3 ppg-Take survey as needed-Ream and wash one Jt every connection 12:00 18:00 6.00 18.00 DRILL E 3 P Drilling Rotary Steerable 0 8'A"section f/15865'1/16210'\475 gpm @ 3070 psi\80+120 rpm @ 13+17k ft-lbs\WOB= 3+14k lb\ECD=11.21?11.11 ppg\Up wt=165k lb-NO S/O-Rot wt=105k lb\Mud wt=9.2+ppg-Take survey as needed-Ream and wash one Jt every connection 18:00 00:00 6.00 24.00 DRILL E 3 P Drilling Rotary Steerable 0 8'A"section(/16210'516505'\475?450 gpm @ 3070?2830 psi\80+120 rpm @ 14+17k ft.lbs\ WOB=5+17k lb\ECD=11.11?11.19 ppg\Up wt=165k lb-NO S/O-Rot wt=105k lb\Mud wt=9.2 ppg-Take survey as needed-Ream and wash one Jt every connection Daily ADT=15.84 hrs [ADT=46.63-JAR=47.01 hrs] Daily mud loss 585 bbl NOTES' Crossed planned faults @ 15472'and 16345'MD where losses were increased until 50 bph-Pumped SafeCarb pills (30/50)in order to minimize losses.[SafeCarb 20/40 already in the mud system] Daily Contacts Position Contact Name Company Title E-mail Office Mobile Eni representative Rodney McCoy Eni Petroleum Sr.DrIg.Spvr. 907-685-1493 - Eni representative Mirko Musumeci Eni Petroleum Drip Spvr. 907-685-1493 907-903-7269 Eni representative Mitch Billington Eni Petroleum Rig Clerk 907-670-8601 Eni representative Sach Bowe Eni Petroleum Materal Coordinator 907-685-1491 907-299-0531 Eni representative Mike Nelson Eni Petroleum HSE 907-685-1496 Eni representative Alvin Criswell Eni Petroleum Expediter 907-980-7545 Tool Push Bruce Simonson Nabors Alaska Drilling Tool Pusher 907-670-1492 Tool Push Matti Turcotte Nabors Alaska Drilling Tour Pusher • 907-670-1492 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(mKB) Bottom(mKB) Run Date CASING 95/8 L-80 0.00 3,180.59 2/8/2012 Last Leakoff Test _ Depth(mKB) TVD(mKB) Fluid Type Fluid Density(gIL) P Surf Applied(kgflcm') Eq.Mud Weight(gIL) P LeakOff(kgflcm') 3,191.26 1,133.29 OBM 1102.4 45.7 1505.7 170.6 iill* Eni E&P Division (Well Name:0115-S4 ENI Petroleum Co.Inc. Daily Report Well Code:26195 Field Name: NIKAITCHUO • API/UWI:50-029-23460-00-00 2�,r, Date:2/17/2012 - Report#: 35 II II II page 1 of 1 Wellbore name: 0115-S4 Well Header Permit/Concession N° Operator ENI Share(%) Well Configuration type 402100 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(m) Ground Level(m) Water Depth(m) RKB-Base Flange(m) RKB-Tubing Spool(m) 16.22 3.72 11.37 Rig Information Contractor Rig Name Rig Type NABORS ALASKA NABORS 245 E 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) 0115-04 DRILLING 1/18/2012 5,848.81 1.092.64 5,864.35 185.75 31.6 30.29 Daily Information End Depth(mKB) End Depth(TVD)(... Depth Progress(m) Drilling Hours(hr) Avg ROP(m/hr) POB Temperature(°C) Weather Wind 5,412.03 1,117.34 379.78 8.77 43.3 91.0 -21.1 Cloudy WC-25° •NE @ 12 MPH Daily summary operation 24h Summary Drill ahead 8 W section(/16505'1117791' Operation at 07.00 Trouble work on TDS to fix power cable broken(Circulation 300 gpm @ 1560 psi-No losses-TDS unable to rotate)-Actual depth 17889' 24h Forecast Drill ahead 8 W section to planned TD 19190' Lithology Shows MAASP(kgf/cm') Mud Weight(gIL) 1114,4 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 E 3 P Drilling Rotary Steerable 0 8%"section(/16505'1117029'1450 gpm @ 2830?2870 psi\80+120 rpm @ 14+16k ft-lbs 1 WOB=3+14k lb\ECD=11.19?11.3 ppg\Up wt=158k lb-NO S/O-Rot wt=103k lb\Mud wt=9.2 ppg-Take survey as needed-Ream and wash one Jt every connection 08:00 11:00 3.00' 11.00 DRILL E 7 P P/U off bottom and reduced flow rate-Circulate rotating and reciprocating(280 gpm @ 1375 psi-60 rpm @ 10.5k ft]lbs)- Download new FazePro from truck 11:00 18:00 7.00 18.00 DRILL E 3 P Drilling Rotary Steerable 0 8 3/4"section(/17029'1117495'\450 gpm @ 2870 psi\80+120 rpm @ 16*17k fobs\WOB= 2+10k lb\ECD=11.3?11.36 ppg\Up wt=160k lb-NO S/O-Rot wt=103k lb\Mud wt=9.3 ppg-Take survey as needed- Ream and wash one Jt every connection NOTES. -Crossed unplanned faults @ 17268'drilled 185'out of target boundary -Pumped SafeCarb pills(30/50)in order to minimize losses 18:00 00.00 6,00 24,00 DRILL E 3 P Dolling Rotary Steerable 0 8'/°"section(/17495'017791'\450 gpm @ 2870?2960 psi\60+120 rpm @ 15+17k fblbs\ WOB=2+10k lb\ECD=11.36?11.41 ppg\Up wt=170k lb-NO S/O-Rot wt=105k lb\Mud wt=9.3 ppg-Take survey as needed-Ream and wash one Jt every connection Daily ADT=8.91 hrs [ADT=55.54-JAR=55.92 hrs] Daily mud loss 885 bbl NOTES -Operation slowed due to directional tools unable to get down-link while drilling -Average losses while drilling 50 bph Daily Contacts Position Contact Name Company Title Email Office Mobile Eni representative Ben Perry Eni Petroleum Sr.Ddg.Spv, 907-685-1493 Eni representative Mirka Musumeci Em Petroleum Drig Spvr. 907-685-1493 907-903-7269 Eni representative Mitch Billington Em Petroleum Rig Clerk 907-670-8601 Eni representative Sach Bowe Eni Petroleum Materal Coordinator 907-685-1491 907-299-0531 Eni representative Mike Nelson Em Petroleum HSE 907-685-1496 Eni representative Alvin Criswell Eni Petroleum Expediter 907-980-7545 Tool Push Bruce Simonson Nabors Alaska Drilling Tool Pusher 907-670-1492 Tool Push Mattt Turcotte Nabors Alaska Drilling Tour Pusher 907-670-1492 - Last Casing seat _ Cas.Type OD(in) ID(in) _ Grade Top(mKB) Bottom(mKB) Run Date CASING 9 5/8 L-80 0.00 3,180.59 2/8/2012 Last Leakoff Test Depth(mKB) TVD(mKB) Fluid Type Fluid Density(gIL) P Surf Applied(kgf/cm') Eq.Mud Weight(gIL) P LeakOff(kgf/cm') 3,191,26 1,133.29 OBM 1102.4 45.7 1505.7 170.6 fl* Eni E&P Division I Well Name:0115-54 ENI Petroleum Co.Inc. Daily Report Well Code:26195 Field Name:NIKAITCHUO • Date:2/18/2012 - Report#: 36 APIIUWI:50-029-23460-00-00 2" " page 1 of 1 Wellbore name: 0115-S4 Well Header PermiVConcession N° Operator ENI Share(%) Well Configuration type 402100 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(m) Ground Level(m) Water Depth(m) RKB-Base Flange(m) RKB-Tubing Spool(m) 16.22 3.72 11.37 Rig Information Contractor Rig Name Rig Type NABORS ALASKA NABORS 245 E 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) 0115-84 DRILLING 1/18/2012 5,848.81 1,092.64 5.864.35 185.75 31.6 31.29 Daily Information End Depth(mKB) End Depth(TVD)(... Depth Progress(m) Drilling Hours(hr) Avg ROP(m/hr) POB Temperature(°C) Weather Wind 5,757.67 1,104.39 345.64 9.41 36.7 91.0 -21.1 Cloudy WC-21" ENE @ 15 MPH Daily summary operation 24h Summary Drill ahead 8'%"section 1/17791'V18891' Operation at 07.00 Drill ahead 8'/"section as perwellplan @ 19,127 at report time 24h Forecast Drill ahead 8 G"section to planned TD 19190'-Clean up cycle(x11 BU)-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 03:00 3.00 3.00 DRILL E 3 -P Drilling Rotary Steerable 0 8'"section f/17791'1/17888'\450 gpm @ 2870?2930 psi/60.120 rpm @ 15.18k Bibs I WOB=3.13k lb\ECD=11.3?11.41 ppg\Up wt=175k lb-NO S/0-Rot wt=100k lb\Mud wt=9.3 ppg-Take survey as needed-Ream and wash one Jt every connection 03:00 08:00 5.00 8.00 DRILL E 25 TRO4 TDS's power cable broken owing hung up on the tong bucket-C/O power cable-Circulation 300 gpm @ 1550 psi-No losses-TDS unable to rotate 08:00 12:00 4.00 12.00 DRILL E 3 •P Drilling Rotary Steerable 0 8%"section 1/17888'V18283'\450 gpm @ 2930?3000 psi\60+120 rpm©17+18k ft'lbs\ WOB=4+13k lb\ECD=11.41711.66 ppg\Up wt=178k lb-NO S/0-Rot wt=100k lb\Mud wt=9.3 ppg-Take survey as needed-Ream and wash one Jt every connection 12:00 18:00 6.00 18.00 DRILL E 3 •P Drilling Rotary Steerable 0 8' 'section f/18283'1/18498'\450 gpm @ 3000?3050 psi\70+120 rpm @ 17+18k Nibs\ WOB=5+10k lb\ECD=11.66711.60 ppg\Up wt=170k lb-NO 5/0-Rot wt=100k lb\Mud wt=9.4 ppg-Take survey as needed-Ream and wash one Jt every connection 18:00 00:00 6.00 24.00 DRILL E 3 'P Drilling Rotary Steerable 0 8'h"section(/18498'1118891'\450 gpm @ 3050 psi\60+120 rpm @ 15+18k 8'lbs\WOB= 3+12k lb\ECD=11.60?11.50 ppg I Up wt=170k lb-NO 5/0-Rot wt=100k lb\Mud wt=9.4 ppg-Take survey as needed -Ream and wash one It every connection Daily ADT=9.41 hrs [ADT=64.95-JAR=65.33 hrs] Daily mud loss 920 bbl NOTES: -Operation slowed due to directional tools unable to get down-link while drilling -Average losses while drilling 50 bph Daily Contacts Position Contact Name Company Title E-mail Office Mobile Eni representative Ben Perry Eni Petroleum •Sr.DrIg.Spur. 907-685-1493 Eni representative Mirko Musumeci Eni Petroleum Ddg Spvr. 907-685-1493 907-903-7269 Eni representative Mitch Billington Eni Petroleum Rig Clerk 907-670-8601 Eni representative Sach Bowe Eni Petroleum Materal Coordinator 907-685-1491 907-299-0531 Eni representative Mike Nelson Eni Petroleum HSE 907-685-1496 Eni representative Alvin Criswell Eni Petroleum Expediter 907-980-7545 Tool Push Bruce Simonson Nabors Alaska Drilling Tool Pusher 907-670-1492 Tool Push Matti Turcotte Nabors Alaska Dolling Tour Pusher 907-670-1492 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(mKB) Bottom(mKB) Run Date CASING 95/8 L-80 0.00 3,180.59 2/8/2012 Last Leakoff Test Depth(mKB) TVD(mKB) Fluid Type Fluid Density(gIL) P Surf Applied(kgflcm') Eq.Mud Weight(gIL) P LeakOff(kgf/cm') 3 191.26 1,133.29 OBM 1102.4 45.7 1505.7 170.6 - 11411. Eni E&P Division Mel!Name:0115-S4 EN!Petroleum Co.Inc. Daily Report Well Code:26195 Field Name:NIKAITCHUQ • Date:2/19/2012 - Report#: 37 APIIUWI:50-029-23460-00-00 2" " page 1 of 1 Wellbore name: 0115-S4 Well Header Permit/Concession N° Operator ENI Share(%) Well Configuration type 402100 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(m) Ground Level(m) Water Depth(m) RKB-Base Flange(m) RKB-Tubing Spool(m) 16.22 3.72 11.37 Rig Information Contractor Rig Name Rig Type NABORS ALASKA NABORS 245 E 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) 0115-S4 DRILLING 1/18/2012 5,848.81 1,092.64 5,864.35 185.75 31.6 32.29 Daily Information End Depth(mKB) End Depth(TVD)(... Depth Progress(m) Drilling Hours(hr) Avg ROP(m/hr) POB Temperature(°C) Weather Wind 5,864.35 1,103.42 106.68 2.56 41.7 93.0 -21.1 Cloudy WC-21' ENE @ 10 MPH Daily summary operation 24h Summary Drill ahead 8%"section to planned TD 19240'-Clean up cycle(x7 BU)in progress Operation at 07.00 Clean up cycle @ 17,604'at report time 24h Forecast Complete clean up cycle(11 BU total)-BROOH V 9 5/8'Shoe-Flow check-POOH on elevator 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 05:30 5.50 5.50 DRILL E 3 P Drilling Rotary Steerable 0 8'/."section 1/18891'UTD(19240'MD-3619'TVD)1450 gpm @ 3050?3090 psi 160.120 rpm @ 15,18k ft'lbs\WOB=2=15k lb I ECD=11.41?11.6 ppg I Up wt=178k lb-NO S/O-Rot wt=100k lb\Mud wt=9.4 ppg- Take survey as needed-Ream and wash one Jt every connection Daily ADT=2.56 hrs ]ADT=66.2-JAR=67.89 hrs] 05:30 06.00 0.50 6.00 DRILL E 7 P Circulate and condition for 10 minutes-Flow check for 10 minutes,got back 80 bbls-Flow check additional 10 minutes. got back 65 bbls-Flow check additional 10 minutes,got back 58 bbls-Downtrending. 06:00 0930 3.50 9.50 DRILL E 7 P Clean up cycle:Circulate x2 BU(450 gpm @ 3100?3050 psi-120 rpm @ 17.5216.5k ft'lbs)Rack back 01 Std each BU // 1/19240'notice `„/r 09:30 14:00 4.50 14.00 DRILL E 7 TP03 Diller notice a gain in flow rate and pit gain-Shut well in(SICP=300 psi,after 15 minutes.dropped to 260 psi,held)- I/)171�/C/-� Circulated BU using drillers method holding 110 psi backpressure through an open choke(354 gaVmin @ 1876 psi)- Bottoms up showed nothing,mud looked good,no major rise in gas(30-50 units). 14:00 20:00 6.00 20.00 DRILL E 7 P Clean up cycle:Circulate 3x BU(4507420 gpm @ 3050?2700 psi-120 rpm @ 17k ft'lbs)rack back xl Std every BU (/19063't118767' 20:00 00:00 4.00 24.00 DRILL E 7 P Clean up cycle:Circulate 2x BU(420 gpm @ 370072640 psi-120 rpm @ 17715.5k ft'lbs)rack back x3 Std every BU f/1876T 1/18174' Daily mud loss 1018 bbl Daily Contacts Position Contact Name Company Title E-mail Office Mobile Eni representative Ben Perry Em Petroleum Sr.Ddg.Spvr. '907-685-1493 Eni representative Mirko Musumeci Eni Petroleum DrIg Spur. 907-685-1493 907-903-7269 Eni representative Mitch Billington Eni Petroleum Rig Clerk 907-670-8601 Eni representative Sach Bowe Eni Petroleum Materal Coordinator 907-685-1491 907-299-0531 Eni representative Mike Nelson Eni Petroleum HSE 907-685-1496 Eni representative Alvin Caswell Eni Petroleum Expediter 907-980-7545 Tool Push Bruce Simonson Nabors Alaska Drilling Tool Pusher 907-670-1492 Tool Push Mattt Turcofte Nabors Alaska Drilling Tour Pusher 907-670-1492 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(mKB) Bottom(mKB) Run Date CASING 9 5/8 L-80 0.00 3.180.59 2/8/2012 Last Leakoff Test Depth(mKB) TVD(mKB) Fluid Type Fluid Density(gIL) P Surf Applied(kgflcm') Eq.Mud Weight(g/L) P LeakOff(kgflcm') 3.191.26 1,133.29 OBM 1102.4 45.7 1505.7 170.6 Eni E&P Division .. I Well Name:0115-S4 Pi* ENI Petroleum Co.Inc. Daily Report Well Code:26195 Field Name: NIKAITCHUQ • API/UWI:50-029-23460-00-00 2 n r, Date:2/20/2012 - Report#: 38 �fh II page 1 of 1 Wellbore name: 0115-S4 Well Header Permit/Concession N° Operator ENI Share(%) Well Configuration type 402100 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(m) Ground Level(m) Water Depth(m) RKB-Base Flange(m) RKB-Tubing Spool(m) 16.22 3.72 11.37 Rig Information Contractor Rig Name Rig Type NABORS ALASKA NABORS 245 E 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) 0115-S4 DRILLING 1/18/2012 5,848.81 1,092.64 5,864.35 185.75 31.6 33.29 Daily Information End Depth(mKB) End Depth(TVD)(... Depth Progress(m) Drilling Hours(hr) Avg ROP(m/hr) FOB Temperature(°C) Weather Wind 5.864.35 1.103.42 0.00 92.0 -22.8 Light Blowing Snow ENE @ 16 MPH WC-32" Daily summary operation 24h Summary Complete clean up cycle(11 BU total)-BROOH 011950' Operation at 07.00 BROOH 10,650'at report time 24h Forecast BROOH//9 5/8"Shoe-Flow check-POOH on elevator 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 0830 8.50 8.50 DRILL E 6 'P Clean up cycle:Circulate 4x BU(420 gpm @ 364022600 psi-120 rpm @ 15.5214.5k hill's)rack back x3 Std every BU (/18174'1/16995' 08.30 00 00 15.50 24.00'DRILL E 6 'P 'BROOH(/16995'5/11950'(430 gpm @ 2600?2130 psi-120 rpm @ 14.5+9.5k ft-lbs-10 min/St) Daily mud loss 683 bbl Daily Contacts Position Contact Name _ Company Title E-mail Office Mobile Eni representative Ben Perry Eni Petroleum Sr.DrIg.Spvr. 907-685-1493 Eni representative Mirko Musumeci Eni Petroleum Ddg Spvr. 907-685-1493 907-903-7269 Eni representative Mitch Billington Eni Petroleum Rig Clerk 907-670-8601 Eni representative Such Bowe Eni Petroleum Materal Coordinator 907-685-1491 907-299-0531 Eni representative Mike Nelson Eni Petroleum HSE 907-685-1496 Eni representative Alvin Criswell Eni Petroleum Expediter 907-980-7545 Tool Push Bruce Simonson Nabors Alaska Drilling Tool Pusher 907-670-1492 Tool Push Matd Turcotte Nabors Alaska Drilling Tour Pusher 907-670-1492 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(mKB) Bottom(mKB) Run Date CASING 95/8 L-80 0.00 3,180.59 2/8/2012 Last Leakoff Test Depth(mKB) TVD(mKB) Fluid Type Fluid Density(gIL) P Surf Applied(kgf/cm') Eq.Mud Weight(gIL) P LeakOff(kgflcm') 3,191.26 1,133.29 OBM 1102.4 45.7 1505.7 1706 1Eni E&P Division .,} 'Well Name:0115 54 EN!Petroleum Co.Inc. Daily Repo L Well Code:26195 Field Name:NIKAITCHUO Date:212112012 - Report#: 39 APIIUW1:50-029-23460-00-00 e iii page 1 of 1 Wellbore name: 0115-S4 Well Header PermitlConcession N° Operator EM Share(%) Well Configuration type 402100 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(m) Ground Level(m) Water Depth(m) RKB-Base Flange(m) RKB-Tubing Spool(m) 16.22 3.72 11.37 Rig Information Contractor Rig Name Rig Type NABORS ALASKA NABORS 245 E 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) 0115-S4 DRILLING 1/18/2012 5,848.81 1,092.64 5,864.35 185.75 31.6 34.29 Daily Information End Depth(mKB) End Depth(TVD)(... Depth Progress(m) Drilling Hours(hr) Avg ROP(m/hr) POB Temperature(°C) Weather Wind 5,864.35 1,103.42 0.00 90.0 -21.1 Cloudy WC-25` 45°NE @ 12 mph Daily summary operation 24h Summary BROOH U 9 5/8"Shoe-Flow check-POOH on elevator Operation at 07.00 POOH on elevator @ 1240' 24h Forecast Continue to POOH on elevator-UD BHA#7-BOP test-P/U,M/U and RIH BHA#8(Breaker displacement) 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. 0000 '05:00 5.00- 5.00 DRILL E 6 P 'BROOH(/11950'8/10414'(430 gpm @ 2130?2050 psi-1207100 rpm @ 9.5.8.2k ft-lbs-10 min/St)-Ream twice 1/10750' 010435'-Lost 40 bbl while back ream 05.00 09:00 4.00' 9.00 DRILL E 7 P Clean up cycle at 9 5/8"shoe:Circulate 4x BU(440 gpm @ 2030?1990 psi-100 rpm @ 8.2k 6'lbs)reciprocate up/down 09:00 16:30 7.50 16.50 DRILL E 11 P Close top rams and check flow through choke line-Record gain every hour:95/38/11/5/5/4/4 bbl/Hr(Total gain during flow check 151 bbl) 16.30 21:00 4.50 21.00 DRILL E 4 P POOH on elevator f/10414'8/8500'as per TAD trip speed schedule(371 bbl/Hr gain) 21:00 00:00 3.00' 24.00 DRILL E 4 'P POOH on elevator(/8500'1/6695'as per TAD trip speed schedule(Proper displacement) Daily Contacts Position Contact Name Company Title E-mail Office Mobile Eni representative Ben Perry Eni Petroleum Sr.Ddg.Spvr. 907-685-1493 Eni representative Mirka Musumeci Eni Petroleum Ddg Spur. 907-685-1493 907-903-7269 Eni representative Bernie Leas Eni Petroleum Rig Clerk 907-670-8601 907-575-9427 En:representative Sach Bowe Eni Petroleum Materal Coordinator 907-685-1491 907-299-0531 Eni representative Steve Millea ENI Petroleum HSE 907-685-1496 Eni representative Alvin Criswell Eni Petroleum Expediter 907-980-7545 Tool Push Bruce Simonson Nabors Alaska Dolling Tool Pusher 907-670-1492 Tool Push Matti Turcotte Nabors Alaska Dnlling Tour Pusher 907-670-1492 Last Casing seat I Cas.Type OD(in) ID(in) Grade Top(mKB) Bottom(mKB) Run Date CASING 95/8 L-80 0.00 3,180.59 2/8/2012 Last Leakoff Test Depth(mKB) TVD(mKB) Fluid Type Fluid Density(gIL) P Surf Applied(kgflcm') Eq.Mud Weight(g/L) P LeakOff(kgflcm') 3.191.26 1,133.29 OBM 1102.4 45.7 1505.7 170.6 lif"f* Eni E&P Division 'Well Name:0115-S4 ENI Petroleum Co.Inc. Daily ReportWell Code:26195 Field Name:NIKAITCHUO � API/DIM:50-029-23460-00-00 2 II^ Date:2/22/2012 - Report#: 40 'I II npage 1 of 1 Wellbore name: 0115-S4 Well Header Permit/Concession N° Operator ENI Share(%) Well Configuration type 402100 ENI PETROLEUM 100.00 HORIZONTAL _ - Rotary Table Elevation(m) Ground Level(m) Water Depth(m) RKB-Base Flange(m) RKB-Tubing Spool(m) 16.22 3.72 11.37 Rig Information Contractor Rig Name Rig Type NABORS ALASKA NABORS 245 E 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) 0115-S4 DRILLING 1/18/2012 5,848.81 1,092.64 5,864.35 185.75 31.6 35.29 Daily Information End Depth(mKB) End Depth(TVD)(... Depth Progress(m) Drilling Hours(hr) Avg ROP(m/hr) POB Temperature(°C) Weather Wind 5,864.35 1.103.42 0.00 94.0 -27.2 Cloudy,Light Snow Winds Calm WC-17° Daily summary operation 24h Summary POOH on elevator-L/D BHA#7-BOP test-Downtime due to a failure on hydraulic pump Operation at 07.00 Repairing hydraulic test pump. 24h Forecast Fix hydraulic pump-Complete BOP test-P/U,M/U and RIH BHA#8(Breaker displacement) 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 04:30 4.50 4.50 DRILL E 4 P POOH on elevator f/6695'5325'as per TAD trip speed schedule(Proper displacement) 04:30 08:30 4.00 8.50 DRILL E 5 P POOH and L/D BHA#7(Bit Dull:1-1-WT-A-X-1-CT-TD)-Download MWD tools 08:30 12:30 . 4.00' 12.50 DRILL C 5 P Pull wear ring failed(lock in groove packed with cuttings)-P/U and M/U wash tool and flush wear ring profile-Pull wear ring-Install test plug-Fill Stack and lines w/water-Purge air out of system-R/U BOP test equipment 12:30 '14:30 2.00 14.50 DRILL C 25 TR05 Body test BOP and lines 3500 psi-Found leak on ram door-Drain stack-C/O door seal-Fill Stack w/water 14:30 22:00 7.50 22.00'DRILL C '12 P 'Test BOP as per AOGCC requirements w/5"and 4 W test Jt-Annular @ 250?2500 psi-Rams,choke manifold,floor and top drive valves @ 250?3500 psi-Chart record-BOP test witness waived by AOGCC rep.Chuck Scheve t)-11 NOTES Failure on hydraulic pump-Test pump,Iron roughneck and Winch not able to work-Upper and lower rams not yet tested 1 c� w/4%"Jt 22:00 '00:00 2.00 24.00 DRILL C '25 TR99 Work on hydraulic pump failure-Pull test plug-Fill up stack-Monitor well on top tank Daily Contacts Position Contact Name _ Company Title E-mail Office Mobile Eni representative Ben Perry Eni Petroleum Sr.DrIg.Spvr. 907-685-1493 Eni representative Mirko Musumeci Eni Petroleum Drlg Spvr. 907-685-1493 907-903-7269 Eni representative Bernie Leas Eni Petroleum Rig Clerk 907-670-8601 907-575-9427 Eni representative Sach Bowe Eni Petroleum Materal Coordinator 907-685-1491 907-299-0531 Eni representative Steve Milieu ENI Petroleum HSE 907-685-1496 Eni representative Alvin Criswell Eni Petroleum Expediter 907-980-7545 Tool Push Mike Williams Nabors Alaska Drilling Tool Pusher 907-670-1492 Tool Push Mattt Turcotte Nabors Alaska Drilling Tour Pusher 907-670-1492 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(mKB) Bottom(mKB) Run Date CASING 9 5/8 L-80 0.00 3.180.59 2/8/2012 Last Leakoff Test Depth(mKB) TVD(mKB) Fluid Type Fluid Density(gIL) P Surf Applied(kgflcm°) Eq.Mud Weight(gIL) P LeakOff(kgflcm°) 3,191.26 1,133.29 OBM 1102.4 45.7 1505.7 170.6 Eni E&P Division I Well Name:0115-S4 f ii* ENI Petroleum Co.Inc. Daily Report Well Code:26195 Field Name:NIKAITCHUO • Date:2/23/2012 - Report#: 41 APIIUWI:50-029-23460-00-00 2 rr i U page 1 of 1 wellbore name: 0115-S4 Well Header Permit/Concession N' Operator ENI Share(%) Well Configuration type 402100 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(m) Ground Level(m) Water Depth(m) RKB-Base Flange(m) RKB-Tubing Spool(m) 16.22 3.72 11.37 Rig Information Contractor Rig Name Rig Type NABORS ALASKA NABORS 245 E 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) 0115-S4 DRILLING 1/18/2012 5,848.81 1,092.64 5,864.35 185.75 31.6 36.29 Daily Information End Depth(mKB) End Depth(TVD)(... Depth Progress(m) Drilling Hours(hr) Avg ROP(mlhr) POB Temperature('C) Weather Wind 5,864.35 1,103.42 0.00 91.0 -27.8 Cloudy,WC-37° 225`SW @ 10 mph Daily summary operation 24h Summary Fix hydraulic pump-Complete BOP test-P/U,M/U and RIH BHA#8(Breaker displacement) Operation at 07.00 RIH on elevators©15,000' 24h Forecast RIH BHA#8(Breaker displacement). Displace open hole to FazeAway Breaker Fluid. Displace 9-5/8"casing above the FazeAway Breaker to 9.1 ppg KCI Inhibited Brine. Lithology Shows MAASP(kgf/cm') Mud Weight(gIL) 1138.4 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00:00 0900 9.00 9.00 DRILL C 25 TR99 C/O motor on hydraulic pump unit 09:00 10.30 1.50 10.50 DRILL C 12 P Install test plug-Fill Stack and lines w/water-Purge air out of system-Test upper and lower rams as per AOGCC requirements w/4'G'test Jt©250?3500 psi-Chart record-BOP test witness waived by AOGCC rep.Chuck Scheve 10:30 11:30 1.00 11.50 DRILL C 5 P Pull test plug-Set wear ring 11:30 20:00 8.50 20.00 DRILL E 5 P M/U BHA#8[8W Hole Opener+Bit Sub vii/float+x3 HWDP 5"+Float Sub+Jar+x2 HWDP 5"+XO and RIH on elevators 1/10400'filling pipe every 20 Std 20:00 21:30 1.50 21.50 DRILL E 20 P Slip and cut 70'drilling line-Service TDS.Draw works and Crown Sheaves 21 30 00:00 2.50 24.00 DRILL E 4 P RIH on elevators f/10400'1/12247'filling pipe every 20 Std and break circulation,correct displacement Tight spot©12196'-Ream up/down x3 times(300 gpm©1000 psi-70 rpm©7+8k fflbs) Daily Contacts Position Contact Name Company Tide E-mail Office Mobile Eni representative Ben Perry Eni Petroleum Sr.Dug,Spvr. 907-685-1493 Eni representative Mirko Musumeci Eni Petroleum Dug Spvr. 907-685-1493 907-903-7269 Eni representative Bernie Leas Eni Petroleum Rig Clerk 907-670-8601 907-575-9427 Eni representative Sach Bowe Eni Petroleum Materal Coordinator 907-685-1491 907-299-0531 Eni representative Steve Milieu ENI Petroleum HSE 907-685-1496 Eni representative Alvin Caswell Eni Petroleum Expediter 907-980-7545 Tool Push Mike Williams Nabors Alaska Dolling Tool Pusher 907-670-1492 Tool Push Math Turcode Nabors Alaska Dulling Tour Pusher 907-670-1492 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(mKB) Bottom(mKB) Run Date CASING 9 5/8 L-80 0.00 3.180.59 2/8/2012 Last Leakoff Test Depth(mKB) ND(mKB) Fluid Type Fluid Density(gIL) P Surf Applied(kgflcm') Eq.Mud Weight(gIL) P LeakOff(kgf/cm') 3.191.26 1,133.29 OBM 1102.4 45.7 1505.7 170.6 t t Eni E&P Division I Well Name:0115-S4 fill* ENI Petroleum Co.Inc. Daily Report Well Code:26195 Field Name:NIKAITCHUQ • API/UN:50-029-23460-00-00 � ^ • ^n Date:2/24/2012 - Report#: 42 lLe II Ii II • page 1 of 1 Wellbore name: 0115-S4 Well Header Permit/Concession N° Operator ENI Share(%) Well Configuration type 402100 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(m) Ground Level(m) Water Depth(m) RKB-Base Flange(m) RKB-Tubing Spool(m) 16.22 3.72 11.37 Rig Information Contractor Rig Name Rig Type NABORS ALASKA NABORS 245 E 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) 0115-S4 DRILLING 1/18/2012 5,848.81 1092.64 5,864.35 185.75 31.6 37.29 Daily Information End Depth(mKB) End Depth(TVD)(... Depth Progress(m) Drilling Hours(hr) Avg ROP(m/hr) POB Temperature(°C) Weather Wind 5.664.35 1.103.42 0.00 89.0 -36.7 Partly Cloudy.WC- 202"SSW @ 9 mph 57" Daily summary operation 24h Summary Continue to RIH BHA#8-Circulate BU-Flow check-R/U to displace FazeAway breaker fluid Operation at 07.00 Displace 8'/"Open Hole from 9.4 ppg FazePro to 9.5 ppg FazeAway breaker fluid 24h Forecast Displace 8 V.."Open Hole from 9.4 ppg FazePro to 9.5 ppg FazeAway breaker fluid-POOH on elevator following TAD top speed schedule Lithology Shows MAASP(kgf/cm') Mud Weight(gIL) I 1126.4 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00:00 05:30 5.50 5.50 DRILL E 4 P RIH on elevators f/12247'7/16790'filling pipe every 20 Std and break circulation,correct displacement-Wash and ream through small areas at 13,773',14,183',14,457',14,545',15,255',16.350'.and 16,667' 05:30 10:00 4.50 10.00 DRILL E 6 P Ream and wash down 016790'1119240'(150-200 gpm @ 900.1000 psi-60 rpm @ 9.5.13k Bibs) 10:00 18:00 8.00 18.00 DRILL E 7 P Circulate BU reciprocating and rotating(125 gpm @ 7007550 psi-60 rpm @ 13k ft'lbs)Total losses 330 bbl-Max gas on surface 942 units-Clean pits 18:00 23:00 5.00 23.00 DRILL E 11 P Flow check recording gain 52/40/32/24/16/8/0 bbl/Hr(Total gain during flow check 58 bbl)[Break circulation every 15 min (0.8 bpm @ 270 psi for 5 min)] 23:00 00:00 1.00 24.00 DRILL E 2 P Connected Vac Trucks with mud pump-PJSF-Prepare to Displace 8%"Open Hole from 9.4 ppg FazePro to 9.5 ppg FazeAway breaker fluid NOTES Hard line from rig pits to overboard plugged by ice-Connect steam line to unfreeze it Daily Contacts Position i Contact Name Company Title E-mail Office Mobile Eni representative Ben Perry I Eni Petroleum Sr.Ddg.Spot. 907-685-1493 Eni representative Mirko Musumeci Eni Petroleum Ddg Spur. 907-685-1493 907-903-7269 Eni representative Bernie Leas Eni Petroleum Rig Clerk 907-670-8601 907-575-9427 • Eni representative Sach Bowe Eni Petroleum Materal Coordinator 907-685-1491 907-299-0531 Eni representative Steve Millea ENI Petroleum HSE 907-685-1496 Eni representative Alvin Criswell Eni Petroleum Expediter 907-980-7545 Tool Push Mike Williams Nabors Alaska Drilling Tool Pusher 907-670-1492 I Tool Push Mum Turcotte Nabors Alaska Dolling Tour Pusher 907-670-1492 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(mKB) Bottom(mKB) Run Date CASING 95/8 L-80 0.00 3.180.59 2/8/2012 Last Leakoff Test Depth(mKB) TVD(mKB) Fluid Type Fluid Density(g/L) P Surf Applied(kgf/cm') Eq.Mud Weight(gIL) P LeakOff(kgf/cm') 3.191.26 1,133.29 OBM 1102.4 45.7 1505.7 170.6 1111* -n Eni E&P Division I Well Name: 0115-S4 ENI Petroleum Co.Inc. Daily Report..}` Well Code:26195 Field Name:NIKAITCHUO • API/U1M:50-029-23460-00-00 2 nil�,t,ii Date:2/25/2012 - Report#: 43 page 1 of 1 wellbore name: 0115-S4 Well Header Permit/Concession N' Operator ENI Share(%) Well Configuration type 402100 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(m) Ground Level(m) Water Depth(m) RKB-Base Flange(m) RKB-Tubing Spool(m) 16.22 3.72 11,37 Rig Information Contractor Rig Name Rig Type NABORS ALASKA NABORS 245 E 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) 0115-04 DRILLING 1/18/2012 5,848.81 1,092.64 5,864.35 185.75 31.6 36.29 Daily Information End Depth(mKB) End Depth(TVD)(... Depth Progress(m) Drilling Hours Thr) Avg ROP(m/hr) POB Temperature('C) Weather VVind 5,864.35 1,103.42 0.00 90.0 -36.7 Clear,WC-50' 135"SE @ 5 mph Daily summary operation 24h Summary Displace 8 Y.."Open Hole from 9.4 ppg FazePro to 9.5 ppg FazeAway breaker fluid-POOH on elevator following TAD trip speed schedule Operation at 07.00 POOH on elevator @ 15,188'. 24h Forecast POOH on elevator following TAD trip speed schedule to 9 5/8'shoe-Displace KCI Brine 9.1 ppg 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 25 U Complete R/U to displace Breaker fluid-Unfreeze hard line from ng pits to overboard plugged by ice 01:00 09:00 8.00. 9.00 DRILL E 9 P Displace 8''/."Open Hole from 9,4 ppg FazePro to 9.5 ppg FazeAway breaker fluid-Pumped 680 bbl FazeAway(2 bpm @ 1100 psi-40 rpm @ 13k(bibs)-Displaced with 132 bbl FazePro+30 bbl 11.4 ppg Pill+12 bbl FazePro-Total losses during Job:42 bbl 09:00 00.00 15,00. 24.00 DRILL E 4 P POOH on elevators 1/19238'1/16077'as per TAD trip speed schedule-Total losses during trip.23 bbl-No tight spot encountered NOTES: f/19230'(09:00)(/18535'(12:30)gain 4 bbl/Hr f/18535'(12:30)1/18000'(15:00)proper displace 818000'(15:00)1/16950'(20:00)loss 1?2.5 bbl/Hr f/16950'(20:00)1/16077'(24:00)loss 2.5?3.5 bbl/Hr Daily Contacts Position Contact Name Company Title E-mail Office Mobile Eni representative Ben Perry Eni Petroleum 'Sr.Dig.Spvr. 907-685-1493 Eni representative Mirko Musumeci Eni Petroleum DrIg Spvr. 907-685-1493 907-903-7269 Eni representative Bernie Leas Eni Petroleum Rig Clerk 907-670-8601 907-575-9427 Eni representative Sach Bowe Eni Petroleum Materal Coordinator 907-685-1491 907-299-0531 Eni representative Steve Millea ENI Petroleum HSE 907-685-1496 Eni representative Alvin Caswell Eni Petroleum Expediter 907-980-7545 Tool Push Mike Williams Nabors Alaska Drilling Tool Pusher 907-670-1492 Tool Push Mattt Turcotte Nabors Alaska Drilling Tour Pusher 907-670-1492 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(mKB) Bottom(mKB) Run Date CASING 9 5/8 L-80 0.00 3.180.59 2/8/2012 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') 3.191.26 1,133.29 OBM 11024 45.7 1505.7 170.6 14 Eni E&P Division [Well Name:0115-S4 ENI Petroleum Co.Inc. Daily Report Well Code:26195 Field Name:NIKAITCHUQ • API/UWI:50-029-23460-00-00 2 II^r, Date:2/26/2012 - Report#: 44 " II page 1 of 1 Wellbore name: 0115-S4 Well Header PermiVConcession N° Operator ENI Share(%) Well Configuration type 402100 ENI PETROLEUM 100.00.HORIZONTAL Rotary Table Elevation(m) Ground Level(m) Water Depth(m) RKB-Base Flange(m) RKB-Tubing Spool(m) 16.22 3.72 11.37 Rig Information Contractor Rig Name Rig Type NABORS ALASKA NABORS 245 E 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) 0115-04 DRILLING 1/18/2012 5,848.81 1,092.64 5,864.35 185.75 31.6 39.29 Daily Information End Depth(mKB) End Depth(TVD)(... Depth Progress(m) Drilling Hours(hr) Avg ROP(mlhr) POB Temperature(°C) Weather Wind 5,864.35 1,103.42 0.00 93.0 -33.3 Scattered Clouds. 45°NE @ 9 mph WC-50" Daily summary operation 24h Summary POOH on elevators f/16.188'to 10,180'following K&M top speed schedule/Circulate and condition B/U at low flow rate. Operation at 07.00 Circulating and conditioning B/U at low flow rate. 24h Forecast Displace to 9.1 ppg KCI Inhibited Brine/POOH on elevators as per K&M trip speed schedule/MU and RIH w/4-1/2"Hydril 521 liner. 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. 0000 12'00 12.00 12.00 DRILL E 4 P POOH on elevators as per K&M schedule f/16,188'-13,334'/Up Wt 147K/Well taking 3-4 bbls per hour/Loss of 42 bbls since starting to POOH. 12:00 20:00 8.00 20.00 DRILL E 4 P POOH on elevators as per K&M schedule f/13,344'-10,193'/Up Wt 140K,Dn Wt 85K. 20:00 00:00 4.00 24.00 DRILL E 7 P Begin circulating and condition B/U as per mud engineer&company man/Circulate at 14 SPM low rate to minimize losses during"BUS"stks/See 34 bbls losses Uhole while pumping"BUS"/GPM=50,PSI=200,RPM=40,TQ=5K. Daily loss to hole 99 bbls/Total losses in production hole.4,594 bbls. Daily Contacts Position Contact Name Company • Title E-mail Office Mobile Eni representative Ben Perry -Eni Petroleum 'Sr.Ddg.Spvr. '907-685-1493 Eni representative Bernie Leas Eni Petroleum Rig Clerk 907-670-8601 907-575-9427 Eni representative Sach Bowe Eni Petroleum Materal Coordinator 907-685-1491 907-299-0531 Eni representative Steve Millea ENI Petroleum HSE 907-685-1496 Eni representative Alvin Criswell Eni Petroleum Expediter 907-980-7545 Tool Push Mike Williams Nabors Alaska Drilling Tool Pusher 907-670-1492 Tool Push Mattt Turcotte Nabors Alaska Drilling Tour Pusher 907-670-1492 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(mKB) Bottom(mKB) Run Date CASING 95/8 L-80 0.00 3,180.59 2/8/2012 Last Leakoff Test Depth(mKB) TVD(mKB) Fluid Type Fluid Density(gIL) P Surf Applied(kgflcm') Eq.Mud Weight(gIL) P LeakOff(kgflcm') 3.191.26 1,133.29 OBM 1102.4 45.7 1505.7 170.6 Eni E&P Division 'Well Name: 0115-S4 Or111* ENI Petroleum Co.Inc. Daily Report Well Code:26195 Field Name:NIKAITCHUQ APIIUWI:50-029-23460-00-00 2 I` II�,r,II Date:212712012 - Report#: 45 page 1 of 1 Wellbore name: 0115-S4 Well Header Permit/Concession N° Operator ENI Share(%) Well Configuration type 402100 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(m) Ground Level(m) Water Depth(m) RKB-Base Flange(m) RKB-Tubing Spool(m) 16.22 3.72 11.37 Rig Information Contractor Rig Name Rig Type NABORS ALASKA NABORS 245 E 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) 0115-S4 DRILLING 1/18/2012 5,648.81 1,092.64 5,864.35 165.75 31.6 40.29 Daily Information End Depth(mKB) End Depth(TVD)(... Depth Progress(m) Drilling Hours(hr) Avg ROP(m/hr) POB Temperature(°C) Weather Wind 5,864.35 1.103.42 0.00 93.0 -40.2 Partly Cloudy.WC- 225'SW @ 6.8 mph 61 Daily summary operation 24h Summary Circulated BU @ 10,187'. Displaced 9.4 ppg FazePro OBM with 9.2 ppg 3%KCI brine. POOH and L/D HWDP and BHA#8. P/U liner running tools. Operation at 07.00 RIH with 4-1/2"11.6 ppf L-80 Hydnl 521 liner at 1,661'. 24h Forecast RIH w/4-1/2"11.6 ppf L-80 Hydnl 521 liner. 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 05:00 5.00 5.00 DRILL 'E '7 P Continue circulating bottoms up @ 10,187'I Circulate @ 1 bbl/min controlling losses/Total losses 59 bbls while circulating bottoms up. 05:00 11:00 6.00 11.00 DRILL 0 9 P Pump 50 bbl hi-vis spacer/Displace 9.4 ppg Faze Pro OBM with 9.2 ppg KCI brine/Pump @ 1.5 bbls/min rotating at 40 rpm/Once pill and clean fluid was out of dnlist ing,increased pump rate to 4.5 bbls/min rotating @ 120 rpm,reciprocating pipe one stand/Lost 69 bbls while pumping./Up Wt=100K,Dn Wt=85K,TO=8,5K. 11:00 13:30 2.50 13.50 DRILL 'E -20 P Clean shakers and pits of OBM/Monitor well/Well flowed back 10 bbls,then became static. 13:30 20:30 7.00 20.50 DRILL E 4 P POOH(/10,193'pulling @ 3 min/stand for 10 stands,2 min/stand to 7,000',1 min/stand to surface as per KW trip schedule./UD HWDP and BHA#8. 20:30 23.30 3.00 23.50 DRILL E '20 P Change saver sub 1/4-1/2"IF to 4-1/2"NC-46/PU liner running tools/PJSM on running liner. 23:30 00.00 ' 0.50 24.00'DRILL 'E 20 P M/U shoe track/Baker lock shoe. Daily Contacts Position Contact Name Company Title E-mail Office Mobile Eni representative Ben Perry Eni Petroleum Sr.DrIg.Spvr. 907-685-1493 Eni representative Bernie Leas Eni Petroleum Rig Clerk 907-670-8601 907-575-9427 Eni representative Sach Bowe Eni Petroleum Materal Coordinator 907-685-1491 907-299-0531 Eni representative Steve Millea ENI Petroleum HSE 907-685-1496 Eni representative Alvin Caswell Eni Petroleum Expediter 907-980-7545 Tool Push Mike Williams Nabors Alaska Drilling Tool Pusher 907-670-1492 Tool Push Mem Turcotte Nabors Alaska Drilling Tour Pusher 907-670-1492 Last Casing seat Cas.Type OD(in) ID(in) _ _ Grade Top(mKB) Bottom(mKB) Run Date LINER 41/2 L80 3.110.83 5,860.69 2/27/2012 Last Leakoff Test Depth(mKB) TVD(mKB) Fluid Type Fluid Density(g/L) P Surf Applied(kgflcm') Eq.Mud Weight(gIL) P LeakOff(kgflcm') 3,191.26 1,133.29 OBM 1102.4 45.7 1505.7 170.6 Eni E&P Division .,} I Well Name:0115-S4 rif I 10 ENI Petroleum Co.Inc. Daily Repo ` Well Code:26195 Field Name:NIKAITCHUO • API/UWI:50-029-23460-00-00 2^ll Date:2/28/2012 - Report#: 46 I� II page 1 of 1 Wellbore name: 0115-S4 Well Header Permit/Concession N° Operator ENI Share(%) Well Configuration type 402100 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(m) Ground Level(m) Water Depth(m) RKB-Base Flange(m) RKB-Tubing Spool(m) 16.22 3,72 11.37 Rig Information Contractor Rig Name Rig Type NABORS ALASKA NABORS 245 E 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) 0115-S4 DRILLING 1/18/2012 5,848.81 1,092.64 5,864.35 185.75 31.6 41.29 Daily Information End Depth(mKB) ,End Depth(TVD)(... Depth Progress(m) Drilling Hours(hr) Avg ROP(m/hr) POB Temperature(°C) Weather Wind 5,864.35 1.103.42 0.00 94.0 -39.6 Scattered Clouds, 225°SW @ 5 mph WC-55° Daily summary operation 24h Summary RIH with 4-1/2",11.6 ppf,L-80 Hydril 521 production finer to 9,031'. Operation at 07.00 RIH with 4-1/2",11.6 ppf,L-80 Hydril 521 production liner at 14,289'. 24h Forecast RIH with 4-1/2",11.6 ppg,L-80 Hydril 521 liner assy to proper setting depth/Pressure test lines/Drop setting ball/Pressure to 3,000 psi to set SLZXP hanger packer/Pressure test packer.POOH L/D DP. Lithology Shows MAASP(kgflcm°) Mud Weight(g/L) 1102.4 Time Log Start End Cum Time Time Our(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00:00 12:00 12.00 12.00 DRILL E 4 P Pick up and RIH with 4-1/2",11.6 ppf,L-80 Hydril 521 production liner/Place ICD's and swell packers as per liner tally/ Torque 6,000 to 6.300 ft/lbs. .. 12:00 22:00 10.00 22.00 DRILL E 4 P RIH with 4-1/2",11.6 ppf,L-80 Hydril 521 production liner and ZXP finer hanger/packer assy and running tool to 9,031'/ Place ICD's and swell packers as per liner tally/Average torque 6,300 ft/lbs/Mix and pour Pal Mix and let set up for 30 1."'"A'''''` mins/Change out elevators to 4-1/2". 22:00 00:00 2.00 24.00 DRILL E 4 P RIH with 4-1/2",11.6 ppf,L-80 Hydril 521 production liner on 4-1/2"DP from 9,031 to 10,362'. Up Wt=100K,Dn Wt=70K, Rot Wt=88K. Daily Contacts Position Contact Name Company Title E-mail Office Mobile Eni representative Ben Perry Eni Petroleum Sr.Ddg.Spvr. 907-685-1493 Eni representative Bernie Leas Eni Petroleum Rig Clerk 907-670-8601 907-575-9427 Eni representative Steve Millea ENI Petroleum HSE 907-685-1496 Eni representative Steve Abbott Eni Petroleum Material Coordinator Eni representative Alvin Cnswell Eni Petroleum Expediter 907-980-7545 Tool Push Mike Williams Nabors Alaska Drilling Tool Pusher 907-670-1492 Tool Push Mattt Turcotte Nabors Alaska Drilling Tour Pusher 907-670-1492 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(mKB) Bottom(mKB) Run Date LINER 41/2 L80 3,110.83 5,860.69 2/27/2012 Last Leakoff Test Depth(mKB) TVD(mKB) Fluid Type Fluid Density(g/L) P Surf Applied(kgflcm°) Eq.Mud Weight(gIL) P LeakOff(kgflcm°) 3,191.26 1,133.29 OBM 1102.4 45.7 1505.7 170.6 Eni E&P Division I Well Name: 0115-S4 ENI Petroleum Co.Inc. Daily Report Well Code:26195 Field Name:NIKAITCHUO • 2^PI* Date:2/29/2012 - Report#: 47 API/UWI:50-029-23460-00-00 II II page 1 of 1 Wellbore name: 0115-S4 Well Header Permit/Concession N° Operator ENI Share(%) Well Configuration type 402100 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(m) Ground Level(m) Water Depth(m) RKB-Base Flange(m) RKB-Tubing Spool(m) 16.22 3.72 11.37 Rig Information Contractor Rig Name Rig Type NABORS ALASKA NABORS 245 E 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) 0l15-S4 DRILLING 1/18/2012 5,848.81 1.092.64 5,864.35 185.75 31.6 42.29 Daily Information End Depth(mKB) End Depth(TVD)1... Depth Progress(m) Drilling Hours(hr) Avg ROP(m/hr) POB Temperature °C) Weather 5,864.35 1,10342 0.00 93.0 -42.8 Mostly Clear,WC- 225`SW @ 7 mph 67' Daily summary operation 24h Summary RIH with 4.5",11.6#,L-80 Hydril 521 liner/Liner set @ 19,228'MD/Liner top @ 10.206'MD/POOH L/D 4.5"and 5"DP. Operation at 07.00 POOH UD 5"DP@3.018'. 24h Forecast POOH UD 5"DP/RIH with 5"DP from derrick/UD E-CD subs./POOH L/D 5"DP. Lithology Shows MAASP(kgttcm') Mud Weight(gIL) 1102.4 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Deno, 00.00 14:00 14.00 14.00 DRILL E 4 P RIH with 4.5".11.6 6,L-80 Hydril 521 production liner on 4.5"and 5"drill pipe to 19,228'MD. 14.00 16:30 2.50 16.50 DRILL E 19 P Drop 1-5/8"setting ball/Pump down drill pipe until sealed/Pressure up to 300 psi,held,felt set/Continue to pressure up to 4,000 psi,held,felt packer set/Bleed off DP pressure to zero/Line up on annulus,pressuring up to 1,500 psi and held for 10 minutes/Good test,on chart/Bleed off pressure and release from hanger/Go thru motions for manual setting as per Baker Rep./L/D pup/Liner set @ 19,228'MD/Liner top @ 10,206'MD. 16:30 00:00 7.50' 24.00 DRILL E 4 P POOH UD 5"and 4.5"DP 1/10,153'to 5,795'. Daily Contacts Position Contact Name Company Title E-mail Office Mobile Eni representative Ben Perry Eni Petroleum Sr.Drig.Spvr. 907-685-1493 Eni representative Bernie Leas Eni Petroleum Rig Clerk 907-670-8601 907-575-9427 Eni representative Steve Millea ENI Petroleum HSE 907-685-1496 Eni representative Ken Bogner Eni Petroleum Material Coordinator Eni representative Greg Parker Eni Petroleum Expediter 907-980-7545 Tool Push Mike Williams Nabors Alaska Dolling Tool Pusher 907-670-1492 Tool Push Matt Vanhoose Nabors Alaska Drilling Tour Pusher 907-670-1492 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(mKB) Bottom(mKB) Run Date LINER 41/2 L80 3,110.83 5.860.69 2/27/2012 Last Leakoff Test Depth(mKB) TVD(mKB) Fluid Type Fluid Density(g/L) P Surf Applied(kgflcm') Eq.Mud Weight(gIL) P LeakOff(kgflcm') 3.191.26 1,133.29 OBM 1102.4 45.7 1505.7 170.6 Eni E&P DivisionWell Name:0115-S4 ENI Petroleum Co.Inc. Daily Report Well Code:26195 Field Name:NIKAITCHUO • API/UWI:50-029-23460-00-00 2^r, Date:3/1/2012 - Report#: 48 g II I� page 1 of 1 Wellbore name: 0115-S4 Well Header Permit/Concession N° Operator ENI Share(%) Well Configuration type 402100 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(m) Ground Level(m) Water Depth(m) RKB-Base Flange(m) RKB-Tubing Spool(m) 16.22 3.72 11.37 Rig Information Contractor Rig Name Rig Type NABORS ALASKA NABORS 245 E 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) 0115-S4 DRILLING 1/18/2012 5,848.81 1,092.64 5,864.35. 185.75 31.6 43.29 Daily Information End Depth(mKB) End Depth(TVD)(... Depth Progress(m) Drilling Hours(hr) Avg ROP(m/hr) POB Temperature(°C) Weather Wind 5,864.35 1,103.42 0.00 92.0 -45.0 Partly Cloudy.WC- 225"SW @ 10 mph 77" Daily summary operation 24h Summary L/D 4.5"and 5"DP/UD Baker running tools/RIH with 5"DP laying down WEI E-CD subs/POOH laying down 5"DP. Operation at 07.00 L/D 5"DP at 1,161'. THIS IS THE FINAL DAILY DRILLING REPORT. 24h Forecast Complete UD 5"DP/Rig up GBR equipment/PU and RIH with 4.5"production tieback string. Lithology Shows MAASP(kgflcm°) Mud Weight(gIL) 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 4 P POOH lay down 4.5"and 5"DP/Lay down Baker liner running tools. 06:00 08:00 2.00 8.00 DRILL E 20 P Slip and cut 103'drilling line. 08:00 12:00 4.00 12.00 DRILL E 4 P RIH w/5"DP from derrick to 3,936'/Lay down WEI E-CD subs on way in hole. 12:00 16:30 4.50 16.50 DRILL E 4 P RIH with 5"DP from 3,936'to 9,051'/Lay down WEI E-CD subs on way in the hole. 16:30 00:00 7.50 24.00 DRILL E 4 P POOH lay down 5"DP from 9,051'to 4.162'. Daily Contacts Position Contact Name Company Title E-mail Office Mobile Eni representative Ben Peny Eni Petroleum Sr.Ddg.Spvr. 907-685-1493 Eni representative Bernie Leas Eni Petroleum Rig Clerk 907-670-8601 907-575-9427 Eni representative Steve Millea ENI Petroleum HSE 907-685-1496 Eni representative Ken Bogner Eni Petroleum Material Coordinator Eni representative Greg Parker Eni Petroleum Expediter 907-980-7545 Tool Push Mike Williams Nabors Alaska Dolling Tool Pusher 907-670-1492 Tool Push Matt Vanhoose Nabors Alaska Drilling Tour Pusher 907-670-1492 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(mKB) Bottom(mKB) Run Date LINER 41/2 L80 3,110.83 5,860.69 2/27/2012 Last Leakoff Test Depth(mKB) TVD(mKB) Fluid Type Fluid Density(gIL) P Surf Applied(kgflcm°) Eq.Mud Weight(gIL) P LeakOff(kgflcm') 3,191.26 1,133.29 OBM 1102.4 45.7 1505.7 170.6 filli* Eni E&P Division [Well Name:0115-S4 ENI Petroleum Co.Inc. Daily Report Well Code:26195 Field Name:NIKAITCHUO • Date:3/2/2012 - Report#: 1 API/UWI:50-029-23460-00-00 2 i i page 1 of 1 Wellbore name: 0115-S4 Well Header Permit/Concession N° Operator ENI Share(%) Well Configuration type 402100 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(m) Ground Level(m) Water Depth(m) RKB-Base Flange(m) RKB-Tubing Spool(m) 16.22 3.72 11.37 Rig Information Contractor Rig Name Rig Type NABORS ALASKA NABORS 245 E 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) 0115-S4 COMPLETION 47.60 Daily Information End Depth(mKB) End Depth(TVD)(... Depth Progress(m) Drilling Hours(hr) Avg ROP(m/hr) POB Temperature(°C) Weather Wind 5.864.35 0.00 86.0 -39.4 Partly Cloudy.WC- 225'SW @ 10 mph 65' Daily summary operation 24h Summary Completed laying down 5"DP/RIH with 4.5",12.66,L-80 Hydril 563 production tubing/Space out and land production tubing. Operation at 07.00 Testing tubing packer. 24h Forecast Set packer/Test packer/Test IA integrity/Open Mirage plug/Shear GLM valve/Set BPV/Nipple down BOP's/Nipple up tree/Test void/Pull BPV/Install TWCV and test tree and pull TWCV/ Freeze protect/Pull and install shear valve in GLM/Set BPV. 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 04:00 4.00 4.00 COMP K 4 P Continue laying down 5"drill pipe from 4,162'to mule shoe. 04:00 05:30 1.50 5.50 COMP K 20 P Pulled wear ring/Pick up GBR tongs and torque computer equipment/Changed elevators. 05:30 12.00 6.50 12.00 COMP K 4 P Pick up and RIH with 4.5",12.6#,L-80 Hydril 563 production tubing and downhole completion equipment as per completion tally to 1,987'. 12:00 23.00 11.00 23.00 COMP K 4 P RIH with 4.5",12.6#,L-80 Hydril 563 production tubing as per completion tally from 1.987'to 10,235'/Up Wt=89K,Dn Wt ke =62K/Tag at 10,210'/Stop collar at 10,235'/GBR torque turn each connection to average torque 3,600 ft/lbs. 23:00 00:00 1.00 24.00 COMP K 20 P Layed down 5 jts/PU and MU space out and VIT joints. Daily Contacts Position Contact Name Company Title E-mail Office Mobile Eni representative 'Ben Perry Eni Petroleum Sr.Drig.Spur. 907-685-1493 Eni representative Bernie Leas Eni Petroleum Rig Clerk 907-670-8601 907-575-9427 Eni representative Steve Millea ENI Petroleum HSE 907-685-1496 Eni representative Ken Bogner Eni Petroleum Matenals Coordinato Eni representative Greg Parker Eni Petroleum Expediter 907-980-7545 Tool Push Mike Williams Nabors Alaska Drilling Tool Pusher 907-670-1492 Tool Push Matt Vanhoose Nabors Alaska Drilling Tour Pusher 907-670-1492 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(mKB) Bottom(mKB) Run Date LINER 41/2 L80 3,110.83 5.860.69 2/27/2012 Last Leakoff Test Depth(mKB) TVD(mKB) Fluid Type Fluid Density(gIL) P Surf Applied(kgflcm') Eq.Mud Weight(g/L) P LeakOff(kgflcm') 3,191.26 1.133.29 OBM 1102.4 45.7 1505.7 170.6 I Eni E&P Division (well Name:0115-S4 ENI Petroleum Co.Inc. Daily Report Well Code:26195 Field Name:NIKAITCHUQ If* • API/UWW:50-029-23460-00-00 2 II^r, Date:3/3/2012 - Report#: 2 II IIpage 1 of 1 Wellbore name: 0115-S4 Well Header Permit/Concession N° Operator ENI Share(%) Well Configuration type 402100 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(m) Ground Level(m) Water Depth(m) RKB-Base Flange(m) RKB-Tubing Spool(m) 16.22 3.72 11.3.7 Rig Information Contractor Rig Name Rig Type NABORS ALASKA NABORS 245 E 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) OI15-S4 COMPLETION 48.60 Daily Information End Depth(mKB) End Depth(TVD)(... Depth Progress(m) Drilling Hours(hr) Avg ROP(m/hr) POB Temperature(°C) Weather Wind 5,864.35 0.00 81.0 -37.8 Partly Cloudy.WC- 225°SW @ 14 mph 64" _ Daily summary operation 24h Summary RIH with 4.5",12.6 it,L-80 Hydnl 563 production tubing to 10,206'/Land hanger and test/Set BPV I Nipple down BOP's/Nipple up production tree and test/Freeze protect/Prep to move rig. Operation at 07.00 Rig up Halliburton slickline and pull shear valve. 24h Forecast Rig up Halliburton slickline and pull shear valve. Replace with new shear valve. RDMO. Lithology Shows MAASP(kgflcm°) Mud Weight(gIL) 1102.4 Time Log / Start End Cum A (1 /` Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. `V' 00.00 07'00 7.00 7.00 COMP K 4 P Continur RIH with 4.5",12.66,L-80 Hydril 563 production tubing I Tag no go at 10,206'/Perform spaceout and MU hanger assy/Land hanger/Lock down and test upper and lower seals to 5,000 psi for 10 minutes/Pressure up to 1,200 psi down l tubing and close autofll/Continue pressuring up to 3,500 psi and set packer,hold for 30 minutes/Bleed off to 2,000 psi `�--� and apply 2,500 psi on IA,no leaks/Bleed off pressure and apply 4,400 psi to tubing and open Mirage plug I Apply 2.500 psi ans ahear valve in GLM/Set BPV. 07:00 12:00 5.00' 12.00 COMP K5 P Nipple down BOP's/Blow down all lines/Remove kill,choke,and bleeder lines. 12:00 74.30 2.50 14.50 COMP K12 P Install and nipple up production tree/Test void to 5,000 psi,hold for 10 min. 14:30 16:00 1.50' 16.00 COMP K12 P Pull BPV and set TWC/Fill tree with diesel and test to 500 psi for 5 min,5,000 psi for 15 min and chart/Pull TWC I R/D test equipment. 16:00 '18:00 2.00' 18.00 COMP K 20 P Nipple up production tree/R/U flow manifold for freeze protect. 18:00 19:00 1.00' 19.00 COMP K 20 P Prep rig for move/Clean pits,prep mud pumps. 19:00 21:00 2.00 21.00 COMP K 20 P Lirttle Red on location for freeze protect/Wad on diesel truck/Continue to prep for ng move. 21'.00 22:00 1.00 22.00 COMP K 20 P Continue to prep for rig move/B/D choke manifold and test pump/R/U Little Red to freeze protect/Check WEI manifold, diesel in lines. 200 0000 2.00 24.00 COMP K 20 P Pressure lines to 2,500 psi/Bullhead 50 bbls diesel down tubing @ 2 BPM @ 500 psi/Bullhead 100 bbls diesel down IA @ 2 BPM @ 1,200 psi/Rig down Little Red. Daily Contacts Position Contact Name Company Title E-mail Office Mobile Eni representative Ben Perry Eni Petroleum Sr.Dig.Spot. 907-685-1493 Eni representative Bernie Leas Eni Petroleum Rig Clerk 907-670-8601 907-575-9427 Eni representative Steve Millea ENI Petroleum HSE 907-685-1496 Eni representative Ken Bogner Eni Petroleum Materials Coordinato Eni representative Greg Parker Eni Petroleum Expediter 907-980-7545 Tool Push Mike Williams Nabors Alaska Drilling Tool Pusher 907-670-1492 Tool Push Matt Vanhoose Nabors Alaska Drilling Tour Pusher 907-670-1492 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(mKB) Bottom(mKB) Run Date LINER 41/2 L80 3,110.83 5.860.69 2/27/2012 Last Leakoff Test Depth(mKB) TVD(mKB) Fluid Type Fluid Density(gIL) P Surf Applied(kgftcm°) Eq.Mud Weight(gIL) P LeakOff(kgflcm') 3.191.26 1,133.29 OBM 1102.4 45.7 1505.7 170.6 Eni E&P Division Well Name:0115-54 011* ENI Petroleum Co.Inc. Daily Report Well Code:26195 Field Name:NIKAITCHUQ • APIIUW1:50-029-23460-00-00 2^ Date:3/4/2012 - Report#: 3 If II page 1 of 1 Wellbore name: 0115-S4 Well Header PermillConcession N° Operator ENI Share(%) Well Configuration type 402100 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(m) Ground Level(m) Water Depth(m) RKB-Base Flange(m) RKB-Tubing Spool(m) 16.22 3.72 11.37 Rig Information Contractor Rig Name Rig Type NABORS ALASKA NABORS 245 E 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) 0115-S4 COMPLETION 49.60 Daily Information End Depth(mKB) End Depth(TVD)(... Depth Progress(m) Drilling Hours(hr) Avg ROP(m/hr) POB Temperature(°C) Weather Wind 5 864.35 0.00 62.0 -37.8 Mostly Clear,WC- 225'SW @ 13 mph 63 Daily summary operation 24h Summary R/U Halliburton slick line-RIH and put shear valve-RIH and install new ann->tbg 2000 psi shear valve in GLM @ 2,219'-R/D slick line equipment-Prepare and move drill module 40'. Operation at 07.00 R/U slick line over well OP 14-S3 for workover."'FINAL COMPLETION REPORT"'. 24h Forecast Workover on well OP14-S3."'FINAL COMPLETION REPORT"'. Lithology Shows MAASP(kgflcm') Mud Weight(gIL) 1102.4 Time Log Start End Cum Time Time Our(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00:00 05:30 5.50 5.50 COMP R 5 �P R/U Halliburton slick line to change shear valve.Test wire line BOPS to 1000 psi:Ok. 05:30 1 .30 11 00 16.50 COMP R 15 P - 6RIH and set catcher @ 2,525'.RIH and attempt to pull GLM shear valve @ 2,219':three anempts made without success. RIH and pull catcher shear valve was in it(s/n SCG-7419).RIH and set new catcher.RIH with new 1"DCK-2 Ann->Tbg shear @ 2000 psi(SCG-7403)and set in GLM @ 2,219'.RIH and pull catcher(found catcher at-3400'). 16:30 17.30 1.00 17.50 COMP R 5 P 'R/D Halliburton slick line tools and L/D to shed.NO BPV installed in well. 17:30 19.00 1.50 19.00 MOB A 1 'P Secure well bay and cellar.Prepare to move rig.Swap power,B/D steam on drill module,void sumps in pipe shed of H2O. disconnect vac system,ACS glue herculite,remove scaffolding. 19:00 21:30 2.50 21.50 MOB A 1 P Set rig mats,secure all landings and doors,disconnect diesel lines and interconnects. 21:30 00.00 ' 2.50 24.00 MOB A 2 P 'Jack up drill module and set on crib blocks,roll up wind walls and move drill module 40'. Release rig @ 00:00 03/05/2012. Daily Contacts Position Contact Name Company Title E-mail Office Mobile Eni representative Ben Perry Eni Petroleum Sr.DrIg.Spvr 907-685-1493 Eni representative Angelo Lamarina Eni Petroleum Drlg Spvr. angelo.lamarina@enipetroleum.com 907-685-1493 907-903-7269 Eni representative Bemie Leas Eni Petroleum Rig Clerk 907-670-8601 907-575-9427 Eni representative Steve Millea ENI Petroleum HSE 907-685-1496 Eni representative Ken Bogner Eni Petroleum Materials Coordinate Eni representative Greg Parker Eni Petroleum Expediter 907-980-7545 Tool Push Mike Williams Nabors Alaska Drilling Tool Pusher 907-670-1492 Tool Push Mao Vanhoose Nabors Alaska Drilling Tour Pusher 907-670-1492 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(mKB) Bottom(mKB) Run Date LINER 41/2 L80 3.110.83 5.860.69 2/27/2012 Last Leakoff Test Depth(mKB) TVD(mKB) Fluid Type Fluid Density(gIL) P Surf Applied(kgf/cm') Eq.Mud Weight(gIL) .P LeakOff(kgticm') 3.191,26 1,133.29 OBM 1102.4 45.7 1505.7 170.6 O �e � a � `cm ° a322 gg% 22888 "gig ggggW gggi8 VVsss VVVVV ---, Vaasa v.—, VVVVs e.... eve.. g co V° 0 m A N n N 8 N.7(p8 N 5 t:E1Q=pp S A <p N{8{p g p,8.;74 pps{1{1 p�p O 0 N ro(p8 pN A N (A(yy AWAE O1�N 0 i(([yy 0 0 0 0 ..i 0000 I P t00 W 000 000.-.-00 008' .M..g t0 VVVVVV ^W OI O .1N N N A N J NNNNNNNNNN N N N N N NNNNN NNNNN N N N N N NNNNN N N N N N O 00000 00000 00000 00000 00000 00000 nova0 00000 a t7 pppp 'P'SP "IRS pp ((yy p� 4 C "S"8 AOnSA 00rNA' NAOA' 84.NA `�`IRS ODA EDr ANOONB w ggg"46 SS S * wAsas gw g 55588 00.00 pN ON 00 Q0 p000NN NNNNE0 �NO0N�N0.0000 �U)).N NN .....paNN 1000 N m..... 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'� -. 111 _ I c w lir -Ir T, i � umAms 10550 ' Bit Size GR GR@ASCII_Lo Casing Window S/T Protection Casing Amp Casing Window 5 ( in ) 10 0 ( gAPI ) 150 300 ( us ) 2000 40 ( us/ft ) 240 0 ( ) 150 300 ( us ) 2000 Casing Window Casing Window Casing 300 ( us ) 2000 300 ( us ) 2000 Casing 0 Waveform 1 -M SWF1@SWP;1 .IS _C - MINIEli '\n.,n/\, 5 ( in ) 10 300 ( us ) 2000 300 ( us ) 2000 Casing I 5 ( in ) 10 MD 1 : 240 ft Company: ENI Petroleum CO., Inc. Well: 0115-54 Schlumberger FIELD: Nikaitchuq North Slope Borough State: Alaska Date Logged: 15-Jan-2012 Date Processed: 23 Feb - 2012 Elevations: KB: 53.2 ft DF: NA GL: 12.2 ft API Number: 50-029-23460-00 2J \-- $cblumberger Drilling&Measurements MWD/LWD Log Product Delivery Customer ENI US Operating Co.Inc.Alaska Dispatched To: Christine Shartzer Well No 0115-S4 Date Dispatched: 28-Feb-12 Installation/Rig Nabors 245E Dispatched By: Hector Echeto Data No Of Prints No of CDs 0l15-S4 Log 1 2inMD 1 2 in TVD 1 5 in MD 1 5inTVD 1 1 Received By: Malt&A.A, Please sign and return one copy to: D&M,2525 Gambell Street,Suite 400 Anchorage,Alaska 99503 hecheto@slb.com Hector Echeto Fax:907-561-8317 LWD Log Delivery V2.1,03-06-06 Pr') 0111410 2. 11410 Regg, James B (DOA) From: Perry Ben [Ben.Perry@enipetroleum.com] Sent: Sunday, February 19, 2012 10:04 PM j Z-(1.11 (77 To: DOA AOGCC Prudhoe Bay Subject: BOPE used ENI Petroleum 0115-S4 2-19-2012 Attachments: AOGCC.pdf Regards From: Perry Ben Sent: Sunday, February 19, 2012 5:00 PM To: 'doa.aogcc.prudhoe.bay@akaska.gov' Cc: Carballo Nelson; Longo Joseph Subject: BOPE used ENI Petroleum 0I15-S4 2-19-2012 Let me know if there are any questions. Thanks Ben Perry ENI Drilling Supervisor Nabors Rig 245E ENI Alaska Office: 907-685-1493 Cell: 318-613-9377 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 Reporting BOPE use to Prevent the Flow of Fluids from a well ENI Petroleum, Well 01 15-S4, Conductor slot#15 Oliktok point Nikaitchug Project Reservior location#S4,Injector(Schrader Bluff) Nabors Rig 245, 13 5/8" 5000 psi Hydril BOPE Tested 2-11-2012 4c cc c.or}, sj APD Permit to Drill: 211-141 API#: 50-029-23460-00-00 Ben Perry,Drill site supervisor,Office: 907-685-1493, Cell: 318-613-9377 OI 15-S4 well was drilled to a TD of 19,240'MD, 3619' TVD. While drilling production section,mud losses were encountered with a mud wt. of 9.2 ppg while pumping at 450 gpm. Losses were between 30 and 200 bbls per hour at this rate. If pumps were shut off or pump rate was reduced to less than 260 gpm,the well would flow back mud lost in the formation(ballooning effect). Rates of flow back ranged from 30 to 200 bbls per hour. Once TD was achieved, a flow check was performed with three 10 minute checks which produced 80 bbls, 65 bbls and 58 bbls with pumps shut off. Back reaming operations commenced,pulling one stand per bottoms up (1185 bbls). After pulling 180 ft of drill pipe out of the hole,pumping at 450 gpm and loosing mud,the driller noticed that he was gaining mud and flow rate increased from 17%to 23.8%. He spotted a tool joint and closed the t.. .'.- . is . d th- ...e. The gain was approximately 40 bbls and the SICP was 300 psi. SIDPP was zero due to float valves in drillstiing. After 15 minutes of monitoring pressures,the casing pressure dropped to 260 psi. Shut in was monitored for 1.25 hours and AOGCC notified. Using the drillers method,back pressure was held on the casing and a bottoms up was pumped at 354 gpm with 110 psi held on the casing. On the bottoms up, there were no sign of a formation influx, (gas, oil, water,or gas cut mud) noticed. The well was then opened and back reaming operations continued with normal mud losses as before. Respectfully, Ben Perry ENI Petroleum Drillsite Supervisor 2/19/2012 17:00 hrs t IL ASEA 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 Project Manager ENI US Operating Co. Inc. 3800 Centerpoint Drive, Suite 300 Anchorage, AK 99503 Re: Nikaitchuq Field, Schrader Bluff Oil Pool, 0I15-S4 ENI US Operating Co. Inc. Permit No: 211-141 Surface Location: 3163.8' FSL, 1639.8' FEL, SEC. 5, T13N, R9E, UM Bottomhole Location: 5262' FSL, 1986' FEL, SEC. 25, T14N, R8E, UM Dear Mr. Grandi: Enclosed is the approved application for permit to drill the above referenced service 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, 11 1 Dani- . Seamount, Jr. Chair DATED this Io, day of December, 2011. cc: Department of Fish & Game, Habitat Section w/o encl. (via e-mail) Department of Environmental Conservation w/o encl. (via e-mail) STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 I la.Type of Work: 1 b.Proposed Well Class: Development-Oil L Service- Winj U ' Single Zone ❑ 1 c.Specify if well is proposed for: Drill ❑✓ . Redrill El Stratigraphic Test El Development-Gas ❑ Service-Supply El Multiple Zone El Coalbed Gas El Gas Hydrates ❑ Re-entry ❑ Exploratory ❑ Service- WAG ❑ Service-Disp El Shale Gas ❑ 2.Operator Name: 5. Bond: Blanket Q Single Well ❑ 11.Well Name and Number: ENI US Operating Co.Inc. Bond No. RLB0008627 0115-S4 . 3.Address: 6.Proposed Depth: 12.Field/Pool(s): 3800 Centerpoint Drive Suite 300,Anchorage 99503 MD: 19191' ' TVD: 'kaitchuq Schrader Bluff Oil Pool _ 4a. Location of Well(Governmental Section): 7.Property Designation(Lease Number)6•?/�++ /V rf 3163.8 FSL 1639.8 FEL S5 T13N R9E UM ADL 355024 373301 390616,39' $3T Surface: 1�� �,� Topof Productive Horizon: 8.Land Use Permit: 13. oximate Spud Date: 1/ 893 FSL 306 FEL 30 T14N R9EUM ADL 4173-8 04 4 3/29/2012 • Total Depth: 9.Acres in Property: ms CQ Distance to Nearest Property: 5262 FSL 1986 FEL 25 T14N R8EUM • 1280 4/kn�,$221'I.6�t® y�Qdaary 4b.Location of Well(State Base Plane Coordinates-NAD 27): 10.KB Elevation above MSL: •53.2 feet ! Distance toeirest Well Open Surface:x- 516640 • y- 6036517 . Zone- 4 GL Elevation above MSL: • 12 feet to Same Poo• OP1f1 S3 --i/ccs AD /CT" / /7 16.Deviated wells: Kickoff depth: 300 feet 17.Maximum Anticipated Pressures in psig(see 20 AAC 25.035) Maximum Hole Angle: 90° degrees Downhole: 1614 psig •* Surface: 1220 psig •- 18.Casing Program: Specifications Top - Setting Depth - Bottom Cement Quantity,c.f.or sacks Hole Casing _ Weight Grade Coupling Length MD / TVD MD ND (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 2375 35 _ 35 _ 2410 2173 1078 sx 10.7#ASL,230 sx 12.5#Deeperete 12.25" 9-5/8" 40 L-80 Hydril 563 11019 33 33 11052 3779 809 sx 12.5#Deeperete 8.75" 4.5" 11.6 L-80 Hydril 521 8339 10852 3779 19191 3586 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 TVD Conductor/Structural Surface Intermediate _ Production Liner Perforation Depth MD(ft): Perforation Depth TVD(ft): 20. Attachments: Property Plat ❑✓ 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 I Phone 907-865-3320 Date 9/19/2011 Commission Use Only Permit to DrillAPI Number: 2,57/4E,,,,,_,,,,.,,, Permit Approval See cover letter for other Number: �/ 50-Vi.--/ _ 1--C-. Date: OAO \ ,, requirements. Conditions of approval: If box is checked,well may not be used to explore for,test,or produce coalbed methane gas hydrates,or gas contained in shales: / Other: 3.56atL /30f Samples req'd: Yes ElNo[� Mud log req'd: Yes ❑ o LJ hn T C�-:,,) HZS measures: Yes❑ No Directional svy req'd: Yes 2' o❑ �- Z Saa rs 14 l J G(14.; .e r ov. A.«o14 L)/ A to 3C0 CSL € 1'417- Eel r• o1 � ) Dia,..-4-L, u,,Loe.n ' ZO as: a j . / APPROVED BY THE COMMISSION 2-1/�/// AD T./� i COMMISSIONER ORIGINAL f /2.3./( ,,,,'gip '' 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 fir* • Enli■ Petrolleurn eno RECEIVED NOV 21 2011 Alaska Oil & Gas Cans.Commission Anchorage 3800 Centerpoint Drive Suite 300 Anchorage,Alaska 99503 Maurizio Grandi Phone(907)865-3320 Email: Maurizio.Grandi@enipetroleum.com November 14,2011 Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage,Alaska 99501 RE: Application for Permit to Drill InJector 0I15- S4 eZte Dear Commissioners, `'`�""— ` - Eni US Operating Co.Inc. hereby applies for a Permit to Drill for the onshore injector well 0115-S4.This -3-/1 well will be drilled and completed using Nabors rig 245E. The planned spud date could be as early as 2/6/2012. 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 Luca Borri at 907-865-3328. Sincerely, �GY Maurizio Grandi Well Operations Project Manager em us operating WELL 0115-S4 Drilling Procedure 0115-S4 Oliktok Point Conductor slot #15 Reservoir location #S4 Injector (Schrader Bluff) Nikaitchuq Project Drilling Wellolan Paee 1 of 31 11/14/11 O'f* • s open Lu FIng WELL 0115-S4 Oliktok Point Nikaitchuq Field enspeCrr©ku 0I15-S4 North Slope - Alaska DIR/LWD FORM DEPTH HOLE CASING MUD INFO MWD MD TVD SIZE SPECS INFO Cement to Surface 20" Hole Angle 0 X-65 0° 20"Conductor Shoe 160' 160' Driven Welded N/A 0 GR/Res Gr„ surface.% Dir/PWD ui 13-3/8" a 68 lbs/ft MW(ppg) Wellbore Stability Mud Motor B/Permafrost 1903 1778 P L-80,BTC 8.8-9.5 Lost Circulation — w Hole Cleaning `n Casing Sections KOP:325' ' Casing Wear DLS: Surface T'Tail Cement 1906 1780 0-3.5 0/100' Hole Angle 46.41 Deg 13-3/8" 2,411' 2,172' , 16" 50°F WBM GR/RES Neutron/Density/PWD Inter.Casing Wellbore Stability 9-5/8" Lost Circulation Xceed 900 40 lb/ft MW(ppg) Hole Cleaning L-80,Hydril 563 8.8-9.5 Torque&Drag Casing Sections Tangent Angle: ' Casing Wear 85.00 Deg BHA Expense Intermediate TOC 8,366' 3,413' Pick-up Top of Sand • in►tet N Top 9,366' 3,572' Injection Packer 9,852' m v n NOTE:Injectors REQUIRE CBL on Intermediate Casing TOL 10,852' 3,761' a Hole Angle ✓ ►�4 85.00 Deg 9-5/8" 11,052' 3,778' 12.25" 85"F OBM GR/RES Neutron/Density/PWD Wellbore Stability Lost Circulation Slotted Liner Hole Cleaning 4-1/2" Torque&Drag 11.6 lb/ft MW(ppg) Casing Sections Xceed 675 L-80,Hydril 521 8.7-9.4 Casing Wear BHA Expense e' Ll Hole Angle 90.91 Deg 4 1/2" 19,191' 3,586' 8-3/4" 85°F MOBM Drilling Wellnlan Page 2 of 31 1 1/14/11 • 2n0 us operrafing WELL 0115-S4 Table of Contents WELL PLAN SUMMARY 4 MIRU SECTION 5 SURFACE SECTION 6 Surface Drilling 7 Surface Casing 9 Surface Cementing 12 Pick Up Intermediate Drilling Assembly 14 INTERMEDIATE SECTION 15 Intermediate Drilling 16 Intermediate Casing 17 Intermediate Cementing 20 Pick Up Production Drilling Assembly 22 PRODUCTION SECTION 23 Production Drilling 25 Production Liner 26 ATTACHMENTS 28 Health, Safety & Environment 29 Safety Meeting Topics 30 Drillinv Wellnlan Pave 3 of 31 11/14/11 101 en us operafing WELL 0115-S4 WELL PLAN SUMMARY Rig: Nabors 245E Type of Well: v Injector Well Design: 13-3/8"Surface x 9-5/8"Intermediate x 4-1/2"Liner Close Approach and Offset Well Interception Risks It is important to stay as close as practical to the planned directional program. The directional program and a summary of close approaches can be found in the attachments. These close approaches will be in conformance with the minimum well separation criteria detailed by the DrillingAnti-Collision Analysis and Close Approach Guidelines. It is the p Y PP responsibility of the Directional Driller and the Drilling Supervisor to ensure that the directional plan is executed as planned,that the position of the well as it is drilled is monitored on an anti-collision diagram and that no tolerance line for close approach wells is crossed. It is important that the well bore remains close to the planned well path as any major deviations from the profile may adversely affect the ability to drill future wells and still adhere to the current close crossing guidelines. I Survey Program & Procedures Take MWD surveys as frequently as needed,but no less than every 100 ft. Carefully review the anticipated close crossings with existing wellbores and future well paths. Make sure that directional drillers are aware of all drilling close crossing issues,hard lines and no-go lines. If a no-go or hard line has been or will be crossed,stop drilling immediately and contact the Drilling Superintendent to discuss options. Mud Logging Program Mudlogging will be utilized from spud to production hole TD. Refer to the Geological Mud Logging Procedure document. Drilling Wellnlan Page 4 of 31 11/14/11 en o us operrahng WELL 0115-S4 MIRU SECTION OD WT Grade Conn. ID(in) Collapse Burst Tensile Yield (in) (PPO Type (psi) (psi) (kips) 20 178.89 X-65 Welded 18.25 3240 4980 3417 1. Confirm that the identification markings on the conductor match the planned surface location with the "as-built survey." If identification markings are not present on the conductor, contact the Drilling Supt. prior to moving the rig onto the well. ➢ Each conductor is to be marked with a common pad elevation survey mark by the surveyors ➢ Surveyors to also mark each conductor with a degree of angle to set each horizontal wing valve 2. Move in and rig up. Record move distance and rig floor distance to pad and sea level in WellView and on IADC reports. Initiate a Rig Elevation Record and place it on the N drive. • Ensure all concerned parties(Directional Drillers,MWD Operators, and Geologists)are using the same rig floor elevation. 3. Post drilling permit in the rig office and company office. 4. Nipple up the Vetco Gray landing ring,Vetco starter head,the diverter spool,and the annular preventer. Function test the system. D. Notify AOGCC prior to spudding well and 24 hours prior to performing diverter function test ➢ Test lower seals of the starting head to 80%collapse of the pipe,but do not exceed 500 PSI. D. Confirm proper signage is on the pad indicating the rig has diverter equipment rigged up and to restrict access to diverter line area ➢ Place drip berm under the end of diverter line 5. Verify that two 3"threaded nipples have been welded on the conductor on opposite sides. Include ball valves and Cam-Lock male fittings on each nipple. Ensure threaded ball valves can be installed without running into the OD of the diverter head. Nipples are to be used as follows: D. Assist in washing out surface casing hanger on cement jobs D. Take returns to Vac trucks while cementing D. Provide access to annulus for top job through small diameter tubing 6. Build spud mud. Drilling Wellman Pane 5 of 31 11/14/11 2rnn i FIs opera i nns WELL 0115-S4 SURFACE SECTION Surface Formation Markers: (all depths Nabors 245E: Schlumberger Plan (P5) Formation Tops Measured True Vertical Comments Depth, ft Depth, ft SV-4 713 711 SV-3 967 958 SV-2 1251 1220 SV-1 1807 1697 Ugnu Top (UG-4) 2207 2024 UG-2 2945 2478 Lower Ugnu 7214 3231 Flt 01-04 7833 3329 Schrader Bluff 8889 3496 N Seq Top 9149 3538 N Top 9366 3572 N Bottom 9579 3606 N Seq Base 9937 3659 OA Sand Top 10800 3756 OA sb12 11065 3779 T�rillinQ Wellnlan Page 6 of 11 1 I 14 I I us 0perraihng WELL 0115-S4 Surface Close Approach Wells NOTE: It is the responsibility of the Directional Driller and the Drilling Supervisor to ensure that the directional plan is executed as planned,that the position of the well as it is drilled is monitored on an anti-collision diagram and that no tolerance line for close approach wells is crossed. Surface Mud Program: NOTE: Maintain Weight up Schedule as listed below to casing point API Fluid Density 6 RPM Chlorides Interval Depth Loss PH (ppg) Reading (mII30min) (mg/1) 110'— 1800' 8.8 -9.2 20—24 <8 <2000 9.0—9.5 Surface: 1800'—C.P. 9.2—9.5 20—24 <6 <2000 9.0—9.5 Surface Logging/Formation Evaluation Program: MWD Directional/PWD LWD GR/Res Surface Drill Pipe Surface Drilling Surface Hole Notes: • The area around the conductor should be continuously monitored during drilling,circulating,and cementing operations. If broaching occurs,stop drilling immediately. Contact the AOGCC field inspector and the Drilling Superintendent and inform them of the broach. The Conductor Broach Procedure will then be implemented. • Prior to spud,a safety meeting will be held with the rig crews to discuss open hole drilling procedures. Suggested topics include: • Conductor broaching operations and contingencies • Well control procedures and rig evacuation procedures • Flow rates and hole cleaning • Ported float valves are required in all hole sections Surface Hole Procedure: 1. Pick up and drift all DP, HWDP,and DC's for surface section to confirm free of debris. 2. PU BHA(Include UBHO for Single shot E-line Gyro if MWD surveys are not clean initially)for directionally drilling to Surface Casing point with one BHA 3. Directionally drill surface hole: Drilling Wellnlan Page 7 of 11 1 1/14/1 1 111* n11 us operrafing WELL 0115-S4 > Avoid anti-collision boundaries ➢ Take MWD surveys as frequently as needed. Carefully review the anticipated close crossings with existing welibores. Make sure that directional drillers are aware of all drilling close crossing issues,hardlines and no-go lines. If a no-go or hardline has been or will be crossed,stop drilling immediately and contact the Drilling Superintendent to discuss options. 4. Hole conditions will always determine final mud properties. ➢ Watch returns closely for signs of gas when near the base of the permafrost and circulate out all gas-cut mud before continuing to drill. • Due to expected gas hydrates,keep mud as cool as possible(cold lake water). • Control drill at 100 to 120 fph through any troublesome zone so the hole does not load-up with gas cut mud. • Check and report trip gas. • Have 2 ppb Lecithin on location prior to drilling below the permafrost to minimize the effects of hydrates on the mud if hydrates are encountered. 5. Surface casing point: > Landed in good shale found in this area between 2000' SSTVD and 2150' SSTVD ➢ Below the sand at the base of the Sagavanirktok Formation(SV-1). > Inside the upper Ugnu(UG-4). ➢ Drill the footage necessary to leave the appropriate amount of rathole below the casing shoe. 6. Backream out of the hole at surface casing point: > Circulate until shakers are clean. > Backream to the HWDP • Decrease backreaming speed as torque and pump pressure dictate. • NOTE: once backreaming in the open hole has been started,do not stop backreaming until the HWDP. Do not attempt to pull out on elevators once backreaming has started. • If shakers/mud return system become overloaded and flow rate is cut to handle the issue,then do not continue to Backream until the parameters are brought back to full backreaming rate ➢ Once the HWDP is reached,circulate until hole is clean(shakers clean) 7. Pull and lay down BHA. 8. Perform a dummy hanger run before running casing. Surface Casing Program: (all depths feet RKB) OD WT Grade Conn. Cplg OD ID(in) Drift(in) Collapse Burst Tensile Yield (in) (PPO Type (in) (psi) (psi) (kips) 13-3/8 68 L-80 BTC 14.375 12.415 12.259 2260 5020 1556 Drilling Wellnlan Pace 8 of 31 11/14/11 ena us .perraltnng WELL 0115-S4 Surface Casing Connection Make Up Torque (ft.lbs) OD WT Opt. (in) (ppb Grade Conn.Type Make Up Torque 13-3/8 68 L-80 BTC Triangle Surface Casing Casing Running Notes a. Rig up and utilize a Fill Up tool for the casing job. b. Any packing off while running casing,and especially while above the base permafrost,should be treated as a very serious problem if major returns are lost. Contact the Drilling Superintendent if the casing packs off high for discussion of the options. c. Have Vetco representative verify the correct casing hanger is on location prior to the point at which it is needed. d. Torque values for the BTC casing are determined at the rig by making up the connection to the make-up mark (base of triangle). Record torque values for the first 10 connections made up in this manner and average. This average will be used as the make up torque for the remainder of the string. 1. Inspect and drift all surface casing to 12.259". 2. While RIH with the the Casing: ➢ obtain SO Weights )=. obtain PU Weights Drilline Wellnlan Pane 9 of 31 11/14/11 fff* 2n0 FIs operating WELL OI15-S4 3. Run the surface casing as follows: Surface Casing Running Order 1 Float shoe Bakerlock 2 2 joints 13-3/8"68#L-80 BTC casing Bakerlock 3 Float Collar Bakerlock 4 13-3/8"68#L-80 BTC casing ** TAM BTC port collar+/-500 ft Only run if losses are expected 6 13-3/8"68#L-80 BTC casing 7 13-3/8"hanger 8 13-3/8"landing joint **If TAM port collar is run: • A landing joint,which has a connection that can be broken below the rotary table,will need to be run to allow for running the drill pipe inside the 13-3/8"without needing a false rotary table. Also,the drill pipe running tool needs to be on location and stood back in the derrick ready to run in case the TAM port collar needs to be opened to circulate cement to surface. • If decision to run is at the last minute,ensure the additional footage of the port collar plus handling pup will allow for sufficient rathole below the surface casing shoe. Surface Centralizers +1- 18 13-3/8"Tandem Rise Weatherford Drilling Wellnlan Paee 10 of 31 11/14/11 eno• us operating WELL 0115-S4 Surface Centralizer Placement 10' oa 13-3/8"x 16"Tandem Rise Centralizers Collar • 2 at 5'&8' above Float shoe on stop collars,using stop buttons or stop collars. • No centralization on collar of 1"joint. • 1 at 10' above Float Collar,using stop buttons or stop collars. • From 3rd joint through tail slurry(500' tail slurry),1 centralizer per joint run on collars. Do not allow centralizer to float between collars. • 2 on 13-3/8"casing collars,inside conductor @ TD so csg can be reciprocated. 8' Drilling Wellnlan Page 11 of31 11/14/11 en II us operating WELL 0115-S4 Surface Cementing Program Section ! Casing Size Type of Fluid / Cmt Volume Properties Mudpush II 100 bbls Density10.1 ppg Lead Slurry 449 bbls Density 10.7 ppg Surface 13-3/8" (ArcticSet Lite) Yield 2.26 ft3/sk Tail Slurry Density 12.5 ppg (DeepCRETE) 63 bbls 3 Top of Tail @ 1,906'MD Yield 1.54 ft'/sk Surface Cementing Casing Cementing Notes a. Obtain and review the Test Report from the cementing lab on the job blend prior to pumping the cement. DO NOT pump cement if there are any doubts as to cement quality,quantities,pumping times, or thickening times. b. Use split landing joint if TAM port collar is utilized and needs to be opened by running tool on drill pipe. 1. After reaching bottom, rig up and circulate with casing on bottom, if possible, without losing returns. Reduce mud viscosity prior to pumping cement if necessary. 2. Rig up to cement and pressure test cement lines. 3. Pump cement job per the attached Schlumberger cementing plan. ➢ If necessary,verify that the TAM Tech has located the proper crossovers to his combo running tool ➢ If necessary,rack TAM running tool in derrick and ready to run 4. Report the number of bbls of cement returned to surface: ➢ Task one person to be in charge of monitoring for cement returns and volume of cement returns ➢ Recommend that a dye or small amount of celloflake be added to the wash or spacer to give an indication of top of cement. 5. Drop the bottom plug between the lead cement and the mud push. 6. Drop top plug after the tail slurry. 7. Pump displacement 8. Drop circulation rate for last 20 bbls of displacement for bumping plug. 9. Pump until the plug bumps and then pressure up to 500 psi above circulating pressure to ensure the plug has landed. If floats do not hold,maintain final circulating pressure on casing and shut in cement head for a minimum of 6 hours before rechecking. D. Do not over displace the cement(no more than''Athe shoe joint volume). ➢ Watch for signs of packing-off during pumping operations and closely monitor the cellar area for mud or cement returns around the conductor. ➢ In the event cement is not circulated to surface,pump the calculated volumes and prepare to open the TAM Port Collar(if applicable)for a secondary cement job. ➢ AOGCC and Drilling Superintendent must be contacted prior to beginning top job. Do not proceed with top job without AOGCC approval. 10. Drain and wash cement from riser. Nipple down riser and flush all lines. Drilling Wellnlan Page 12 of 31 11/14/11 • evil us operating WELL 0115-S4 11. Nipple up Vetco Gray Well Head,orienting the well head valves as indicated on the conductor markings. ➢ Ensure that the seal between the casing hanger and well head is tested to 5,000 psi for 10 minutes. ➢ Measure the distance from the rig floor to the top flange of the well head and record on the IADC report and in WellView. Complete the Rig Elevation Record and place it in the electronic well folder. 12. Nipple up the 13-5/8"5M BOP stack and test per the AOGCC Permit to Drill(attached) ➢ Test rams and choke manifold components to 3500 psi high/250 psi low V ➢ Test annular preventer to 2500 psi high/250 psi low ➢ Do not test BOPE against casing. ➢ Notify AOGCC 24 hours prior to performing BOP test. • PERMIT TO DRILL requires BOP testing frequency every 14 days unless notified otherwise by AOGCC Drilling Wellnlan Page 13 of 31 11/14/11 ifff* 2rnnn 1soperraC'ng WELL 0115-S4 Pick Up Intermediate Drilling Assembly 1. Install wear bushing. 2. Pick up BHA. 3. RIH to top of float equipment and pressure test surface casing to 2500 psi for 30 min and record on chart. > Plot Casing Pressure Test on LOT form. Verify that the test indicates a linear line and that there is no air entrained in the mud. Repeat Casing pressure test if needed. 4. Drill out the float collar&shoe. 5. Drill 20'-50' of new hole using spud mud. 6. Displace hole to new LSND mud system. 7. Perform Leak Off Test as per AOGCC requirements following the attached LOT Procedure. '---- ➢ PU into casing and perform LOT. > If the pressure continues to rise past 13.0 ppg EMW,shut down and call it a FIT per the FIT Guidelines (attached). ➢ If LOT is unacceptable to drill ahead(i.e.less than 11.0 ppg EMW),contact Drilling Superintendent to discuss options. ➢ Plot on LOT form on N drive. Drillinc Wellnlan Pace 14 of 31 11/14/11 -- emu us oper fins WELL 0I15-S4 INTERMEDIATE SECTION Surface Formation Markers: (all depths Nabors 245E: Schlumberger Plan (P5) Formation Tops Measured True Vertical Comments Depth, ft Depth, ft SV-4 713 711 SV-3 967 958 SV-2 1251 1220 SV-1 1807 1697 Ugnu Top (UG-4) 2207 2024 UG-2 2945 2478 Lower Ugnu 7214 3231 Flt 01-04 7833 3329 Schrader Bluff 8889 3496 N Seq Top 9149 3538 N Top 9366 3572 N Bottom 9579 3606 N Seq Base 9937 3659 OA Sand Top 10800 3756 OA sbl 2 11065 3779 Drillinn Wellnlan Pane 15 of 31 1 1 14 1 1 us . perahang WELL 0115-S4 Intermediate Mud Program: NOTE: Weight up to at least a 9.4 ppg MW by the top of the"N" sand Interval Density PV 6 RPM API FL pH Drill Solids MBT (pp1 Reading (m1/30min) (%) Intermediate: . —9.4' 12-18 12-18 <6.0 9-10 <6.0 <18 Intermediate Logging/Formation Evaluation Program: MWD Directional/PWD LWD GR/Res Intermediate Section Notes: a. If the well is to be an ESP producer,a pump tangent must be placed in the intermediate hole section as per the planned directional profile. The pump tangent must be within 300' TVD from the top of the uppermost OA sand and at least 200' MD in length. b. Shallow test MWD tools. Intermediate Drilling 1. Directionally Drill 12-1/4"hole 2. Casing Point ➢ Land Intermediate casing in 0A2 sand reservoir V 3. Backream at Intermediate Casing point. ➢ Circulate until shakers are Clean ➢ Decrease backreaming speed as torque and pump pressure dictate ➢ Circulate until shakers are clean in the surface casing shoe 4. Pull and lay down BHA. Drillinc Wellnlan Pace 16 of 31 11/14/11 • en0 us operrafing WELL 0115-S4 I Intermediate Casing Program: (all depths feet RKB) OD WT Conn. Cplg OD Collapse Burst Tensile Yield (in) (ppf) Grade Type (in) ID(in) Drift(in) (psi) (psi) (kips) Hydril **Special 9-5/8 40 L-80 563 10.625 8.835 Drift 3090 5750 916 8.75 Intermediate Connection Make Up Torque (ft.lbs) Min. Target Max. OD WT Grade Conn. Type Make Up Make Up Make Up Yield Torque (in) (P11.0Torque, ft- Torque Torque lbs • 9-5/8 ' 40 L-80 H563 1 10,800 13,000 N/A 75,000 **Special Drift casing to 8.75 Intermediate Casing Interval Notes: a. Ensure proper sized rams are installed and tested prior to running intermediate casing. b. Rig up and utilize a casing fill up tool for the casing job. Shoe Track: 1. Have a spare float shoe and collar made up with centralizers and on location ready to go )=. The shoe track joints should be Bakerlocked. ➢ Inspect the float valves as the shoe track is picked up. ➢ Run the shoe track into the well to test and confirm the floats are holding negative differential pressure. Casing Running Order 1 Float shoe Baker-Lock 2 2 joints 9-5/8"casing Baker-Lock 3 Float Collar Baker-Lock 4 9-5/8"Casing 6 9-5/8"hanger 7 9-5/8"landing joint Centralizers +/-38 9-5/8"x 11-3/4"Rigid Hydroforms(Floating) Volant Drilling Wellnlan Page 17 of 31 11/14/11 fo* 2no us operr has WELL 0115-S4 Running Procedure: 1. Inspect and drift intermediate casing(drift 8.75"). 2. Centralizers(See Diagram Below) 3. Pull wear bushing. Install 9-5/8"rams and test. Pick up and run casing. 4. Monitor running speeds to minimize surge and swab pressures while running in or picking up off slips. ➢ Monitor trip tank while running in hole. Reduce speed if decrease or loss of flow is noted. 5. While running in open hole with Casing: ➢ obtain SO Weights 6. Once on bottom with the casing: ➢ obtain PU and SO Weight 7. Run the casing string on bottom. Establish circulation rate and pressure. Reciprocate casing while circulating and cementing. Drilline Wellnian Pace 18 of 31 11/14/11 . en II FIs opereClins WELL 0115-S4 Intermediate Centralizer Placement IIM i 10' 9-5/8"x 11-3/4" Hydroform Centralizers Collar Run 1 Hydroform: • On Stop collar 5'above Float shoe. • No centralizer on next joint oa • On Stop collar 10'above Float Collar. • From 4th joint to+/-1000'above the shoe- 1 centralizer floated between collars • 1 centralizer floated between collars from N sand oil bearing zone to+/-500'above N sand oil bearing zone A , i Al L 5' Drillinn Wellnlan Pane 19 of 11 1 1/14/1 1 w ___ — 2n0 • us operating WELL 0115-S4 Intermediate Cementing Program Section Casing Size Type of Fluid/Cmt Volume Properties Intermediate 9-5/8" Mudpush II 70 bbls Density 10.5 ppg DeepCrete 231 bbls Density 12.5 ppg Top of Cement @ 8,366'MD (831 sacks) Yield 1.56 ft3/sk Intermediate Cementing Intermediate Cementing Notes: a. Obtain and review the Test Report from cementing lab on the job blend prior to pumping the cement. DO NOT pump cement if there are any doubts as to cement quality,quantities,pumping times,or thickening times. If need be,confer with Drilling Superintendent. b. Do not over displace the cement(no more than'A the shoe joint volume). c. For injectors,a cement bond log is required. Prefer to run sonic LWD in production hole BHA and log intermediate casing on trip in hole to drill out intermediate shoe. 1. Perform Rig pump efficiency check and confirm+96%efficiency before pumping and displ c e-cr ent. 2. Ensure Schlumberger re-calculates cement volume based on"N"sand actual de th �' ➢ Cement volume is based on 50%excess and at least 1LKk o ular fill above top of the sand(highest known hydrocarbon bearing zone). 3. Batch mix cement. Test cement lines and pump cement job as per the attached Schlumberger program. 4. Displace cement with rig pumps. ➢ Ensure that the cement unit and rig pumps are manifolded so there will be redundancy in case of any pump failure during displacement. ➢ Pump cement and displace watching for lost returns. Slow rate to during last+/-30 bbls prior to bumping plug. 5. When the plug bumps,pressure the casing to 500 psi over the fmal displacement pressure and ensure that the string is holding pressure. Notify the Drilling Superintendent if the string will not hold pressure. Bleed off pressure and ensure the floats are holding. If the floats leak,pressure back up to final displacement pressure and shut in cementing head. 6. Land casing ➢ Maintain reciprocation as long as possible 7. Install Vetco 9-5/8"packoff assembly. 8. Pressure test packoff per Vetco Gray. ➢ Do not exceed 80%of intermediate casing collapse ➢ Record test on IADC report and in WellView llrillinu Wellnlan Pane 70 of 11 11/14/11 j" j ergo us operrahng WELL 0115-S4 9. Freeze protect 13-3/8"x 9-5/8"annulus to the surface casing shoe. ➢ Pressure limitations are as follows: 80%of surface burst or 80%of intermediate collapse,whichever is less. ■ 2472 PSI is 80%Intermediate casing collapse(9-5/8"40#L-80) ➢ Freeze protect the surface by intermediate annulus with diesel. Pump enough diesel to flush and freeze protect to the surface casing shoe. 10. Install rams and test per the AOGCC Permit to Drill(attached) ➢ Test rams and choke manifold components to 3500 psi high/250 psi low ➢ Test annular preventer to 2500 psi high/250 psi low ➢ Do not test BOPE against casing. ➢ Notify AOGCC 24 hours prior to performing BOP test. • PERMIT TO DRILL requires BOP testing frequency every 14 days unless notified otherwise by AOGCC 11. Install wear bushing. 12. Clean mud pits • Pits must be clean and free of all Barite Drilling Wellnlan Page 21 of31 11/14/11 tfos 2n1 us operaCnns WELL 0115-S4 Pick Up Production Drilling Assembly 1. PU the 8-3/4"bit and the BHA assembly. 2. RIH to the float equipment. ➢ Pressure test the casing to 3000 psi for 30 min and record on chart(AOGCC required casing integrity test). ➢ Plot Casing Pressure Test on the Pressure LOT form. Oil Based Mud Fluid Displacement 3. Displace casing to new Oil Based Reservoir Drilling Fluid ➢ Do not contaminate new OBM in rig pits 4. Drill out the float collar&shoe. 5. Drill 20'-50' of new hole using the Oil Based Reservoir Drill-In fluid. 6. Perform Leak Off Test as per AOGCC requirements following the attached LOT Procedure. ➢ PU into casing and perform LOT. ➢ If the pressure continues to rise past 13.0 ppg EMW,shut down and call it a FIT per the FIT Guidelines (attached). ➢ If LOT is unacceptable to drill ahead(i.e. less than 12.0 ppg EMW),contact Drilling Superintendent to discuss options. �— ➢ Do not pump more than 1/2 bbl after leak off is determined. There is no need to pump more than 1/2 bbl into the leak off and extend the fracture. ➢ Plot on LOT form. Drilline Wellnlan Paee 22 of 31 11/14/11 Efkil en ri• usoperenns WELL 0115-S4 PRODUCTION SECTION Surface Formation Markers: (all depths Nabors 245E: Schlumberger Plan (P5 Formation Tops Measured True Vertical Comments Depth, ft Depth, ft SV-4 713 711 SV-3 967 958 SV-2 1251 1220 SV-1 1807 1697 Ugnu Top (UG-4) 2207 2024 UG-2 2945 2478 Lower Ugnu 7214 3231 Flt 01-04 7833 3329 Schrader Bluff 8889 3496 N Seq Top 9149 3538 N Top 9366 3572 N Bottom 9579 3606 N Seq Base 9937 3659 OA Sand Top 10800 3756 OA sbl 2 11065 3779 Drilling Wellnlan Page 21 of 11 1 1 14 1 1 It* n us operr turns WELL 0115-S4 Production Mud Program: FazePro Density HTHP FL Electrical Interval YP Oil:water Stability (ppg) (m1/30min) mlVolts Production 9.4 14-20 <5.0 65:35 >600 Production Logging/Formation Evaluation Program: MWD Directional/PWD LWD GR/Res Production Section Notes: a. Monitor hole conditions carefully. Be alert for early signs of lost circulation and differential sticking. If any of these problems are observed immediately notify the Drilling Supervisor or Toolpusher(attempt to keep the pipe moving and circulation established). Ensure that all team members are communicating with each other on any observed drilling trends and that everyone understands the potential risks. b. Shallow test MWD tools. c. Keep shut down times to a minimum during connections. When surveying in this hole section reciprocate the pipe slowly while the survey is transmitted uphole. Keep the pipe rotating whenever possible. d. Ensure the Top Drive Torque Limit is set below the lowest make up torque in the string. Do not run the risk of further make up to a connection while drilling. Drilling Wellnlan Page 24 of 31 11/14/11 w _ . 2no us operanns WELL OI15-S4 Production Drilling 1. Directionally drill the 8-3/4"hole to TD. 2. Backream at TD: ➢ At TD circulate hole clean and backream to intermediate casing shoe. • Decrease backreaming speed as torque and pump pressure dictate. ➢ Backream into the intermediate casing shoe. • Decrease backreaming speed as torque and pump pressure dictate 3. Continue backreaming until depth at which it is possible to pull out on elevators at>9.1 swab EMW at 2.5 min/stand 4. Circulate until shakers are clean. 5. Slug DP and trip out of hole on elevators. 6. Lay down BHA f Drilling Wellnlan Page 25 of 31 11/14/11 2no els operr ing WELL 0I15-S4 Production Liner OD WT Conn. Cplg OD Collapse Burst Tensile Yield (in) (PM Type Type (in) !D(in) Drift(in) (psi) (psi) (kips) 4-1/2" 11.6 L-80 HS dl 1 4.695 4.000 3.875 6360 7780 171 Production Liner Connection Make Up Torque (ft-lbs) Min. Target Max. ODiW T Make Grade Conn. Type Torque,Uft- Make Up Make Up Yield lbs Torque Torque Torque 4-1/2" 1 1.6 L-80 Hydri1521 3600 4300 N/A 16000 Production Liner Centralization From To Quantity/Joint Fixed/Floating Type Shoe Liner 1/joint Fixed 4-1/2"x 7" top -Mid joint -Crimped on -Hydroform Production Liner Liner Running Procedure Notes: v tL a. Ensure proper crossover from DP to slotted liner is on the rig floor in case of a well control situation. b. Liner top should be placed a minimum of 200 ft above the intermediate casing shoe. c. Perform visual inspection,measure and caliper all components prior to running any assembly in the hole. Ensure accurate dimensional data is recorded for all equipment run in the well. d. Ensure all equipment has been hydraulically and operationally tested. Also ensure all equipment to be run is dimensionally compatible with all other equipment. e. Review all setting operations and shear pressures with service hand. f. Ensure that all workstring components have been rabbited as ball will be dropped to actuate downhole tools.Rabbit DP on last trip out of prior to running liner. g. If any openhole sidetracks have been drilled,monitor sidetrack depths during run in and ensure shoe enters the correct hole. llrillinv Wellnlan Pave 26 of 11 11/14/11 drook,,, en us operons WELL 0115-S4 Procedure: 1.. Hold Pre job safety meeting to ensure all parties understand operation. 2. PU the Liner Assembly and Running/Inner String. 3. RIH with Liner Assembly. Record PU and SO weights as required. 4. Pick up liner hanger assembly and make up to proper torque. 5. Trip in hole one stand and circulate 5 bbls to ensure all flow paths are free. ➢ Record ROTATE,PU and SO of liner assembly. 6. RIH in hole to casing shoe with DP. RIB with Liner Assembly as hole conditions allow. ➢ Break circulation and fill DP as necessary. 7. Monitor mud flow while running in open hole and slow running speed if necessary. > Circulate minimum of one DP volume and record ROTATE,PU and SO weights. 8. Continue RIH with Liner Assembly to proper setting depth. > Liner should be spaced out to locate the liner top approximately 200 feet above 9-5/8"casing shoe. 9. Prior to setting the hanger&packer,double check all pipe tallies and record amount of drill pipe on location. 10. Rig up to pump down workstring with rig pumps. Pressure test lines. Bleed off test pressure. li 11. Drop setting ball down the workstring and pump slowly. Slow pump before the ball seats. Do not allow ball to slam into ball seat. 12. Pressure up to 3000 psi and hold for 5-15 minutes to set hanger packer. Continue pressuring up in 500 psi increments holding for 5 minutes each up to 4000 psi. 13. Packer can now be pressure tested. Bleed DP pressure to zero,close annular preventer and test annulus to 1,500 psi for 10 minutes and chart. 14. Bleed off pressure and pickup to verify that the running tool has released. If packer did not test,rotating dog sub can be used to set packer. 15. Once running tool is free and packer is tested,Displace mud from liner top to surface with 9.0 ppg KC1 brine 16. POOH and LD and inspect the liner running tools. Drilling Wellnlan Page 27 of 31 11/14/11 Tv* s operrafing WELL 0115-S4 ATTACHMENTS 1. Quarter mile scan report 2. Health,Safety,and Environment 3. Safety Meeting Topics 4. ENI LOT procedure 5. ENI FIT Guidelines Drilling Wellnlan Page 2R of 30 11/14/11 2no f's* us operating WELL 0115-S4 Quarter mile scan report We know that no other wells that penetrate the OA sand reservoir other than those defined herein. Attached is the quarter mile scan report for the 0115-S4 and anticollision report. Health, Safety & Environment The following are part of the mitigation&contingency measures to be put in place in order to complete this project while helping to meet our HS&E goals. It is the Drilling Supervisor's responsibility that these measures are implemented and communicated to the relevant parties on location. Good communication when drilling is essential for increasing the safety of personnel and equipment. H2S Contingency Measures Assume all locations have the potential for H2S. 1. The AOGCC will be notified within 24 hours if H2S is encountered in excess of 20 ppm during drilling operations. 2. The rig will have fully functioning automatic H2S detection equipment meeting the requirements of 20 AAC 25.066. Manual detectors in accordance with 20 AAC 25.065 will also be maintained on location. 3. Self-contained Breathing Apparatus for all rig personnel will be maintained on location. 4. All personnel engaged in the drilling operation will be trained in H2S emergency procedures and the use of proper personal protective equipment. 5. A standard H2S contingency plan will be posted at the rig. All rig personnel should read and familiarize themselves with this document and copies should be posted in the rig floor doghouse and in the camp on location. 6. H2S treating material for the drilling mud system will be available on location in the event that any H2S is encountered. It is expected that the rig and personnel will have the equipment and training to identify and contain a H2S emergency situation. If it becomes necessary to notify the AOGCC of an H,S encounter,drilling will be suspended and will resume only after the development of detailed remedial and contingency procedures,full compliance with 20 AAC 25.065 and the applicable referenced sections of API RP49 and approval of the AOGCC. Lessons Learned Documentation of lessons learned has been proven to reduce downtime and increase efficiency of rig operations. It is expected that planning meetings,daily operations meetings and pre-tour meetings will be held on a regular and consistent basis and that the records of those meetings will be placed on the N drive in the appropriate folder for this well. Drillin2 Wellnlan Page 29 of 30 11/14/11 2no us operafins WELL 0115-S4 Safety Meeting Topics Move In, Rig Up ➢ Prior to spud,a safety meeting should be held with the rig crews to discuss open hole drilling procedures. - Subsidence around wellheads-use of buddy system, - Conductor broaching operations and contingencies, - Shallow gas hydrate drilling practices, - Proper tripping practices and hole fill calculations with various sizes of pipe and tubing, - Well control procedures, - Flow rates and hole cleaning,and - Diverter operation and crew responsibilities. > A'Diverting Shallow Gas'drill should be held with rig crews prior to spud,unless each crew on tour has completed this drill within the past 3 months. Document drill and record on morning report. ➢ An'Accumulator'drill should be held with rig crews prior to spud. Document drill and record on morning report. ➢ Shut-in drills should be held on a regularly scheduled basis. A suggested minimum is once per day on alternating tours. Document and record on morning report. ➢ Check trip tank for leaks and confirm gauges are calibrated. Complete trip sheets and submit to the Drilling Supervisor after each trip. ➢ Perform and document all drills. ➢ Designate crew member to control access at the pad entrance in case of diverter operation. Surface ➢ A'Stripping'drill should be held with rig crews prior to drill out,unless each crew on tour has completed this drill within the past 3 months. Document drill and record on morning report. ➢ A'Well Kill'drill should be held with rig crews prior to drill out,unless each crew on tour has completed this drill within the past 3 months. Document drill and record on morning report. D A well kill sheet shall be posted in the doghouse and updated each tour. Intermediate ➢ Prior to picking up the BHA a safety meeting should be held with the rig crews to discuss hole risks and open hole drilling procedures. ➢ Potential formation pressures and mud weight,Well control procedures. D Hole cleaning best practices,flow rates. D Stuck pipe,Lost circulation. D Proper tripping practices and hole fill calculations with various sizes of pipe and tubing. Production ➢ Potential formation pressures and mud weight,Well control procedures. D Hole cleaning best practices,flow rates. > Stuck pipe,Lost circulation. D Proper tripping practices and hole fill calculations with various sizes of pipe and tubing. Drilling Wellnlan Page 36 of 30 1 1/14/1 1 ENI S.p.A. SPEO IDENTIFICATION CODE PAG 206 OF 338 CMI 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 = P x 10 + 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 EMI 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 Enti 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 Llqure 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 Eno E&P Division REVISION STAP-P-1-M-6140 0 1 (141 LEAK-OFF TEST REPORT Report N° Date: WELL NAME: WELL CODE: CONTRACTOR: RIG NAME: RIG CODE: Open hole depth(m). 825 Mud Twe. FWGELS Rig twe: J.UPs Hole Dameter(in): 17'114 Weight(KgA): 1.3 R.K.B.ele'Let on(m): 26 Last Csg.Shoe(m): 797 Marsh Vlscosity(sec/Ot): 44 Water Depth(m): 24 Csg.diametergn): 131/8 P.V.(cps): 19 Pumps: 12-P-160 Grade: J.55 Y.P.06/100 ft-0): 5 Liners(in): 6.5' Weight Obit): 81 GelsLb/100 tg: 2/8 - Flow rate(bpi): 0.25 Max.Burst pres(psi): 3103 W.L(cc/30 min): 10.5 Litholog y Shale Expected EMW 1.68 Kglcm2/10 m Time Voltrne Pressure Time Volume Pressure Time Vdume Pressure (min) (bid) (Psi) (min) (bbl) (Psi) (min) (bbl) (Psi) 1 025 50 9 2 490 16 2 435 2 050 100 96 2 480 3 0.75 200 10 2 470 4 1DO 300 10.5 2 463 5 125 400 11 2 455 8 150 500 11.5 2 450 7 1.75 570 12 2 445 • 8 200 600 13 2 440 8 2D0 550 14 2 437 8.5 200 505 15 2 435 • Note: Pumped with a constant low rate of(bbl): Volume pumped(bbl): Volume retumed(bbl): (psi) 1000 900 800 stop pump F 700 r - e 600 shut in curve S 500 / S .\--•—•-•-••- -•—H-- • • • 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(bin 41 IP Time mins RESULTS:(Press.,, +Press.Lo.)x10iDepth=[(1.3x797/10)+(430x0.07)]x10/797=1.68(Kg/cm510m) Note: ' I Company Representatiie Figure 15-1 - Leak-Off Test Report 1 SWrnbd'ger 0115-S4(P5)Anti-Collision Report Analysis Method: 3D Least Distance Distance Unit: ft Depth Interval: Every 100.00(ft)Measured Depth Azimuth Unit: deg Step-down Trajectory: Reference Trajectory TC Azimuth Reference: North Analysis Date-24hr Time: September 28,2011-11:46 North Reference: True Analysis Machine: DEC-AKA-980 Client ENI Database I Project: localhost\drilling-nikailchuq Version/Patch: 2.0.960.0 NOTE:Measured Depth is referenced to individual borehole elevation. TVD,NS,EW are referenced to the reference trajectory's wellhead location and borehole elevation. A minimum of 0200 m is always included for borehole diameters. All local minima Indicated. Results filtered:Depth 11050.00 ft<=MD<=19200.00 ft,Ct-Ct separation<=1500.00 ft Anti-Collision Rules Used Rule Set Name D&M AntiCollision Standard S002 v5.1 Exemption Risk Level: Minor Rule Name Risk Level Rule Tvoe Rule Label NoGo Rule SLB Alert Zone Threshold OSF=5.0 S002 v5.1 Alert Ratio OSF=5.00 SLB Minor Risk Threshold OSF=1.5 S002 v5.1 Minor Ratio OSF=1.50 X SLB Major Risk Threshold OSF=1.0 S002 v5.1 Major Ratio OSF=1.00 SLB Surface Rule S002 v5.1 Major Fixed MAS=32.81(ft) SLB Alert Zone Threshold CtCt<=15m S002 v5.1 Alert Fixed MAS=4921(8) • Drilling Office 2.0.960.0 Nikaitchuq\Oliktok Point\0115-S4\0115-54\0115-S4(P5) 9/28/2011 11:46 AM Page 1 of 82 • Reference Trajectory Summary Field: Nikaitchuq Well: 0115-S4 Structure: O0ktok Point Borehole: 0l15-S4 Slot: OP15 Trajectory: 0115-S4(P5) Client: ENI Type: Del Plan Coordinate System: NAD27 Alaska State Plane,Zone 04,US Feet North Reference: True Grid Convergence Angle: 0.12836652° Grid Scale Factor: 0.999900315 Magnetic Declination: 20.614° Magnetic Declination Date: April 02,2012 Magnetic Model: BGGM 2011 Reference Point: Northing Eastina Elevation Structure Unc.11sdl Slot Unc.tledl 6036516.890(WS) 516640.370(ftUS) 52.200(ft)MSL 0.000(ft) 0.000(ft) Tralectory Error Model:ISCWSAO 3-D 95.000%Confidence 2.7955 sigma Survevinst Prost: Description MD From(ft) MD To(ft) EOU Freq(ft) Survey Tool Type Hole Diameter(in) Borehole I Survey 0.000 40.000 1/100.000 SLB_GYRO-MWD-Depth Only-No Global 16.000 0115-S4/0115-S4(P5) 40.000 1350.000 1/100.000 SLB_GYRO-MWD-No Global 16.000 0115-S4/0115-S4(P5) 1350.000 2410.555 1/100.000 SLB_MWD+GMAG-No Global 16.000 0115-04/0115-04(P5) 2410.555 11051.615 1/100.000 SLB_MWD+GMAG-No Global 12.250 0115-S4/0115-S4(P5) 11051.615 19191.362 1/100.000 SLB_MWD+GMAG-No Global 8.750 0115-S4/0115-04(P5) • • Drilling Office 2.0.960.0 Nikaitchuq\Oliktok Point\0115-S4\0115-S4\0115-S4(P5) 9/28/2011 11:46 AM Page 2 of 82 • • Offset Trajectory Summary Offset Selection Criteria: Wellhead distance scan:Global within 60201.86 ft Offset Selection Criteria: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 Selection Summary Wells Selected:57 Boreholes Selected:76 Definitive Surveys Selected:39 Non-Def Surveys Selected:3 Definitive Plans Selected:37 Non-Def Plans Selected:0 Total Trajectories:79 Offset wells whose minimum OSF is less than 1500 are displayed in this report. Trio ct Borehole Well Type Nikaitchuq 1 Nikaitchuq 1 Nikaitchuq 1 Def Survey OP23-W W02 OP23-W W02 OP23-W W02 Def Survey OP18-08PB2 0P18-08PB2 OP18-08 Def Survey 0113-03(P8) 0113-03 0113-03 Def Plan Oliktok Point 1-2 Oliktok Point 1-2 Oliktok Point 1-2 Def Survey OP16-03 OP16-03 OP16.03 Def Survey OP18-08 OP18-08 OP18.08 Det Survey 0PO4-07PB1 0PO4-07PB1 OPO4-07 Def Survey Oliktok Point I-1A-106(P5) Oliktok Point I-1A-108 Oliktok Point 1.1 Det Plan OP05-06 OP05-06 OP05.06 Def Survey OP10.O9 OP10-09 OP10-09 Det Survey OP03-P05P81 OP03-P05P81 OP03-P05 Def Survey S120-N4PB1(P1) S120-N4PB1 S120-N4 Dei Plan SP18-N5(P3) SP18-N5 SP18-NS Det Plan SP36-W5(P2) SP36-W5 SP38-W5 Dei Plan Tuvaaq ST 1 Tuvaaq ST 1 Tuvaaq ST 1 Def Survey OP09-S1 OP09-S7 OP09-S1 Def Survey 0P17.O2PB1 OP17-02PB1 OP17-02 Dei Survey S037-DSP1 current SD37-DSP1 SD37-DSP1 Non-Def Survey SP04-SE5(P2) SP04-SE5 SP04-SE5 Def Plan 0111-01PB1 OP11-01PB1 0111-01 Def Survey Nikaitchuq 3PB2 Nikaitchuq 3PB2 Nikaitchuq 3 Def Survey Oliktok Point 1-2PB1 Otiktok Point I-2PB1 Oliktok Point 1-2 Def Survey 0106-05 current 0106-05 0106-05 Non-Def Survey SP11-N7(P2) SP11-N7 SP11-N7 Def Plan 0107-04 0107-04 0107-04 Det Survey S119-FN2(P2) S119-FN2 5119-FN2 Def Plan SI14-N6(P2) 5114-N6 5114-N6 Def Plan Oliktok Point 1.1 Oliktok Point 1-1 Oliktok Point I-1 Def Survey S129-S2(P2) S129-S2 S129-S2 Def Plan OPOS-06PB2 OP05-06PB2 OP05.06 Def Survey OPO4-07 OPO4-07 OPO4-07 Def Survey SP33-W3(P2) SP33-W3 SP33-W3 Def Plan Nikaitchuq 2 Nikaitchuq 2 Nikaitchuq 2 Def Survey SP1O-FN5(P2) SP1O-FN5 SP1O-FN5 Def Plan 0111-01 0111-01 0111-01 Def Survey SP22-FN1(P2) SP22-FN7 SP22-FN1 Def Plan OP05-06PB1 OP05-06PB1 OP05-06 Def Survey Nikaitchuq 3 Nikaitchuq 3 Nikaitchuq 3 Def Survey Sx34-N Sand(P2) Sx34-N Sand Sx34-N-Sand Def Plan SP24-SE1(P2) SP24-SE1 SP24-SE1 Def Plan OP21-W W01(P3) OP21-W W01 OP21-W W01 Def Plan OP22-W W03(P1) OP22-W W03 OP22-W W03 Def Plan SP3O-W 1(P2) SP3O-W1 SP3O-W1 Def Plan SP16-FN3(P2) SP16-FN3 SP16-FN3 Def Plan OP08-04PB1 OP08-04PB1 OP08-04 Def Survey SP23-N3(P3) SP23-N3 SP23-N3 Def Plan OP12.01 OP12-01 OP12-01 Def Survey S120-N4(P4) S120-N4 S120-N4 Def Plan 0P26-DSPO2 OP26-DSPO2 OP26-DSPO2 Def Survey 0P03-P05 OP03-P05 OP03-P05 Def Survey OP03-P05PB2 OP03-P05PB2 OP03-P05 Def Survey SP05-FN7(P2) SP05-FN7 SPO5-FN7 Def Plan Kigun 1 P81 Kigun 1 PB1 Tuvaaq ST 1 Def Survey Nikaitchuq 4PB1 Nikaitchuq 4PB1 Nikaitchuq 4 Def Survey Nikaitchuq 3PB3 Nikaitchuq 3PB3 Nikaitchuq 3 Def Survey 5117-SE2(P2) SI17-SE2 S117-SE2 Det Plan SI25-N2(P2) S125-N2 S125-N2 Det Plan S135-W4(P2) S135-W4 S135-W4 Def Plan Kigun 1 Kigun 1 Tuvaaq ST 1 Def Survey OP08-04 OP08-04 OP08-04 Def Survey SI08-FN6(P2) S108-FN6 5108-FN6 Def Plan Nikaitchuq 4 Nikaitchuq 4 Nikaitchuq 4 Def Survey Nikatchuq 3PB1 Nikaitchuq 3P81 Nikaitchuq 3 Def Survey S102-SE8(P2) S102-SE6 SI02-SE6 Def Plan 0P18-08PB1 OP18-08PB1 OP18.08 Def Survey SD37-DSP1(P4b) SD37-DSP1 SD37-DSP1 Def Plan 0124-08(P9) 0124-08 0124-08 Def Plan SP01-SE7(P2) SP01SE7 SP01-SE7 Def Plan 0106-05(P9c) 0106-05 0108-05 Def Plan SP27-N1(P3) SP27-N1 SP27-N1 Def Plan S107-SE4(P2) S107-SE4 S107-SE4 Def Plan 0106-05 MWD-Standard 0106-05 0106-05 Non-Def Survey SP12-SE3(P2) SP12-SE3 SP12-SE3 Def Plan Oliktok Point 1-2PB2 Otiktok Point I-2PB2 Oliktok Point 1-2 Def Survey S132-W2(P2) S132-W2 SI32-W2 Def Plan OP14-S3 OP14-S3 OP14-S3 Def Survey 5113-FN4(P2) S113-FN4 SI13-FN4 Def Plan 0120-07(P14) 0120-07 0120-07 Def Plan I Drilling Office 2.0.960.0 Nikaitchuq\Oliktok Point\0115-S4\0115-S4\0115-S4(P5) 9/28/2011 11:46 AM Page 3 of 82 Field: Nikaitchuq Well: OP10-09 Structure: Oliktok Point Borehole: OP10-09 Slot: OP10 Trajectory: OP10-09 Client: ENI Type: Del Survey Coordinate System: NAD27 Alaska State Plane,Zone 04,US Feet North Reference: True Grid Convergence Angle: 0.12874865° Grid Scale Factor: 0.999900316 Magnetic Declination: 21.277° Magnetic Declination Date: January 25,2011 Magnetic Model: BGGM 2010 Reference Point: Northing Ea ting Elevation Structure Unc.(lsd) Slot Unc.11sd) 6036543.170(ftUS) 516689.840(flUS) 53.130(fl)MSL 0.000(ft) 0.000(ft) Trajectory Error Model:ISCWSAO 3-D 95.000%Confidence 2.7955 sigma Surveying Prop: Description MD From(ft) MD To(ft) EOU Freq Survey Tool Type Hole Diameter(in) Borehole I Survey 0.000 40.930 Act-Stns SLB_GYRO-MWD-Depth Only-No Global 16.000 OP10-09/OP10-09 40.930 1016.850 Act-Stns SLB_GYRO-MWD-No Global 16.000 OP10-09/OP10-09 1016.850 2404.150 Act-Stns SLB_MWD+GMAG-No Global 16.000 OP10-09/OP10-09 2404.150 11191.730 Act-Stns SLB_MWD+GMAG-No Global 12.250 OP10-09/OP10-09 11191.730 19146.000 Act-Stns SLB MWD+GMAG-No Global 8.750 OP10-09 I OP10-09 Reference Cylinder North EOU-EOU Intersection MD Reference TVD Reference NS Reference EW Offset MD Offset ND Offset NS Offset EW Azim Ct-Cl Distance Clearance OSFAngle Trace# (ft) (ff) (ft) (ft) (ft) (f) (f) (0) (°) (ft) (ft) (°) All local minima indicated. Results filtered:Depth 11050.00 ft<=MD<=19200.00 ft Results filtered:Ct-Ct separation<=1500.0011 Results highlighted:Ct-Ct separation<=1320.0011 13663.94 3732.85 9847.23 -6022.24 12936.95 3698.02 8896.82 -6675.90 215.93 1154.02 891.16 4.40 3.58 1 13700.00 3733.08 9867.50 -6052.06 12964.90 3696.18 8912.59 -6698.91 216.05 1153.96 891.23 4.40 4.74 1 14490.71 3748.26 10313.09 -6705.09 13768.37 3679.01 9365.89 -7361.40 217.75 1154.31 872.35 4.10 1.65 1 14504.56 3746.30 10320.91 -6716.53 13776.81 3678.84 9370.69 -7368.35 217.69 1154.26 872.49 4.11 1.07 1 14700.00 3738.15 10429.63 -6878.66 13913.96 3680.10 9444.50 -7483.90 216.48 1157.86 876.90 4.13 6.71 1 15760.54 3671.35 10978.22 -7780.68 14996.37 3658.36 10059.56 -8372.36 210.51 1092.78 784.59 3.55 3.10 1 16100.00 3662.89 11147.39 -8074.86 15280.92 364096 10204.76 -8616.41 211.06 1087.34 777.39 3.52 2.98 1 16171.23 3881.11 11182.89 -8136.59 15342.01 3636.22 10234.94 -8689.31 211.23 1087.67 777.32 3.51 2.74 1 16200.00 3660.47 11197.20 -8161.54 15366.92 3634.60 10247.11 -8690.99 211.21 1087.96 777.46 3.51 2.16 1 16600.00 3651.70 11396.15 -8508.44 15742.90 3632.59 10417.99 -9025.66 210.87 1106.66 789.17 3.49 1.99 1 17500.00 3645.83 11841.48 -9290.47 16556.01 3634.24 10747.97 -9768.09 209.87 1193.32 865.01 3.64 5.76 1 18000.00 3630.15 12085.38 -9726.28 17071.71 3628.36 10945.53 -10244.32 209.57 1252.04 908.52 3.65 5.47 1 18600 00 3597 07 12376.98 -10249.47 17693.51 3596.11 11189 53 -10814.90 209.34 1315.20 954.13 3.65 4.15 1 18900.00 3590.31 12523.52 -10511.14 17996.20 3587.59 11318.19 -1108873 209.47 1336.57 967.73 3.83 4.02 1 18191.36 3585.70 12666.05 -10785.22 18264.30 3577.29 11425.70 -11334.07 209.72 1364.80 991.21 3.68 4.76 1 End of results Drilling Office 2.0.960.0 Nikaitchuq\Oliktok Point\0115-54\0115-54\0115-S4(P5) 9/28/2011 11:46 AM Page 14 of 82 Field: Nikaitchuq Well: 0111-01 Structure: Oliktok Point Borehole: 0/11-01 Slot: OP11 Trajectory: 0111-01 Client: ENI Type: Def Survey Coordinate System: NAD27 Alaska State Plane,Zone 04,US Feet North Reference: True Grid Convergence Angle: 0.12869420° Grid Scale Factor: 0.999900316 Magnetic Declination: 21.434° Magnetic Declination Date: October 07,2010 Magnetic Model: BGGM 2010 Reference Point: Northing EaaLlflg Elevation Structure Uncdlsd) Slot Unc.(16d) 6036539.390(ftUS) 516682.790(BUS) 53250(ft)MSL 0.000(ft) 0.000(ft) Traiectory Error Model:ISCWSAO 3-D 95.000%Confidence 2.7955 sigma Surveying Pros: Description MD From(ft) MD To(ft) EOU Freq Survey Tool Type Hole Diameter(in) Borehole I Survey 0.000 41.050 Act-Stns SLB_GYRO-MWD-Depth Only-No Globa 16.000 OP11-01PB110111-01 PBI 41.050 1306.760 Act-Stns SLB_GYRO-MWD-No Globe 16.000 OPI1-01 PB1/0111-011.81 1306.760 2267.280 Act-Stns SLB_MWD+GMAG-No Globa 16.000 OP11-01PB1/0111-01PB1 2267.280 4890.650 Act-Stns SLB_MWD+GMAG-No Globa 12.250 OP1 t-01PB1/0111-01PB1 4890.650 5917.000 Act-Stns SLB_MWD+SAG-No Gleba 12.250 OP11-01PB1/0111-01PB1 5917.000 6317.770 Act-Stns SLB_MWD+GMAG-NO Globa 8.500 OP1 t-01PB1/0111-01PB1 6317.770 10594.000 Act-Stns SLB MWD+GMAG-No Globa 8.500 0111-01/0111-01 Reference Cylinder North EOU-EOU Intersection MD Reference TVD Reference NS Reference EW Offset MD Offset TVD Offset NS Offset EW Azim Ct-Ct Distance Clearance OSF Angle Trace# (ft) (ft) (5) (ft) (II) (ft) (ft) (0) (°) (tt) (5) (°) All local minima indicated. Results filtered:Depth 11050.00 ft<=MD<=1920000 ft Results fittered:Ct-Ct separation<=1500.00 ft Results highlighted:Ct-Ct separation<=1320.00 ft 11051.61 3778.30 8235.57 -3971.73 10594.00 3686.56 7051.43 4234.07 222.27 1216.31 1081.40 907 9.89 1 11071.61 3780.04 8248.37 -3987.00 10594.00 3686.56 7051.43 4234.07 222.27 1225.75 1092.66 927 9.89 1 11100.00 3782.34 8266.53 -4008.69 10594.00 3886.56 7051.43 4234.07 222.54 1239.54 1109.04 956 9,43 1 11200.00 3787.70 8330.26 -4085.56 10594.00 3686.56 7051.43 4234.07 223.60 1291.39 1169.88 10.71 8.14 1 11222.61 3788.32 8344.60 -4103.03 10594.00 3686.58 7051.43 -4234.07 223.86 1303.78 118426 10.99 7.92 1 1130000 3790.05 8393.65 -4162.86 10594.00 3686.56 7051.43 -4234.07 223.86 1348.09 1235.24 12.04 7.92 1 11400.00 379229 8457.03 -4240.18 1059400 3686.56 7051.43 -4234.07 223.86 1409.59 1304.93 13.59 7.92 1 11500.00 3794.52 8520.42 -4317.45 10594.00 3686.56 7051.43 -4234.07 223.86 1475.31 1378.31 15.38 7.92 1 End of results Drilling Office 2.0.960.0 Nikaitchuq\Oliktok Point\0115-S4\0115-S4\0115-S4(P5) 9/28/2011 11:46 AM Page 39 of 82 Field: Nikaitchuq Well: OP08-04 Structure: Oliktok Point Borehole: OP08-04 Slot: OP08 Trajectory: OP08-04 Client: ENI Type: Del Survey Coordinate System: NAD27 Alaska State Plane,Zone 04,US Feet North Reference: True Grid Convergence Angle: 0.12885757° Grid Scale Factor: 0.999900317 Magnetic Declination: 21.564° Magnetic Declination Date: July 08,2010 Magnetic Model: BGGM 2010 Reference Point: Northing Eating Elevation Structure Unc.(lsd) Slot Unc.(1sd) 6036550.670(SUS) 516703.940(ftUS) 53.300(ft)MSL 0.000(ft) 0.000(ft) Traiectory Error Model:ISCWSAO 3-D 95.000%Confidence 2.7955 sigma Surveying Prog: Description MD From(ft) MD To(ft) EOU Freq Survey Tool Type Hole Diameter(in) Borehole/Survey 0.000 41.100 Act-Stns SLB_GYRO-MWD-Depth Only-No Gbba 16.000 OP08-04P81/OP08-04PB1(Projected-Up) 41.100 41.100 Act-Stns SLB_GYRO-MWD-Depth Only-No Globe 16.000 OP06-04PB1/OP08-04PB1 41.100 834.520 Act-Stns SLB GYRO-MWD-No Gleba 18.000 OP08-04PB1/OP08-04PB1 834.520 2261.410 Act-Stns SLB_MWD+GMAG-No Globe 16.000 OP08-04PB1/OP08-04PB1 2261.410 4954.890 Act-Stns SLB_MWD+GMAG-No Globe 12.250 OP08-04PB1/OP08-04PB1 4954.890 8059.610 Act-Stns SLB_MWD+GMAG-No Globe 8.500 OP08-04PB1/OP08-04PB1 8059.610 11240.000 Act-Stns SLB MWD+GMAG-No Globe 8.500 OP08-04/OP08-04 Reference Cylinder North EOU-EOU Intersection MD Reference TVD Reference NS Reference EW Offset MD Offset TVD Offset NS Offset EW Azim Ct-Ct Distance Clearance OSF Angle Trace# (ft) (ft) (ft) (ft) (II) (ft) (ft) (It) (°) (6) (ft) (°) All local minima indicated. Results filtered:Depth 11050.00 ft<=MD<=19200.00 ft Results filtered:Ct-Ct separation<=1500.00 9 Results highlighted:Ct-Ct separation<=1320.00 ft 1105161 3778.30 8235.57 -3971.73 11240.00 3704.87 7670.77 -2896.50 46.68 1218.77 1097.87 10.31 16.18 1 11071 61 3780.04 8248.37 -3987.00 11240.00 3704.87 7670.77 -2896.50 46.68 1236.31 1117.88 10.52 18.18 1 11100 00 3782.34 8266.53 -4008.69 11240.00 3704.87 7670.77 -2896 50 43 32 1264 09 1146.30 10.81 1551 1 11200.00 3787.70 8330.26 -4085.58 11240.00 3704.87 7670.77 -2896.50 30.24 136223 1246.45 11.86 13.20 1 11222.61 3788.32 8344.60 -4103.03 11240.00 3704.87 7670.77 -2896.50 27.08 1384.46 1269.09 12.09 12.69 1 11300.00 3790.05 8393.65 -4162.86 1124000 3704.87 7670.77 -2896.50 2708 1460.65 1346.57 12.91 12.69 1 End of results Drilling Office 2.0.960.0 Nikaitchuq\Oliktok Point\0115-S4\0115-S4\0115-S4(P5) 9/28/2011 11:46 AM Page 64 of 82 Field: Nikaitchuq Well: OP14-S3 Structure: Oliktok Point Borehole: OP14-S3 Slot: OP14 Trajectory: OP14-S3 Client: ENI Type: Def Survey Coordinate System: NAD27 Alaska State Plane,Zone 04,US Feet North Reference: True Grid Convergence Angle: 0.12842137° Grid Scale Factor: 0.999900315 Magnetic Declination: 21.155° Magnetic Declination Date: April 18,2011 Magnetic Model: BGGM 2010 Reference Point: Northing Ea In Elevation Structure Unc.(1sd) Slot Unc.(1sd) 6036520.670(ftUS) 518647.470(ftUS) 53230(ft)MSL 0.000(ft) 0.000(ft) Trajectory Error Model:ISCWSAO 3-D 95.000%Confidence 2.7955 sigma Surveying Prog: Description MD Front(ft) MD To(ft) EOU Frog Survey Tool Type Hole Diameter(In) Borehole/Survey 0.000 41.030 Act-Stns SLB_GYRO-MWD-Depth Only-No Global 18.000 OP14-63/OP14-S3 41.030 922.480 Act-Stns SLB GYRO-MWD-No Global 18.000 OP14-33/OP14-53 922.460 2259.120 Act-Stns SLB_MWD+GMAG-No Global 16.000 0P14-S3/OP14S3 2259.120 10384.510 Act-Stns SLB_MWD+GMAG-No Global 12.250 OP14-S3/OP14-S3 10384.510 21340.000 Act-Stns SLB MWDvGMAG-No Global 8.750 OP14-S3/OP14-S3 Reference Cylinder North EOU-EOU Intersection MD Reference TVD Reference NS Reference EW Offset MD Offset TVD Offset NS Offset EW Azim Ct-Ct Distance Clearance OSF Angle Trace# (ft) (ft) (ft) (ft) (ft) (ft) (ft) (ft) (°) (ft) (ft) (°) All local minima indicated. Results filtered:Depth 11050.00 ft<=MD<=19200.00 ft Results filtered:Ct-Ct separation<=1500.00 ft Results highlighted:Ct-Ct separation<=1320.00 ft 11681.77 3798.27 8635.66 -4458.01 13777.17 3849.39 9512.03 -3734.57 42.03 1137.54 930.40 5.51 2.75 1 11800.00 3798.92 8710.79 -4549.30 13860.09 3845.07 9566.20 -3797.19 41.78 1139.96 92826 5.41 4.18 1 12156.23 3800.85 8937.15 -4824.35 14259.35 3824.55 9821.05 -4103.76 40.67 1140.65 922.42 5.25 2.87 1 12300.00 3796.34 9028.55 -4935.21 14380.57 3819.63 9886.44 -4180.86 40.59 1142.60 918.99 5.13 1.96 1 12400.00 3787.90 9092.00 -5012.03 14430.15 3815.82 9933.05 -4232.37 40.62 1147.17 920.13 5.07 4.35 1 12600.00 3767.53 9218.56 -5165.54 14560.83 3808.45 10024.41 -4325.48 40.63 1164.81 931.47 5.01 7.40 1 14000.00 3740.18 10036.23 -6300.01 16181.46 3811.63 11098.38 -5530.30 37.40 1313.66 1059.20 5.18 2.42 1 14100.00 3742.62 10092.48 -6382.66 16263.36 3811.15 11146.93 -5596.26• 37.28 1317.19 1059.32 5.12 3.03 1 14200.00 3744.54 10148.82 -8465.25 18371.91 3809.88 11211.79 -5683.29 37.25 1321.22 1061.31 5.10 2.69 1 1440000 3745.73 10261.83 -663026 16664.29 379464 11375.70 -5924.79 36.52 1319.39 1059.51 5.09 5.16 1 14504.56 3746.30 10320.91 -6716.53 1689370 3774.95 11488.86 -6123.24 35.60 1310.31 1056.56 5.18 8.59 1 14900.00 3712.83 10538.62 -7044.36 17247.01 3766.67 11645.83 -6439.40 36.39 1262.85 997.03 4.76 8.04 1 15600.00 3671,94 10900.00 -7640.50 17946.51 3732.01 11944.16 -7070.37 31.70 1191.19 910.17 4.25 2.84 1 16000.00 3665.38 11097.55 -7988.20 18291.48 3720.43 12119.10 -7367.42 ' 32.50 1196.65 901.41 4.06 1.62 1 16400.00 3656.09 11296.68 -8334.99 18717.14 3721.09 12327.46 -7738.41 32.95 1192.75 889.83 3.95 2.53 1 16662.34 365033 11427.16 -8562.51 18930.35 3719.16 12437.84 -7920.73 33.07 1199.20 88629 3.84 2.95 1 16700.00 3649.74 11445.90 -8595.17 18960.65 3717.86 12454.22 -7946.20 33.05 1201.05 886.77 3.83 3.51 1 16900.00 3647.28 11545.39 -8788.65 19122.02 3710.42 12543.87 -8080.14 32.77 1214.49 892.79 3.78 5.83 1 17182.04 3644.05 11685.62 -9013.33 19469.96 3690.00 12731.84 -837214 31.73 1227.93 902.83 3.79 434 1 17300.00 3644.67 11743.46 -9116.13 1957434 3682.53 12786.94 -8460.48 31.12 1232.94 903.94 3.76 5.46 1 17800.00 3644.50 11988.31 -9552.04 20149.09 3666.54 13074.74 -8957.41 30.24 1238.71 902.06 3.69 1.44 1 18900.00 3590.31 12523.52 -10511.14 21340.00 3670.78 13581.30 -10033.51 33.35 1163.41 809.90 3.30 5.93 1 19000.00 3588.73 12572.43 -10598.34 21340.00 3670.78 13581.30 -10033.51 33.35 1159.13 793.69 3.18 5.93 1 19100.00 3587.15 12621.35 -10685.55 21340.00 3670.78 13581.30 -10033.51 33.35 1163.46 788.70 3.11 5.93 1 19191.36 3585.70 12666.05 -10765.22 21340.00 3670.78 13581.30 -10033.51 33.35 1174.87 79401 3.09 5.93 1 End of results . Drilling Office 2.0.960.0 Nikaitchuq\Oliktok Point\0115-S4\0115-S4\0115-S4(P5) 9/28/2011 11:46 AM Page 80 of 82 en viol Schlumberger - 0115-S4(P6) 1FIELD Nikaitchuq STRULTUREOIiktok Point Ma9rr Parameters I So4ace L9DRe0n NAD27 Alaska Stets Plane,Zone 06 US Feet `Miar<R1r•Oi• A4114.1 BGGM 2011 OD Bt 046' Date Apn102.2012 Ls(. N 703039.431 Northing 6936516 891915 Grid Cony 0126w55D• Stet OP15 NDRN: Rotary Tabb(52.29 above MSL) May Dec. 20614' F5: 576459n Lan'. W 1495149.794 Eaaeg: 516640321,1)5 Scab Fact 099990031 Plan'. 015-54(.5) 5rvy Deb:September 062011 5132-642 (P2) Tuvaaq ST 1 SP30-W1 (P2) SP30-W1 (P2) SP36-W5 (P2) SP24-SE1 (P2) S129-S2 (P2) OP09-S1 SI35-W4 (P SI17-SE2 (P2) -1 '00 -10110 -8000 -60'' -400, -201' 0 1 ,,Oa Io 1 :aka Kic un 1 "1 '.,'.A ,• S132-V11 46 SP33 643 ('2) At' 14000 - -a; 4C' ► __ 14000 " '-643 P2 .&:0P14-S3 . 10 �' x ( ) ° • .° a• I ' b. 117-SE2 (P2) • OI' ^54 � ' c -W4,44 ° - 12000 - - • ` 12000 �^ P24-SE1 (P2) M-' '� q OP09-S1 SF 36-W5 (P2) �°• `�"q 0113-03 (P6) �• • <°• • Q'9'� ``° ,,.,•, • nr q goo 10000 - ti ti `1.., e� �� , , 10000 ? "b \. �^ �°, `,•` I29-S2 P2) Z O§17-02 `liitik .,V � . ^' OP17-02PB1 4b^^3b� �•4. ;° 4~ Ikii 08-04 N 8000; $�•• ti • b`. • \qC°• ` -�- 8000 ,yh P� • z q • • Ire hh�; E •• •.• b �° X12-0 •. n, ^" ,°cQ yc,°°s..ktok `•int�y. - ° 22.646403 (P1) ii .'''-08�Pla h y� .` ''q5� tip•.• >b• • \gi•• joifT / D ° °., OP14-S3 • 6000 - —�E s - ,.. 6000 co • :-08PB2 ''S� b<'°• .`' '6` ' ^4° • A ,4,�' ,c'°�o•• ^c�°c'°� `` �ro• OP14-S3 '4,‘ ,Sy° b, '''..,'N'<> tt.^ SA • �e5 CP ' ���yy.•c:�ktok P. „qt I-26 :r :000 Tv° • S I, OP26-DSP02 lost'' ,�aO•\ •'s�e�K . ' `,c4o '.,.oho 4000 -4-- q • ."4 ,�' '11)• �ti • •s ±J a.'i .` A 4000 -07(P1it 4o• ,s4 ''', ,, .'• ,�'• -� ,�j'' • • + B1 , c4°• '' �''" ,`, '' 1/4:�° • 6� I OP23-WW02 .., <'•-",• •,,‘, 41°,0 • .is' ti. ••,.;•,,, s tok I-2 9TV, ii6 2000 . � ��7‘11 ‘A" MillaVillf � 2000 1 ff►. �,.'1� OP08-04.81 o 1l1,, ��1 ° . S `1 OP08-04 -X„::.;',-,Z46;7"..,: 1P18-08PB1 -12000 -10000 -8000 -6000 -4000 -2000 ! P °''•3 OP10-09 «< W Scale= 1(in):2000(ft) E >>> OP26-DSP02 Oliktok Point 1-2 OP10-09 Oliktok Point I-2PB1 Oliktok Point I-2PB2 OP21-WW01 (P3) volt EnB ° 3800 Centerpoint Drive Suite 300 Anchorage,Alaska 99503 Maurizio Grandi Phone(907)865-3320 Email: Maurizio.Grandi@enipetroleum.com October 11,2011 Alaska Oil and Gas Conservation Commission ocr ZQI 333 West 7thAvenue,Suite 100 411' Irk Anchorage,Alaska 99501 01/4Gas RE: Application for Permit to Drill Injector 0115-S4 q0�C Dear Commissioners, ENI US Operating Co. Inc. hereby applies for a Permit to Drill for the onshore injection well 0I15-S4.The well will be drilled and completed using Nabors rig 245E. The planned spud date is 03/29/2012. 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, VAi Maurizio Grandi Well Operation Project Manager Enil• Petirolleum 2nll Application for Permit to Drill Saved:4-Oct-11 Application for Permit to Drill Document Injector Well 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(b) 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 25.005(c)(6) 5 7. Diverter System Information 5 Requirements of 20 MC 25.005(c)(7) 5 8. Drilling Fluid Program 6 Requirements of 20 MC 25.005(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 25.005(c)(10) 7 AOGCC PERMIT Document.doc Page 1 of 10 Printed:4-Oct-11 I 1111,1* • Cin Petirolleum 2no Application for Permit to Drill Saved:4-Oct-11 11. Seabed Condition Analysis 7 Requirements of 20 MC 25.005(c)(11) 7 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 10 Attachment 1 Directional Plan 10 Attachment 2 Drilling Hazards Summary 10 Attachment 3 BOP and Diverter Configuration 10 Attachment 4 Cement Loads and CemCADE Summary 10 Attachment 5 Well Schematic 10 Attachment 6 Formation Integrity And Leak Off Test Procedure 10 Attachment 7 Surface Platt 10 AOGCC PERMIT Document.doc Page 2 of 10 Printed:4-Oct-11 • Enil Petirolleum conn Application for Permit to Drill Saved:4-Oct-11 1. Well Name Requirements of 20 MC 25.005(f) Each well must be identified by a unique name designated by the operator and a unique API number assigned by the commission under 20 AAC 25.040(b).For a well with multiple well branches, each branch must similarly be identified by a unique name and API number by adding a suffix to the name designated for the well by the operator and to the number assigned to the well by the commission. Well Name: 0I15-S4 2. Location Summary Requirements of 20 MC 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. (8)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 3163.8 FSL 1639.8 FEL S5 T13N R9E UM ASP Zone 4 NAD 27 Coordinates RKB Elevation 52.2'AMSL - Northing 6036517 ' Easting: 516640.37' • Pad Elevation 12.2'AMSL Location at Top of Productive Interval 893 FSL 306 FEL 30 T14N R9EUM ("OA"Sand) ASP Zone 4 NAD 27 Coordinates Measured Depth, RKB: 11051' Northing: 6044742.7' Easting:512650.6 Total Vertical Depth, RKB: 3778' Total Vertical Depth, SS: 3726' Location at Total Depth 5262 FSL 1986 FEL 25 T14N R8EUM ASP Zone 4 NAD 27 Coordinates Measured Depth, RKB: 19191' Northing: 6049157.5' Easting:5058479' Total Vertical Depth, RKB: 3585' Total Vertical Depth, SS: 3533' • Please see Attachment 7:Surface Platt and (D)other information required by 20 AAC 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; AOGCC PERMIT Document.doc Page 3 of 10 Printed:4-Oct-11 co* • Eni PtIroIkLuIm Application for Permit to Drill Saved:4-Oct-11 Please see Attachment 1: Directional Plan and (2)for all wells within 200 feet of the proposed wellbore (A)list the names of the operators of those wells, to the extent that those names are known or discoverable in public records, and show that each named operator has been furnished a copy of the application by certified mail;or (5)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(BOPS)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 = (3586' TVD)(0.45 - 0.11 psi/ft) = 1220 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 toi 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 AAC 25.0300; Please see Attachment 6: Formation Integrity And Leak Off Test Procedure AOGCC PERMIT Document.doc ✓ Page 4of10 Printed:4-Oct-11 • Enil P 2nn Application for Permit to Drill Saved:4-Oct-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 TVD MD TVD (including stage data) Driven 20" 178.89 X-65 Welded 124 36 36 160 160 pre-installed 1078 sx 10.7#ASL,230 sx 12.5# 16" 13-3/8" 68 L-80 BTC 2375 35 35 2410 2173 Deeperete 12.25" 9-5/8" 40 L-80 56311 11019 33 33 11052 3779 809 sx 12.5#Deeperete • 8.75" 4.5" 11.6 L-80 52111 8339 10852 3779 19191 3586 uncemented liner in open hole p(C 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. ENI requests that AOGCC waive diverter requirements per 20 AAC 25.035. (h). (2). 61< of;kf•(' 0- AOGCC PERMIT Document.doc Page 5 of 10 Printed:4-Oct-11 - Cin�6 Petirolleum o ens Application for Permit to Drill Saved:4-Oct-11 Drilling Fluid Program Requirements of 20 AAC 25005(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 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 st) 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) 13-3/8"Csg Shoe to 9-5/8"Csg Point Value Value Density(ppg) 9.4 Density(ppg) 8.8 - 9.5 Plastic Viscostiy 15 - 25 Funnel Viscosity (CP) (seconds) 45 - 60 Yield Point Plastic Viscostiy (lb/100 sf) 15 - 20 (CP) 12 18 HTHP Fluid loss Yield Point (ml/30 min <5.0 (lb/100 sf) 18-24 200psi& 100°F API Filtrate Oil/ Water (cc/30 min)) 4 6 Ratio 60/ 40 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(t); AOGCC PERMIT Document.doc Page 6 of 10 Printed:4-Oct-11 trot 2nll • Enil Petirolleuim Application for Permit to Drill Saved:4-Oct-11 Not applicable: Application is not for an exploratory or stratigraphic test well. 9. Seismic Analysis Requirements of 20 MC 25 005(c)(10) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (10)for an exploratory or stratigraphic test well,a seismic refraction or reflection analysis as required by 20 AAC 25.061(a); Not applicable: Application is not for an exploratory or stratigraphic test well. 10. Seabed Condition Analysis Requirements of 20 MC 25 005(c)(11) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (11)for a well drilled from an offshore platform,mobile bottom-founded structure,jack-up rig, or floating drilling vessel,an analysis of seabed conditions as required by 20 AAC 25.061(b); Not applicable: Application is not for an offshore well. 11. Evidence of Bonding Requirements of 20 MC 25 005(c)(12) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (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 25005(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 Nabors 245E. 2. Spud and directionally drill 16" hole to casing point as per directional plan. Run Gyro and MWD tools as required for directional monitoring. ,/3. Run and cement 13-3/8", 68#, L80, BTC casing to surface. Pump cement and displace with mud, land casing hanger and bump plug. .4. Install and test wellhead to 5000 PSI. 5. Nipple up 13-5/8" 5K BOP and test to 3500 PSI. Notify AOGCC 24 hrs before test. 6. Pressure test casing to 2500 psi per AOGCC regulations. Record results. 7. PU 12-1/4" bit and directional drilling assembly with MWD, LWD and PWD. 8. Drill out cement and between 20'and 50' of new hole. Perform formation integrity test, recording results. F�1 9. Directionally drill to 9-5/8"casing point per directional plan. Pull out of hole backreaming to the surface casing shoe. 10. Install 9-5/8"casing rams in the BOP and test to 3500 PSI. 11. RU casing drive system. AOGCC PERMIT Document.doc Page 7 of 10 Printed:4-Oct-11 tes • Enil PetiroHeuim en Application for Permit to Drill Saved:4-Oct-11 12. Run 9-5/8", 40# L80, Hydril 563 casing to setting depth. Pump cement and displace with mud. Bump plug with casing on depth. 13. Install 9-5/8" Emergency Slips.- 14. Install 9-5/8" packoff and test to 5000 psi. 15. Flush 13-3/8"x 9-5/8"annulus with diesel freeze protect. 16. Pressure test casing to 3000 psi per AOGCC regulations. Record results. 17. 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. 18. Sonic LWD will be utilized for cement bond logging of Intermediate Casing. 72,L- 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 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 Injection packer and 4-1/2"tubing as required and RIH to depth. Set Injection Packer and Land tubing. Set BPV. 24. Nipple down BOP, nipple up tree and test. Pull BPV. 25. Test IA to 2500 PSI and chart for 30 minutes. • ENI requests that the AOGCC waive surface safety valve requirements pr 20 AAC 25.265. (c). (1). • 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. 644 • Wellhead schematics should be on file with the AOGCC. 26. Freeze protect well with diesel to the base of the permafrost. 27. Set BPV and Move rig off. 13. Discussion of Mud and Cuttings Disposal and Annular Disposal Requirements of 20 MC 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 AOGCC PERMIT Document.doc Page 8 of 10 Printed:4-Oct-11 Ift* • Enil PtIroIkLuIm 2n 11 Application for Permit to Drill Saved:4-Oct-11 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. AOGCC PERMIT Document.doc Page 9 of 10 Printed:4-Oct-11 2nll • Eiroffoit �� Petroll--‘mum Application for Permit to Drill Saved:4-Oct-11 Attachments Attachment 1 Directional Plan Attachment 2 Drilling Hazards Summary Attachment 3 BOP and Diverter Configuration Attachment 4 Cement Loads and CemCADE Summary Attachment 5 Well Schematic Attachment 6 Formation Integrity And Leak Off Test Procedure Attachment 7 Surface Platt AOGCC PERMIT Document.doc Page 10 of 10 Printed:4-Oct-11 0) a m^ M Mr M d m ?-58Z327, w O_w d 'N w M y N N w w w c.7,!888 o b w om m d wr„p r8;V;2 M w b w w1Mrb N W OmCop mOmrbr Ek wNPIhComwq rirmVw'MOd wwbw0 bwbwb bw00h bbbbbOwpob bOMhbwhvibb b14b0 2 a m o rh u?aNmwm8V nobV 'NDON �oNoM t-7-'42A2 NwMm Mrmm^O 81;'82 m 2 2 2 82 C wwrrO ..,mw mwmC wOOh0 Omyp)Od rwv8r0 22 r2 ,8 — '5%111 " NN dwMil w0rnn wwwwm 11 055 YjrNM MMMMr0_N N) O) O gE0ON N N anO b d O ;;838,:,w;;838,:, 8:1:i8:11 w CodmNd O Mw N m M 488'48 wMw w M ;7,2;2'42 N wwWwW ro22- 'rNNN NNNNN NMMMM MM mryrw") d40<8 2.12,%22 O y 7 Co C 0 N .r W_NC 1,i : :,:,:,:, < x Co 7 0O C: O0 00 00 N0 N� 6-44g18 dNmNnN 0M 8242,Q NdOM 28822, CM MM NO oO w NaNMNo d v MOMo 0el dNComrd dm !!:6,!F,w0jd0 ik O E C L j 0o N�N�0M M00oi 0ry0 pCr.)> F0N0p NM54,''%1 )M MM.00 A+ CD 06 03 MI vz c ggAg E wwS ww=w w 22222 wwdKh% KK 0)0)0)0)0) Is - M MMM M 3,7“8 of°'p>N Nrcd MN N'oo m d N N N N N N N N v J z N C o J wJ ONOC 7dC EY WtO' N NN °.-"" M"1/1 N wm0rs1 N;r Mg. gNm 322O4 c CA UORCCN' om00 andCMmmwmr —w: OChrV M mVV<,NVM0 NMN 43"°'14dN« "'-'U iF,MgmN 'b mp<OrwmNw Cl). 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BGGM2011 Dp. 81.046' Date 66602.2012 Let N 70 3039 431 Northing. 6036516.898US Grad Com:0.12836652' Slot OP15 IVO Ref Rotary Table(52.21tabeve MSL) Meg Dec. 20.614' FS 57645 WIT Lon'. W 1495149.794 Ea6e9 516640.37 BUS Scale Fan.099900031 Plan. 0115-S4(P5) OPS Date September 08,2011 -10000 -8000 -6000 -4000 -2000 0 14000 14000 0115-S4(P5) TO End Cry 54 Tgt 14 Cry 2/100 End Cry 12000 End Cry/ SlTgt 12 r 12000 54 Tgt 15 � Cry 2/100 Cry 2/100 End Cfv End Civ .N Sd Tgt 13 _ S4 Tgt 10 One 2/100 Cry 2/100 End Cry End CryS4 Tgt 8 Sd Tgt 11 Cry 2.6/100 —.lair' Cry 2/100Eng CryEntl Cry S4Tgt 9: • 3CTgt6 Civ 2/100 Cry 2/100 End Cry • End Cry 10000 04.T9t.7- 54'Tgrd r"•• 0 10000 Cry 2.5/100 • Cry 2/100 End Cry • End Cry S4Tgt5 54 Tgt2 Cry 2/100 Cry 2.5/100 End Cry $4 Tgt 3 E 3d Cry CM 2.5/100 • Cry 2.5/100 A End Cry End Cry A S4 Tgt 1 A 8000 o Cry2.5100 0 8000 Z 95/8" S4 Heel Cry 2.5/100 O O O N c.:-..... II N 6000 0".'- 6000 S co to V V V 4000 < 4000 / 2000 << d 2000 End Cry 134/8" RTE 0 Cry J,S/104 ...... - 0 Div 0.5/100 Bid 3/100 KOP Bld 1.5/100 -10000 -8000 -6000 -4000 -2000 0 «< W Scale=1(in):2000(ft) E >>> Schlumberger OI15-S4 (P5) Anti-Collision Summary Report Analysis Date-24hr Time: September 13,2011-14:37 Analysis Method: Normal Plane Client: ENI Reference Trajectory: 0115-S4(P5)(Def Plan) Field: Nikaitchuq Depth Interval: Every 5.00 Measured Depth(ft) Structure: Oliktok Point Rule Set: D&M AntiCollision Standard S002 v5.1 Slot: OP15 Min Pts: All local minima indicated. Well: 0115-S4 Borehole: 0115-S4 Offset Trajectories Summary Offset Selection Criteria Wellhead distance scan: Global within 60201.86 ft 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 OP16-03(Def Survey) Warning Alert 150 1 35 5.53 0.00 0.00 CtCt<=15m<15.00 Enter Alert 7 99 6.76 1 35 5. 14.11 14.11 MinPt-0SF 7.29 3.41 0.6� 454.15 454.12 MinPts • 7 47 3.27 0.83 1.49 484.12 484.06 MinPt-O-EOU • 7.63 3.30 0.9.EllMaE 494.10 494.02 MinPt-O-SF 8.12 3.43 1.4814 514.05 513.92 MinPt-O-SF 35.86 22.91 17.. EI : 815.54 811.64 MinPt-O-SF 89.92 44.16 31.•.mom 1004.27 992.94 MinPt-OSF - 270.87 215.50 188.44 4.98 1642.87 1558.84 OSF>5.00 Exit Alert 7942.35 7737.86 7636.1.MEM, 9466.96 3587.96 MinP1-0SF 7328.23 7111.61 7003.:...mo00 10412.48 3718.55 MinP1-0SF 7325.3• r�r r" 34.00 10453.41 3723.02 MinPts MEM 7108.92 7001.20 34.00 10454.40 3723.13 MinPt-CtCt MIME 6802.00 6666.32 26.07 13817.54 373574 MinPt-CtCt 7075.28 6801.07 6664.46 25.89 13892.52 3737.57 MinPt-O-EOU �707619 6801.2 '6664.225.82 13922.50 3738.29 MinPt-O-ADP WIT 19191.36 3585.70 MinPts OP14-S3(Def Survey) Warning Alert 8 04 6.82 1.37 5.57 0.00 0.00 CtCt<=15m<15.00 Enter Alert =M}j 5. .MERE 2.88 243.97 243.97 MinPts 7.74 4.80 1.07 2.22 373.94 373.94 MinPts 7.97 4.59 1.30 1.99 451.32 451.29 MinPt-O-EOU 9.71 4.89 3.04 111.1350 548.49 548.25 MinPt-O-SF 12...1® 2.51 1.96 652.94 651.96 MinPt-O-EOU 12.77 5.361MEIEE 1.87 692.70 691.23 MinPt-O-ADP 13.91 5.6011.' 1.79 747.33 744.97 MinPt-O-ADP 14.19 5.71 2..:1 757.25 754.70 MinPt-O-SF 50.64 33.441 3.09 1345.77 1304.50 MinPt-O-ADP 54.17 35.35 26. iril 1399.20 1350.81 MinPt-OSF 113.81 89.94 7862 4.97 2156.80 1985.16 OSF>5.00 Exit Alert 514.53 468.38 445.8.11111111111111 3464.71 2836.47 MinPt-O-SF 592.04 538.81 512.6.® 3672.38 2669.39 MinPt-O-SF L 1137.541930.57 827.57 5.52 11878.11 3798.24 MinPt-CtCt 1138.02 930.0 826.60 5.49 11718.10 3798.47 MinPt-O-EOU 1140.73 930.75 826.261 5.45 11802.88 3798.93 MinPt-O-ADP 927.11 820.21 5.34 12002.52 3800.04 MinPt-CtCt 1140 60�921�.5}6� 812.54 5.23 12177.61 3800.75 MinPt-CtCt 1141.30 ME.:y�', 811.16 5.20 12237.46 3799.41 MinPt-O-EOU 1142.15 921.06 :®. 5.18 12267.39 3798.15 MinPt-O-ADP 1153.55 928.85 816.9.I4 12436.63 3783.98 MinPt-O-SF • 1252.16 1015.54 897.7 ® 13090.04 3752.54 MinPt-O-SF 1062.70 938.62 5.28 13868.95 3736.99 MinPt-CtCt 131284 106 65 5.24 13951.54 3739.00 MinPt-O-EOU 1314.91 1062121 5.22 14016.48 3740.58 MinPt-O-ADP 1320.83 EIMME, 936.34 5.16 14165.98 3744.15 MinPt-O-EOU 1317.75 1053.25 921.50 5.00 14468.30 3746.13 OSF<5.00 Enter Alert 90920 768.72 4.24 15622.61 3672.10 MinPt-CtCt 1194. +• 903.931 759.21 4.12 15898.29 3667.92 MinPt-O-EOU 890.69 740.18 3.96 16381.75 3656.49 MinPt-CICt 1194.9.1 737 36 3.92 16521.66 3653.42 MinPt-O-EOU 1126.64 905,66 ] 3.81 16576.64 3652.21 MinPtO-ADP 1226.• 905.66 745 75 3.83 17115.85 3644.83 MInPt-0-EOU 1227.32 905.72® 3.82 17145.66 3644.27 MinPI-0-ADP 1228.66 906.51 745 93 1 17180.93 3644.05 MinPt-O-SF MiliEDIE=ZEIE 18999.67 3588.73 MinPts 0113-03(P6)(Def Plan) Warning;Alert 16.04 15.05 15.05 N/A 5.00 5.00 CtCt<=15m<15.00 Enter Alen I 15.49 11.81 10.46 5.37 429.85 429.83 MinPt-CtCt 15.82 11.50 9.84 4.45 484.77 484.71 MinPt-O-EOU 16.3. 11.50 9.60 4.02 514.76 514.83 MinP1-0-EOU 16.89 11.62 9.48 3.71 539.77 539.56 MinPt-O-ADP 22.38 14.81 11.52 3.25 665.05 663.93 MinPt-O-SF 26.01 17.40 13.6 3.2 720.32 718.44 MinPt-O-SF 109.89 87.06 76.13 498 1404.74 1355.57 OSF>5.00 Exit Alert 528.28 458.00 423. •1 3680.97 2670.76 MinPt-O-SF Drilling Office 2.0.960.0 Nikaitchuq\Oliktok Point\0115-S4\0115-S4\0115-S4(P5) 9/13/2011 2:38 PM Page 1 of 13 • Offset Trajectory Separation Allow Sep. Reference Trajectory Separation Factor Alert Status Ct-C1(ft)I EOU(ft) Dev.(ft) Fact. MD(ft) I TVD(ft) Alert I Minor I Major 2919.99 2700.30 2590.9 13.35 1029326 3704.90 MinPt-O-SF 2918.18 2698.91 2589.7 13.36 10402.69 3717.47 MinPt-0-ADP 2918.01 2698 87 2589.79 13.37 10420.98 3719.49 MinPt-O-EOU t 2917.76 2699.22 259045 13.41 10494.19 3727.37 MinPt-CtCt 2615.27 2347.58 2214. -�:; 13092.00 3752.49 MinPt-O-SF 2614.56 2347.28'.u' ° 9.81 13128.84 3751.57 MinPt-O-ADP 2564.96 2289.95 2152.94 9.36 13721.01 3733.42 MinPt-CtCt 2565.4. 2289.4. 2151.87 9.32 13769.99 3734.58 MinPt-O-EOU 2566.15 2289 5,;fir' 9.31 13794.96 3735.19 MinPt-O-ADP 2566.49 2289.66 MIME 9.30 13804.94 3735.43 MinPt-O-ADP 2616.44 2325.75 2180.,' 14493.12 3746.28 MinPt-O-SF 2648.50 2349.82 2200.9: 8 891 15171.70 3678.40 MinPt-OSF I 2649.41 2349.28 2199.71 2199.71 -8.85 15674.58 3672.40 MinPt-CtCt 2652.9 2345.11 2191.71 8 64 15914.87 3667.50 MinPt-0-EOU 2653.92 2345.2_11 2191.40 8.62 15947.83 3666.68 MinPt-O-ADP 2719.19 2394.39 2232.4 8 39 17144.10 3644.29 MinPt-0SF 2767.85 2436.52 2271.35 8.3 17668.12 3646.81 MinP1-0SF 2918.41 2562.85 2385.56 8.2 19191.36 3585.70 MinPt-O-SF OP17-02P51(Def Survey) Warning Alert 1 15.97- 14.751 2.93 1205 0.00 0.00 CtCt<=15m<15.00 Enter Alert 15.98 14.75 2.94 1204 23.95 23.95 MinPt-OSF 16.46MIIM 3.42 7.28 188.94 188.94 MinPt-O-EOU 16.64 MO= 3.60 6.77 208.93 208.93 MinPt-O-EOU 22.51 17.77 9.47®" 398.53 398.53 MinP1-0SF 49.06 41.27 36.02 6.14 634.22 633.42 CtCt<=15n1 15.00 Exit Alert 70.98 60.76 56.261 1 744.58 742.27 MinPt-O-SF 170.56 142.31 128.80] Irel 1136.88 1116.83 MinPt-O-SF 206.54 172.51 156.11 i3Ficl 1264.51 1232.69 MinPt-O-SF 219.83 183.72 183.72 166.2 1308.89 1272.11 MinPt-O-SF 1 5005.1 4789.06 4681.57 23.28 10259.78 3700.90 MinPt-OtCt 5005. 4789.061 4681. 23.27 10264.02 3701.41 MinPts 5005.09 4789.11 4881.61 23 2711 10272.50 3702.43 MinPt-O-SF 3881.19 3730.35 13.86 15708.04 3672.25 MinPt-CtCt 4184.6 MIZI= 3728.81 13 80 15739.70 3671.80 MinPt-O-EOU 4185.93 3880.7-Wan 13.76 15759.83 3671.37 MinPt-O-ADP 4201.08 3886.. 13.37 16153.98 3661,54 MinPt-O-ADP 4208.41 3888.66 3729.28 13.20 16348.23 3657.22 MinPt-O-EOU 4210.60 3889 1..MEC1M 13.13 16418.19 3655.69 MinPt-O-ADP 4300.40 3960.15 3790.5.MIKE 17175.11 3644.06 MinPt-0SF 4351.161 3992.63 3813.85 12.17 17980.08 3631.90 MinPt-0-EOU 435241 3992. 3813.61 12.14 18020.06 3628.38 MinPt-0-ADP 4497.60 4107.42 3912. 11.551 19191.36 3585.70 MinPt-O-SF OP12-01(Def Survey) Warning Alert 40 02 38 79 7.7 31.69 2.62 2.62 CtCt<=15m<15.00 Enter Alert 39.48 35 95 7.2 10.83 332.49 332.49 MinPts 39.87 35.15 7.59 8.19 437.27 437.26 MinPt-O-EOU 40.9 35.421 8.71 7.15 507.16 507.05 MinPt-O-EOU 53.82 32.17 21. ' 880.48 874.59 MinPt-O-SF 61.361 27.94 11.84 1.87 1022.83 1010.48 MinPt-O-EOU 90.27 32.32 3.961 1.571 1350.20 1308.37 MinPts 204.471 140.21 108.57 3.22 2706.82 2357.96 MinPt-O-EOU 204.69 140.2 108.521 3.21 2757.23 2385.65 MinPt-O-ADP 205.441140.5 108.59 3.20 2904.78 2459.63 MinPt-0-EOU 205.16 140.21 108.2 3.1 3007.88 2504.84 MinPt-0-SF 204.97 1401 108.1 3.19 3038.33 2517.13 MinPt-O-ADP 204.8 140.0 108.21 3.20 3058.48 2525.00 MinPt-O-EOU 1 204.5 140.50 108.97 3.23 3123.06 2548.78 MinPt-CtCt 236.69 188.20 164.45 4.96 3446.09 2633.38 OSF>5.00 Exit Alert 1210.59 1072.19 1003. : 88] 7151.86 3220.97 MinPt-O-SF • 2265.111 2056.161952.18 10.89 10053.02 3674.69 MinPt-O-EOU 2266.18 2056 50 1952.15 10.85 10319.51 3707.98 MinPts 1883.50 1630.56 1504.58 7.47 13127.81 3751.60 MinPt-O-SF I1803.401 1548 151 142102 7.09 13546.06 3735.23 MinPts Oliktok Point l-2PB1(Def Survey) Warning Alert 128.52 127.44 95.71 118.21 0.00 0.00 Surface 1-128.521 127.'•IMMO 118.21 40.00 40.00 MinPts 9762 76.97 64.81 4.68 4.68 962.72 953.49 OSF<5.00 Enter Alert 95.66 73.53 62.Bry 4.271 987.73 977.27 MinPt-OF 70.08 32.92 14.88 1 91 1307.33 1270.73 MinPts 69.97 32.89 14.89 l 91 1312.34 1275.15 MinPt-O-EOU 1 69.69 33.30 15.64 1 94 1337.41 1297.19 MinPt-CtCt 78.98 57.01 46.17 3 5511 1496.42 1434.13 MinPt-O-SF 8478 66.65 51.97 4 62 1545.67 1476.18 05605.00 Exit Alert 138.49 119.19 105.6:MEE 1906.62 1780.92 MinPt-O-SF 600.35 546.67 520.3-man 3158.36 2560.82 MinPt-0-SF 2505.32 2384.37 232439 20.88 5993.21 3037.30 TD Oliktok Point 1-2(Oaf Survey) Warning Alert 128 52 127 44 95.71 118.21 0.00 0.00 Surface II 128 5211 127 4-( 118.21 40.00 40.00 MinPte 97.62 76 97 64 81 4.68 962.72 953.49 OSF<5.00 Enter Alert 95 66 73 53 62 86 4 27 987.73 977.27 MinPt-O-SF 70.08 32.92 14.881 1.911 1307.33 1270.73 MinPts 69 971 32.89 14 89 1 91 1312.34 1275.15 MinPt-O-EOU Drilling Office 2.0.960.0 Nikaitchuq\Oliktok Point\0115-S4\0115-S4\0115-S4(P5) 9/13/2011 2:38 PM Page 2 of 13 Offset Trajectory Separation Allow Sep. Reference TrajectorySeparation Factor Alert Status Ct-Ct(ft) EOU(ft) Dev.(ft) Fact. MD(ft) 1 TVD(ft) Alert I Minor I Major 69.69 33 30 15.64 1.94 1337.41 1297.19 MinPt-CtCt 78.98 57.01 46.1 E 1496.42 1434.13 MinPt-O-SF 84.78 66.65 51.97 4.62 1545.67 1476.18 OSF>5.00 Exit Alert 138.49 119.19 105.6 511E 1906.62 1780.92 MinPt-O-SF 600.35 546.67 520.3.IIIIIIIIEEZ 3158.36 2560.82 MinPt-0SF 2669.67 2540.48 2476. • ECEE 6325.44 3089.96 MinPt-0SF 3705,76 3489.24 3381.47 17.19 10287.41 3704.21 MinPt-CtCt 3705.77 3489.231 3381. 17.19 10303.79 3706.14 MinPts 3705.79 3489.25 3381.4 17.1 10320.17 3708.06 MinPt-0-SF I 3143.35 2869.83 2733.57 11.5 13930.41 373849 MinPts • Oliktok Point I-2P82(Def Survey) Warning Alert 128.52 127.54 95.71 129.58 0.00 0.00 Surface ®I 127. .NEM 118.21 40.00 40.00 MinPts 97.62 76.98 64.81 4.68 962.72 953.49 OSF<5.00 Enter Alert - 9566 73.53 62. 4.2 987.73 977.27 MinPt-O-SF , 70.08 32.93 14.89 1.91 1307.33 1270.73 MinPts 69.97 32.90 14.90 1.91 1312.34 1275.15 Mink-0-EOU 1 69.69 3330 15.65 1.94 1337.41 1297.19 MinPt-CtCt • 78.98 57.02 46.1 ZIE 1496.42 1434.13 MinPt-O-SF 84.78 66.66 51.97 4.62 1545.67 1476.18 OSF>5.00 Exit Alert 138.49 119.19 105.6.® 1906.62 1780.92 MinPt-O-SF 600.35 546.67 520.3 ® 3158.36 2560.82 MinPt-O-SF 2669.67 2540.48 2476.3.®r 6325.44 3089.96 MinPt-O-SF 3505.60 3318.56 3225.5 18.84 8777.76 3478.71 MinP1-0SF 0120-07(P12)(Def Plan) Warning Alert 48.02 46.80 15.21 38.23 0.00 0.00 CtCt<=15m<75.00 Enter Alert 48.02 45.38 15.21 17.74 250.00 250.00 MinPts 48.52 44.58 15.71 12.02 450.12 450.09 MinP1-0-E00 49.17 44.81 16.36 10.99 479.90 479.84 CtCt<=15m>15.00 Exit Alert 57.50 51.47 24.69 MEM 578.02 577.63 MinPt-0-SF 62.85 56.27 30 0.,MIKIM 611.93 611.32 MinPt-O-SF 87.95 78.97 551,mom 721.46 719.55 MinPt-O-SF 120.85 108.75 88.04 9.89 823.08 818.98 MinPFO-SF 168.90 152.15 136.09®" 938.64 930.49 MinPt-O-SF 223.35 201.18 190.54 MIER T 1044.65 1031.01 MinPt-O-SF 394.47 354.97 335.83 MEEE 1291.38 125662 MinPt-0-SF 442.94 398.58 377.01,M= 1347.92 1306.37 MinPt-O-SF 5447.25 5306.37 5236.4 - 6594.66 3132.64 MinPt-0-SF • 8686.72 8510.28 8422.56.MM 8134.25 3376.70 MinPt-0-SF 8712.10 8535.13 8447.1 - 8166.10 3381.75 MinPt-0-SF 8718.51 8541.41 8453.3 - 8173.67 3382.95 MinPt-O-SF 8877.05 8697.47 8608.1>- 8308.77 3404.36 MinPt-0-SF 7344.91 7117.68 7004.5 - 11223.11 3788.33 MinPt-0-SF 8289.52 8033.89 7906.5 12400.20 3787.88 MinPt-0-SF 8496.99 8227.6 •IIIIIIIIlan 31.66 13633.82 3733.01 MinPt-O-ADP 8721.5 MIME 8289.06 30.32 14672.88 3740.26 MinP1-0-EOU 8436.24 8009.87 7797.17 19.83 19191.36 3585.70 TD SP33-W3(P2)(Def Plan) Warning Alert 17869.7 1 17866 2.7 17830.9 5077.93 325.40 325.40 MinPts 17871.87 17870.65 17839.06 14600.70 0.00 0.00 Surface 1241.07 987.42 863.51 4.98 17902.30 3638.54 OSF<5.00 Enter Alert 293.49 12565 43.32 1.761 18778.67 3592.23 MinPt-0-SF 272.09 117.66 41.77 1.78 18840.27 3591.26 MinPt-O-ADP I 205.391 78.07 14.91 1.621 19191.36 3585.70 MinPte OP10-09(Def Survey) Warning Alert • MZESI 54.801® 44.76 4.07 4.07 MinPte 58.42 MZEI 23.61 26.42 199.07 199.07 MinPt-0-EOU 96.11 75.71 63.30 485 843.83 839.13 OSF<5.00 Enter Alert 99.72 77.62 66.91 11.11.3M. 868.38 862.90 MinPt-OSF 137.76 100.61 82.6 MIIMIC01 1066.50 1051.48 MinPt-0SF 216.09 159.49 131.•.®11 1350.28 1308.44 MinPt-0SF 289.75 230.68 201.76 4.99 1591.77 1515.44 OSF>5.00 Exit Alert 360.45 287.43 251.41 4.99 3749.15 2681.56 OSF<5.00 Enter Alert 143.29 80.89 50.1:)jjjjjjjjjjjjEE, 4586.86 2814.36 MinPt-0.SF 131.78 75.5 2.37 4654.07 2825.01 MinPt-O-ADP 123.7'mrLE. 49.63 2.52 4711.79 2834.16 MinPt-0-EOU 1111113311. 82.12 68.15 3.94 4919.34 2867.07 MinPt-CtCt 128.7;)jjjjjjjjjjjjj22111 46.47 2.36 5145.26 2902.68 MinPPO-EOU 142.58 76.1.Malt 2.16 5226.68 2915.79 MinPt-O-ADP 157.76 82.78 45.78® 5303.41 2927.95 MinPt-0-SF • 695.49 555.55 486.07 5.00 7066.96 3207.51 OSF>5.00 Exit Alert 1497.55 128864 1184.6 ijlE 1016166 3688.78 MinPt-0-SF 1226.86 980.67 858.07 5.00 12546.57 3772.28 OSF<5.00 Enter Alert 1184.01 927.80 800.1.MEM 13098.77 3752.33 MinPt-0SF 1153.9 891.21 760.34 4.40 13687.82 3732.95 MinPt-CtCt 11547 890.411 758.73 438 13766.41 373450 MinPt-0-EOU 1156.41 890 7 758.44 4.37 13826.18 3735.95 MinPt-O-ADP II 1154.261 872.63 732.32 4.11 14510.82 3746.30 MinPt-CtCt 1154.'48) 872.4 731.85 4.10 14551.13 3745.84 MinPt-O-EOU 1154.74 872. 731.7 410 14568.39 3745.43 MInPt-O-ADP 1158.82 874.0 732.21 4.08 14718.35 3736.54 MinPt-O-ADP 1158.56 863.06 715.81 3.931 15175.94 3678.10 MinPt-0.SF MEM 777.42 622.96 352 16099.18 3662.91 MinPt-CtCt Drilling Office 2.0.960.0 Nikaitchuq\Oliktok Point\011554\0115-54\0115-S4(P5) 9/13/2011 2:38 PM Page 3 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 1087 75 776.14 620.83 3.50 16174.52 3661.03 MinPt-O-EOU 1089.03 775.60 619.388J 3.48 16255.23 3659.26 MinPt-O-EOU 1089.80 775.75 619.22 3.48 16280.22 3658.71 MinPtA-ADP 1106.45 784.88 624.5 3.45 1657456 3652.26 MinPt-O-ADP 1124.13 795.79 632111 3.43 16848.77 3647.91 MinPt-O-SF 1254.91 899.49 722 271 3 541 17992.20 3630.83 MinPt-O-SF 1336.39 959.45 77148 3.551 18847.78 3591.14 MinPt-OSF 1363.89 980.00 788.55 3.54 19126.33 3586.73 MinPt-O-SF 1370.46 984.94 792.67 3.56 19191.36 3585.70 TD OP18-08PB1(Def Survey) Warning Alert I 23.981 22.74 455 18.59 0.00 0.00 CtCt<=15m<15.00 Enter Alert 23.98 22.76 4.55 18.591 23.46 23.46 MinPt-O-SF 24.26 4.83 10.99 193.46 193.46 MinPt-O-EOU 48.89 42.55 29.45 7 52 641.00 640.14 CtCt<=15m>15.00 Exit Alert 82.96 69.72 63.5 ®I 937.36 929.27 MinPt-O-SF 104.28 84.72 75.56 1176.34 1153.03 MinPt-O-SF 106.40 86.40 77.0 aEE 1196.16 1171.08 MinPt-O-SF 12577 104.07 93.89 6.11 1378.93 1333.33 TD 0111-01PB1(Def Survey) Warning ANN 48.02 46.80 15.21 38.23 3.95 3.95 CtCt<=15m<15.00 Enter Alert 47.85 46.15 15.05 2742 138.95 138.95 MinPts 48.44 45.65 15.63 16.92 338.89 338.89 MinPt-O-EOU 49.14 46.01 16.33 15.31 403.60 403.59 CtCt<=15m>15.00 Exit Alert 9457 74.55 61.76 466 965.46 956.09 OSF<5.00 Enter Alert 99.17 77.12 66.36 rile 999.03 987.98 MinPt-O-SF 157.71 103.00 76.25 1333.92 1294.13 MinPt-O-SF 287.37 228.68 199.96 4.98 1794.08 1686.56 OSF>5.00 Exit Alert W,;.�'-., 8871.28 3176.49 MinPts OP18-08(Def Survey) Warning Alert I 23.94 22.761 4.551 18.59 0.00 0.00 CtCt<=15m<15.00 Enter Alert 23.98 22.76 4.55 18.591 23.46 23.46 MinPt-O-SF 24.26=Mr 4.83 10.99 193.46 193.46 MinPt-O-EOU 48.89 42.55 29.45 7.52 641.00 640.14 CtCt<=15m>15.00 Exit Alert 83.58 70.22 64.1 942.51 934.19 MinPt-OSF 121.12 95.87 83.85 4.99 1275.27 1242.29 OSF<5.00 Enter Alert 133.56 104.52 90.61 1353.75 1311.48 MinPt-OSF 147.90 11726 10255 499 1435.73 1382.17 OSF>5.00 Exit Alert 5875.16 5658.89 5551.2-=, 10669.22 3744.73 MinPt-OSF 6469.91 6071.25 5872.41 16.27 19191.36 3585.70 TD 6767.431 6417.44 6242.94 9 7911 17186.47 3644.05 MinPts OP18-08PB2(Def Survey) Warning Alert 23.94 22.761 455 18.59 0.00 0.00 CtCt<=15m<15.00 Enter Alert 23.98 22.76 4.5 18.59 23.46 23.46 MinPt-O-SF 24.26 MIMI 4.83 10.99 193.46 193.46 MinPt-O-EOU 48.89 42.55 29.45 7.52 641.00 640.14 CtCt<=15m>15.00 Exit Alert 83.58 70.22 64.1 :11:0 942.51 934.19 MinPt-O-SF 121.12 95.87 83.85 4.99 1275.27 1242.29 OSF<5.00 Enter Alert 133.56 104.52 90.61 1353.75 1311.46 MinPt-OSF 147.90 117.26 102.55 4.99 1435.73 1382.17 OSF>5.00 Exit Alert 5875.16 5658.92 5551.2. 10689.22 3744.73 MinPt-O-SF 6452.39 6053.57 5854.65 16.22 19191.36 3585.70 TD 6767.,;Vu 17186.47 3644.05 MinPts 0124-08(P8)(Def Plan) Warning Alert 79.89 76.86 47.08 25.97 300.00 300.00 MinPts 80 01 76.74 47.20 24.08 340.10 340.10 MinPt-O-EOU 114.18 92.01 81.3 INE 943.17 934.82 MinPt-O-SF 121.96 96.55 84.46 4.99 1009.13 997.54 OSF<5.00 Enter Alert 175.07 124.10 99.23 izi:: 1354.15 1311.81 MinPt-O-SF 261.86 208.32 182.16 4.98 1769.13 166556 OSF>5.00 Exit Alert 6000.81 5779.63 5669.5'MOM 10380.26 3714.95 MinPt-O-SF 599881'...35M=ME 27.26 10461.12 3723.86 MinPts 'T '' 5777.45 5667.46 27.27 10464.23 3724.19 MinPt-CtCt Man 4993.14 4835.17 16.80 15888.81 3668.15 MinPt-CtCt 5310.7;' rid 4833.85 16.73 15943.80 3666.78 MinPt-O-EOU 5311.54 4992.6' 16.70 15968.79 3666.16 MinPt-O-ADP 5544.61 5165.78 4976.8' 18436.40 3603.50 MinPt-O-SF OP08-04(Def Survey) Waming Alert MEICE11M2H_MMEI 57.82 0.00 0.00 MinPts 72.31 MOB 39.50 32 56 183.90 183.90 MinPt-O-EOU 148.12 125.86 115 31 6.60 912.22 905.16 MinPt-O-SF 302.61 251.48 226.52 6.041 1348.38 1306.78 MinPt-O-SF 1416.81 1360.61 1333.01 1 25.641 3916.21 2708.05 MinPt-OSF 2008.00 1910.32 1861 981 20 761 6111.52 3056.05 MinPt-O-SF 863.23 889.46 603.06 4.99 9467.33 3588.02 OSF<5.00 Enter Alert 410.44 222.251 128.65 2.191 9983.62 3665.33 MinPts 0111-01(Def Survey) Warning Alert 48.02 46.80 15.21 38.23 3.95 3.95 CtCt<=15m<15.00 Enter Alert 47.85 46.15 15.05 27.42 138.95 138.95 MinPts 48.44 45.65 15.63 16.92 338.89 338.89 MinPt-O-EOU 49.14 46.01 16.33 15.31 403.60 403.59 CtCt<=15m>15.00 Exit Alert 94.57 74.55 61.76 4.66 965.46 956.09 OSF<5.00 Enter Alert Drilling Office 2.0.960.0 Nikaitchuq\Oliktok Point\0115-S4\0115-S4\0115-S4(P5) 9/13/2011 2:38 PM Page 4 of 13 Offset Trajectory Separation Allow Sep. Reference Trajectory Separation Factor Alert Status Ct-Ct(ft)I EOU(ft) Dev.(ft) Feat. MD(ft) I TVDL)_ Alert I Minor I Major 9917 77.12 66.34.4.; 999.03 987.98 MinPt-O-SF 157 71 103.00 76.2 2.93 1333.92 1294.13 MinPt-O-SF 287.37 228.68 199.96 4.98 1794.08 1686.56 OSF>5.00 Exit Alert 797.19 753.42 10.11 6273.82 3081.78 MinPt-CtCt 475.59 379.83 332.14 5.00 7997.37 3355.00 OSF<5.00 Enter Alert 459.39 366.39 320.3. 8030.20 336020 MinPt-O-SF 443.51 354.02 309.76 5.00 8062.35 3365.30 OSF>5.00 Exit Alert 317.98 253.03 221.05 4.96 8464.76 3429.09 OSF<5.00 Enter Alert 317.9 252.14 219.72 4.89 8468.63 3429.71 MinPt-CtCt 337.6 233.29 181.63 3.26 8616.44 3453.14 MinPt-O-EOU 356.66 236.94 177.53.00 8683.12 3463.71 MinPt-O-ADP 400.00 259.34 189.50 2.861 8795.50 3481.52 MinPt-O-SF 922.06 736.58 644.34 4.99 9794.05 3638.42 OSF>5.00 Exit Alert 1048.23 859.14 765.09 5.57 10261.10 3701.06 TD S135-W4(P2)(Def Plan) Warning Alert I1 17871.621 17868.0•' 5069.71 325.40 325.40 MinPts 17873.56 17872.34 17840.75 14602.08 0.00 0.00 Surface 1193.37 949.86 830.67 4.98 18055.69 362524 OSF<5.00 Enter Alert 571.58 391.98 303.8 3.2 18390.78 3605.30 MinPt-O-SF 1 432.18 314.01 25542 3.68 18577.94 3597.94 MinPt-CtCt 459.79 298.17 217.85 2.86 18656.76 3594.84 MinPt-O-EOU 489.11 303.68 211.45 2.65 18694.72 3593.67 MinPt-O-ADP 541.95 329.86 224.31 2.56) 18758.62 3592.55 MinPt-O-SF 841.52 572.27 438.14 3.13 19191.36 358570 TD SP36-W5(P2)(Def Plan) Warning Alert OEM ME=MEIM32 5064.32 325.40 325.40 MinPts 17874.36 17873.14 17841.55 14602.73 0.00 0.00 Surface 988.52 787.74 689.17 5.00 17948.09 3634.72 OSF<5.00 Enter Alert 846.77 668.83 581.2. 18024.96 3627.95 MinPt-O-SF 749.15 597.62 522.82 4.99 18089.31 362228 OSF>5.00 Exit Alert 647.69 534.49 478.39 5.76 18212.63 3612.77 MinPt-CtCt 658.65 529.401 465.28 5.13 18249.78 3610.88 MinPt-O-EOU 663.34 529.66 463.30 4.99 18257.26 3610.56 OSF<5.00 Enter Alert 680.65 533.79) 460.851 4.66 18281.22 3609.61 MinPt-O-ADP 817.61 616.90 517.03 4.091 18394.16 3605.17 MinPt-O-SF 1257.71 1005.30 879.59 5.00 18656.61 359485 05F>5.00 Exit Alert 1756.92 1480.11 1342.20 6.37 19191.36 3585.70 TO SI32-W2(P2)(Def Plan) Warning Alert MEM�- .S 5072.05 325.40 325.40 MinPts 6073.6:M1 NEM 15822.53 3669.80 MinPts 17871.03 17869.81 1783822 14600.01 0.00 0.00 Surface 1344.22 1069.77 935.85 4.99 18326.49 3607.83 OSF<5.00 Enter Alert 1150.49921858.26 715.56 4.01 19142.87 3586.47 MinPt-CtCt 1150. 857.831 71472 4.00 19182.53 358584 MinPt-O-EOU 1151.13 857.86 714.65 4.00 19191.36 3585.70 OSF>5.00 Exit Alert 4483.59 4260.37 4151.18 MECO 15730.81 3671.96 MinPt-O-SF OP23-W W 02(Def Survey) Pass 1 70.911 68.50 38.10 28.96 267.98 267.98 MinPts 1 70.921 68.151 38.11 25.15 344.12 344.12 MinPts ) 66.67 59.53 33.86 9.17 680.06 678.76 MinPts 67.76 58.24 34.95 6.98 743.72 741.42 MinPl-0-EOU 79.13 65.47 46.32®' 868.33 862.86 MinPt-O-SF 567.42 545.19 53461 mg6 :. 2308.90 2100.10 MinPt-OSF 742.61 709.07 692.. gEla 2644.54 2322.12 MinPt-O-SF 1 6883.20 6804.63 6765.83 88.70 8738.09 347242 TO OP22-W W01(P2)(Def Plan) Pass 62.40 57.47 29.59 12.42 556.28 556.00 MinPts • 62.55 57.32 29.75 11.71 581.20 580.79 MinP1-0-EOU 63.0 57.3 30.23 10.95 606.00 605.43 MinP1-0-EOU ' 81.05 70.60 48.25 glErl 770.17 767.35 MinPt-O-SF 1464.96 1442.72 1432.16 MIME 2105.75 1944.84 MinPt-OSF 2696.18 2673.99 2663.3 ®i( 2848.37 2432.61 MinPt-O-SF 5247.39 5183.37 5151.8 MEE 4848.91 2824.20 MinPt-O-SF 8020.87 7938.38 7897.64 98.41 6494.93 3116.83 TD 0106-05 current(Non-Def Survey) Pass 95.75 93.24 62.95 37.61 219.07 219.07 MinPts 96.66 92.30 63.85 21.83 378.17 378.17 MinPt-O-EOU ' 128.97 117.62 96.16 MUM 671.06 669.87 MinPt-O-SF 1576.21 1552.76 1541.69 71.18 1481.47 1421.34 TO 0106-05(P9c)(Del Plan) Pass 96.01 94.79 63.20 77.44 0.00 0.00 Surface ' 96.01 92.99 63.20 31.34 299.11 299.11 MinPts 96.08 92.80 63.27 28.94 358.82 358.82 MinPt-O-EOU • 140.34 129.39 107.53®' 765.22 762.51 MinPt-O-SF 509.33 493.85 476.5 EEKE 1172.68 1149.69 MinPt-O-SF 5546.00 5481.49 5449.7 palE 2813.37 2415.05 MinPt-OSF 7604.98 7410.83 7314.2 ilIC 9664.26 3618.94 MinPt-OSF 7697.86 7501.72 7404.15 39.44 9712.85 3626.33 TD 0107-04(Def Survey) Pass 80.0.'MER]=1111 64.37 3.88 3.88 MvnPts Drilling Office 2.0.960.0 Nikaitchuq\Oliktok Point\0115-S4\0115-S4\0115-S4(P5) 9/13/2011 2:38 PM Page 5 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 80.25 77.29 47.44 26.71 358.65 358.65 MinPt-O-EOU 153.75 140.61 120.94 MEE 867.45 862.01 MinPt-OSF 174.44 159.58 141.6 mEEE 919.26 911.92 MinPt-O-SF 2599.04 2533.93 2501.86 mum3842.16 2696.31 MinPt-0SF 2644.32 2578.24 2545.6• 40.60 394650 2712.85 MinPt-O-SF 4682.39 4516.72 4434.3.MEE 9548.15 3600.83 MinPt-0SF 5072.09 4900.74 4815.56 77 9860.29 3648.04 TD OP26-DSPO2(Def Survey) Pass ®® 264.15 3.99 3.99 MinPts 237 88 215 72 205 07 EMIM 1009.10 997.51 MinPt-O-SF 193.10 153.91 134.88 IMMICO 1357.48 1314.71 MinPt-0SF 189.90 151.80® 5.11 1397.39 1349.25 MinPt-O-ADP 189.65 11.1131ZI 133.40 5.13 1401.87 1353.10 MinPt-O-EOU 188.09 154.36 138.06 5.73 1462.79 1405.35 MinPt-CtCt 196.64 174.67 163.8 60: 1626.41 1544.88 MinPt-O-SF 227.''man 19464 11.87 2003.76 1861.87 MinPt-0-EOU 231.06 208.99 198.2 10. 2046.77 1897.23 MinPt-O-SF 231.96 209.281 198.4 10.70 2055.40 1904.26 MinPt-O-ADP 298.40 255.57 234 7 7.131 2359.88 2136.75 MinPt-0SF 3662.52 3619.02 3597 76 86.12 6486.03 3115.42 TD OP05-06(Def Survey) Pass 103.77 101.89 70.96 5440 153.94 153.94 MinPts 103.84 101.84 7103 51.30 173.94 173.94 MinPt-O-EOU 171.83 161.46 139.02 MEE 772.93 770.05 MinP1-0SF 185.98 174.82 153.17 807.16 803.47 MinPt-O-SF 9006.85 8827.80 8738.7 0.148 i9653.89 3617.35 MinPt-O-SF 9118.76 8937.66 8847.6.®'' 9706.88 3625.43 MinPt-O-SF 9215.99 9033.19 8942.29 50.68 9747.71 3631.56 TD OP05-06PB2(Def Survey) Pass 103.77 101.89 70.96 54.40 153.94 153.94 MinPts 103.84 10184 7103 51.30 173.94 173.94 MinPt-O-EOU 171.83 161.46 139.02 16.46 772.93 770.05 MinPt-O-SF 185.98 174.82 1531718 807.16 803.47 MinPt-0SF 8632.49 8467.72 8385 83 MEE 9061.81 3523.74 MinPt-OSF OP05-06PB1(Def Survey) Pass 103.77 101.89 70.96 54.40 153.94 153.94 MinPts 103 84 101.84 71.03 51.30 173.94 173.94 MinPt-O-EOU 171.83 161.46 139.02 MEEEI 772.93 770.05 MinPt-O-SF 185.98 174.82 153.1 111Mat 807.16 803.47 MinPt-O-SF 1907.39 1875.05 1859.48 61.18 1712.66 1617.92 TD OP09-S1(De(Survey) Pass 6. MZSIE MMIEI 51.30 0.00 0.00 MinPts 64.66 60.95 3185 17.13 368.56 368.56 MinPt-O-EOU 161.43 139.16 128 62) 7.20 977.08 967.15 MinPt-O-SF 253.84 212.16 191 94 6.24 1205.35 1179.43 MinPt-O-SF 2707.10 2586.48 2526 661 22 62 6940.12 3187.40 MinPt-O-SF 2883.42 2754.83 269103 22.59 7385.35 3257.98 M1nPt-OSF 3064.41 2927.32 2859 27 22.51 7829.28 '3328.36 MinP1-0SF 3680.35 3510.29 3425.75 21.76 9545.12 3600.35 MinPt-O-SF 4060.76 3882.25 3793.48 22.87 10101.23 3681.03 MinPt-O-SF 3988.96 3807.73 3717.61 22.13 10649.58 3742.89 MinPt-O-SF 3988A1 3807.26 3717.17 22.13 10664.19 3744.26 MinPts 3800.59 3575 86 3463 98 16.98 12854.36 3758.04 MinPt-CtCt 3614.62 3343.73 3208.711mm 15218.54 3675.44 MinPt-O-SF 3614.50�"1 MEM= 13.39 15228.50 3674.91 MinPts MIMI 3368.31 3222.39 12.54 16271.76 3658.90 MinPt-CtCt 3661.8•Mg= 3220.97 12.48 16331.74 3657.58 MinPt-O-EOU 3662.80 3367.:.mgEENE 12.45 16361.72 3656.92 MinPt-O-ADP 3727 4:MIME 3252.88 11.80 17278.62 364455 MinPt-O-EOU MiDEll. 3403.92 3238.27 11.27 17930.29 3636.28 MinPt-CtCt wiser 3369.811 .MDR 18855.94 3591.01 MinPts OP03-P05PB1(Def Survey) Pass L119.92 118.62 87.11 91.45 64.00 64.00 MinPts 120.03 117.807 87. 53.35 24400 244.00 MinPts 120.17 117.66 87.36 47.26 299.00 299.00 MinPt-O-EOU 120.20 117.65 87.39 46.74 304.00 304.00 MinPt-O{OU 259.03 236.96 226.22 MUD 1047.68 1033.85 MinPt-O-SF 314.17 286.98 273.9.imEEE 1144.51 1123.85 MinPt-O-SF 3694.73 3640.47 3613.8 69.38 3009.22 250539 MinPt-O-SF 4012.73 3952.20 3922."M3111 3638.01 2863.95 MinPt-O-SF OP03-P05(Def Survey) Peas _ ® 118 02® 91.45 64.00 64.00 MinPts ® 117 80® 53.35 244.00 244.00 MinPts 120.17,MM 87.36 47.26 299.00 299.00 MinPt-O-EOU 120.20® 87.39 46.74 304.00 304.00 MinPt-O-EOU 259.03 236.96 226.22 mai 1047.68 1033.85 MinPt-OSF 314.17 286.98 273.9•=NEE 1144.51 1123.85 MinPt-O-SF 3661.76 3608.19 3581.8•Illffilal 2944.78 2477.82 MinPt-O-SF 5930.54 5761.59 5677.6. EgE 9548.50 3600.89 MinPt-O-SF 5944.04 577479 5690.66 35.32 9558.53 3602.48 TD Drilling Office 2.0.960.0 Nikaitchuq\Oliktok Point\0115-S4\0115-S4\0115-S4(P5) 9/13/2011 2:38 PM Page 6 of 13 I 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 OP03-P05PB2(Def Survey) Pass 119.92 118.62 87.11 91.45 64.00 64.00 MinPts 120.0 117.8 87. 53.35 244.00 244.00 MinPts 120.17 117.66 87.36 47.26 299.00 299.00 MinPt-O-EOU 120.20 117.65 87.39 46.74 304.00 304.00 MinPt-O-EOU 259.03 236.96 226.22 MB= 1047.68 1033.85 MinPt-O-SF 314.17 286.98 273.59h 1144.51 1123.85 MinPt-OSF 3661.76 3608.19 3581.891 2944.78 2477.82 MinPt-O-SF 5174.72 5050.00 4988.1 11=111I 7395.13 3259.53 MinPt-O-SF OP08-04PB1(Del Survey) Pass ' 72.0 70.771 39.191 57.82 0.00 0.00 MinPts 72.31 70.12 39.50 32.56 183.90 183.90 MinPt-O-EOU 148.12 125.86 115.31 6.60 912.22 905.16 MinPt-O-SF 302.61 251.48 226.52_ 6 04 1348.38 1306.78 MinPt-O-SF 1416.81 1360.61 1333.01 25.64 3916.21 2708.05 MinP1-0SF 2008.00 1910.32 1861.97 20 76 6111.52 3056.05 MinPt-O-SF 1 1855.811 1710.571 1638.43 12 86 8187.63 3385.16 MinPts OPO4-07(Def Survey) Pass 111.23 108 64 78.42 42.60 278.84 278.84 MinPts 111.31 108.57 78.50 40.15 313.84 313.84 MinPt-O-EOU 206.96 184.79 174.1 MEM 1011.69 999.96 MinPt-O-SF 356.08 305.94 281.48® 1348.77 1307.11 MinPt-O-SF 1408.12 1337.99 1303.41®' 3956.94 2714.50 MinPt-O-SF 2323.80 2218.62 2166.6 ® 6244.66 3077.16 MinPt-O-SF 2643.52 2526.61 24686 11.111ss&1 6933.39 3186.34 MinPt-O-SF 3490.42 3320.51 3236.04•.1 9548.36 3800.87 MinPt-O-SF 4555.91 4379.33 4291.52 25.94 10265.28 3701.56 TD CP04-07P81(Det Survey) Pass 111.23 108.6 78.42 42,60 278.84 278.84 MinPts 111.31 108.57 78.50 40.15 313.84 313.84 MinP1-0-EOU 206.96 184.79 174.15=IIICE0] 1011.69 999.96 MinPt-O-SF 356.08 305.94 281.48® 1348.77 1307.11 MinPt-O-SF 1408.12 1338.02 1303.46 MEM 3956.94 2714.50 MinPt-O-SF 2323.80 2218.63 2166.65® 6244.66 3077.16 MinPt-O-SF 2643.52 2526.62 2468.66 Mg= 6933.39 3186.34 MinP1-0SF , 3490.43 3320.53 3236.08® 9548.36 3600.87 MinPt-OSF • 3706.86 3532.51 3445.82 21.38 9782.73 3636.76 TO • Oliklok Point 1-1(Def Survey) Pass 136.56 135.45 103.75 121.52 . 0.00 0.00 Surface I 136.56 135.44 103.75 121.48 40.10 40.10 MinPts 136.66 135.34 103.85 102.60 84.20 8420 MinPt-O-EOU 351.29 334.74 318.48® 970.51 980.90 MinPt-0SF 387.69 369.47 354.• MEM 1012.01 1000.26 MinPt-O-SF 7574.58 7521.83 7495.9 MOM 2197.17 201645 MinPt-O-SF Oliktok Point 1-15-106(P5)(Def Plan) Pass 136.56 135.45 103.75 121.52 0.00 000 Surface 136.56 135.44 103.75 121.48 4010 40.10 MinPts 136.66 135.34 103.85 102.60 84.20 84.20 MinP1-0-EOU 351,29 334.74 318.48 21.15 970.51 960.90 MinPt-O-SF 387.69 369.47 354.88 21.221 1012.01 1000.26 MinPt-O-SF 1893.34 1850.701 1830.31 46.38 1584.53 1509.28 MinPts 6751.42 6707.07 6685.86 159.07 1399.80 1351.32 MinPt-O-SF i 9759.14 9570.97 9477.77 52.35 8456.44 3427.77 MinPt-O-SF 10489.90 10263.77 10151.58 46.74 9705.87 362527 MinPt-O-SF SP30-W 1(P2)(Del Plan) Pass 1I 17866 54 17863.011 17833.721 5077.79 325.40 325.40 MinPts 17668.60 17867.38 17835.79 14598.03 0.00 0.00 Surface I 2405.00 2115.211 1973.501 8.461 19191.36 3585.70 MinPts 5129-52(P2)(Del Plan) Pass 17868.16 17864. 17835.36 4699.96 353.37 353.37 MinPts '7868 1 17864. 17835.36 4693.80 355.02 355.02 MinPt-O-EOU '7867 76 17866.54 17834.95 14597.34 0.00 0.00 Surface I L 17867 76 7867.76 17865.21 17834.9 7000.71 198.80 198.80 MinPts 17868 0 17864.9 1783524 5716.74 258.80 258.80 MinPt-O-EOU IL 2516 86 2223.4 2080.031 8.75 19189.17 3585.73 MinPts 5694.21 5409.95 5269.99 20.33 19191.36 3585.70 TO 2444.68 2203.20 2085.2. 13113.29 3751.98 MinPt-O-SF !. 2321.32 2074.87 1954.71 9 64 15171.80 3678.39 MinPt-O-SF 2319.13 2073.59®" 9.67 15227.14 3674.98 MinPFO-ADP 2318.65 MEM 1954.11 969 15248.38 3673.93 MInPt-0-EOU 2073.83 1954.85 9.71 15287.85 3672.35 MinPt-CtCt 2332.7' M=MI 9.67 15763.61 3671.27 MinPts 2340.67 2089.00 1966.4.MIME 16173.05 3661.07 MinPt-O-SF 2350.92 2093.1•1 1967.65 9.34 16676.93 3650.05 MinPt-O-ADP 2360.08 2096.07 MIIIMEI 9.14 17142.55 3644.31 MinPI-0-ADP 2381.04 2096.86 1968.11.11MM 17179.54 3644.05 MinPt-O-SF 2432.95 2146.58 2006.73 1141 18723.25 3593.11 MinPt-O-SF Tuvaaq ST 1(Def Survey) Pass 17133 86 17131 15 17101.0 6305.69 162.14 162.14 MinPts 17134 011 17131 031 17101.20 574216 197.17 197.17 MinPt-O-EOU • Drilling Office 2.0.960.0 Nikaitchuq\Oliktok Point\0115-S4\0115-S4\0115-S4(P5) 9/13/2011 2:38 PM Page 7 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 17134.63 17130.41 17101 821 4061.54 361.68 361.68 0l r Pts 17134.63 17130.40 17101.82 4050.95 363.18 363.18 MinPt-O-EOU I 2800.75 2556.68 2436.381 11.631 19191.36 3585.70 MinPts Kigun 1 PB1(Det Survey) Pass 17131 15=EEO 6305.69 162.14 162.14 MinPts 17134.01® 17101.20 5742.15 197.17 197.17 MinPt-O-EOU MEM �' °" 4061.54 361.69 361.68 MinPts 17134 63 ELIICE 17101.82 4050.95 363.18 363.18 MinPt-O-EOU 2800.86 NEM Maail Min 19191.36 3585.70 MinPts Kigun 1(Def Survey) MI= 17131.15 EME13 6305.69 162.14 162.14 MinPtc 17134.01 EMEN 1710120 5742.15 197.17 197.17 MinPt-O-EOU 4061.54 361.68 361.68 MinPts 17134.63 17130.40 17101.821 4050.95 363.18 363.18 MinPt-0-EOU 2800.86 11111=MMBIl MIES 19191.36 3585.70 MinPts SP27-N1(P3)(Def Plan) Pass 17864 OOL 17860 511 5113.94 325.40 325.40 MinPts 17866.07 17864.85 17833.26 14595.96 0.00 0.00 Surface 1 3387.39 3102.25 2962.66 12.11 18983.68 3588.99 MinPt-CtCt 3387.79 3101.87 2961.88 1208 19023.37 3588.36 MinPt-O-EOU 3388.16 3101.94 2961.80 12.07 19038.25 3588.12 MinPP0-ADP 3398.79 3109.54 2967.88 11.981 19191.36 3585.70 MinPt-O-SF 8125-N2(P2)(Det Plan) Pass 1 17862.38 17858.81 17829.5815061.48 325.40 325.40 MinPts 6366.1 6144.01 6034. 29.1 15828.45 3669.66 MinPts 17864.53 17863.30 17831.72 14594.70 0.00 0.00 Surface 1 4246.76 3971.87 3837.17 15.74 18380.13 3605.72 MinPt-CtCt 4247.07 3971.58 3836.59 15.71 18409.87 3604.55 MinPt-O-EOU 4247.46 3971.67 3836.531 15.69 18424.74 3603.96 MinPt-O-ADP 4375.32 4083.84 3940.80 15.28 19191.36 3585.70 TD 1 5176.361 4953.451 4844.461 23.721 15675.34 3672.40 MinPts SP23-1,43(P3)(Def Plan) 17859.481 17855.981 17826 5109.08 325.40 325.40 MinPts 17861.53 17860.31 17828.72 14592.25 0,00 0.00 Surface 4950.74 4706.05 458628 20.65 16848.63 3647,91 MinPt-CtCt 4950.96 ME= 4585.73 20.60 16877.13 3647.56 MinPt-O-EOU 4951.38 4705.84 NEM 20.58 16896.22 3647.33 MinPt-O-ADP 4976.90 4726.81 4604.3 - 17146.81 3644.25 MinPt-O-SF 5106.54 4847.20 4720.08 20.06 17667.82 3646.80 MinPt-O-SF 5173.86 4910.73 4781.71 Mae 17898.45 3638.83 MinPt-O-SF 5365.21 5090.25 4955,2611=1:11 18591.06 3597.42 MinPt-O-SF 5404.54 5127.08 4990.8.- 18719.91 3593.16 MinPt-O-SF 5545.96 5259.82 5119.18 19191.36 3585.70 MinPt-O-SF SP24-SEI(P2)(Def Plan) Pass 17863.85 17860.07 17831 4717.63 325,41 325.41 MinPt-OSF 17863.25 17859.46 17830. 4720.2 333.65 333.65 MinPt-O-SF 11_,. 222.L____17858211 II 2.7 178631 17858.91 17829.92 4684.88 355.10 355.10 MinPts 17862.30 17861 08 17829.50 14592.88 0.00 0.00 Surface 17862 301 17859 7511 17829 501 6996.32 198.80 198.80 MinPts 17862 581 17859 501 17829 77 5785.35 253.80 253.80 MinPt-O-EOU 6399.47 6123.69 5987.94 23.55 18606.86 3596.80 TD 5602.78 5371.87 5257 381 24.461 10366.16 3713.36 MinPt-O-SF 5363.93 5147.35 5040 841 25.161 11071.62 3780.04 MinPt-O-SF 5263.27 5043.41 4935 351 24.341 12532.25 3773.76 MinPt-O-SF 5232.29 5012.43 4904.471 24.221 13091.54 3752.50 MinPt-O-SF 5226.99 5008.97 4902.044 24.42 13162.68 3750.62 MinPt-O-ADP 5226.42 5008.85 4902.17 24.48 13178.81 3750.13 MinPt-O-EOU 1 5226.04 5009.27 4903.03 24,58 13207.49 3749.20 MinPt-CtCt 5242.16 5025.0974918.80 24.64 13663.58 3732.85 • MinPt-O-ADP 5254.2611 5032 21 I 4923.41 24.13 14166.91 3744.17 MinPts 5261.67 5035 91 4925.26 23.76 14492.87 3746.27 MinP1-0-SF 5298.54 5068.72 4956.14 23.51 15173.34 3678.28 MinPt-O-SF 5381.61 5149.51 5035.96 23.68 15762.94 3671.29 MinPts 5423.93 5185.65 5069.00 23 231 16170.56 3661.13 MinPt-O-SF 5591.02 5337.84 5213 691--22.50 17146.05 3644.26 MinP1-0SF 5719.50 5459.07 5331.29 22.361 17666.82 3646.80 MinP1-0SF 5871.56 5605.30 5474 581 22.441 18047.15 3625.99 MinPt-O-SF 5907.17 5639.41 5507 931 22.441 18131.85 3618.55 MinPt-O-SF Sx34-N Sand(P2)(Def Plan) P853 II 17872.6511 17869.00 17839.8411 4894.39 325.39 325.39 MinPts 17872.72 17871.50 17839.92 14601.40 0,00 0.00 Surface 1 5645.71 5403.61 5284.81 23.74 16738.61 3649.27 MinPt-CtCt 5645.87 5403.44 5284.47 23.71 16756.53 3649.05 MinPt-0-EOU 5646.14 5403.50 5284.43 23.69 16767.40 3648.91 MinPt-O-ADP 5712.36 5462.80 5340.26 23. 17145,18 3644.27 MinPt-O-SF 5935.49 5677.12 5550.12 23.3 17667,23 3646.80 MinPt-OF 6405.47 6117.83 5976.07 22.58 19191.36 3585.70 MinPt-OSF S120-N4PB1(P1)(Det Plan) MEMO 17824.2 J 5100.09 325.40 325.40 Mins M=i1E1 6176 25 6063.84 28.47 16037.51 3664.45 MinPt-CtCt Drilling Office 2.0.960.0 Nikaitchuq\Oliktok Point\0115-S4\0115-S4\0115-S4(P5) 9/13/2011 2:38 PM Page 8 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 6405.29 6176.23 6063.80 28.47 16037.88 3664.44 MinPt-O-EOU 6405.33 617624 6063.79 28.46 16038.13 3664.43 MinPt-O-ADP 6410.99 6181.41 6068.70 28.421 16044.23 3864.28 MinPt-OSF 7632.07 7412.47 7304.13 35.21 16527.97 3653.28 TD 17859.14 17857.92 17826.34 14590.30-/1 0.00 0.00 Surface 17857.09 17853.61 17824.291 5119.3us 323.78 323.78 MinPts • SP18-N5(P3)(Def Plan) Paas II 17854.77II 17851.28I® 5103.63 325.41 325.41 MinPts 6537.04I=ME MXIME,1".y 15823.01 3669.79 MinPts •• • 17856.87 17855.65 17824.06 14588.44 0.00 0.00 Surface 650653 6288.11 6180.97 30.34 15575.01 3671.76 MinPt-CtCt 6506.5388.11 180 96 30.34 15576.18 3671.77 MinPts 6506.96 6288.53 6181.371 15583.39 3671.82 MinPt-0-SF 6510.75111'-'` 15761.85 3671.32 MinPts 8041.00 7792.56 7669 82MEE 17144.25 3644.28 MinPt-0-6F 8488.79 8200.57 8057 85 29.73 19191.36 3585.70 TD S114-N6(P2)(Oct Plan) Pass I17851.71 17848.121 17818.961 4898.83 325.41 325.41 MinPts 1785441 1785042 17821.6 4473.041 366.84 366.84 MinPt-0SF 16565.79 6340.61 6230.00 29.66 15849.08 3669.14 MinPt-CtCt 6565.80 6340.611 6229.98 29.66 15850.87 3669.10 MinPts 8570.35 634487 623410 29.641 15887.13 3668.19 MinPt-OSF 17853.82 17852.59 17821.01 14585.95 0.00 0.00 Surface 8941.92 8711.84 8598.0 1 18170.98 3661.12 MinPt-O-SF 9261.43 9013.37 8890.4 I® 17145.05 364427 Mink-OSF 9727.98 9443.67 930254 34 46 19191.36 3585.70 TD SD37-DSP1(P4b)(Del Plan) Pap ' 17876.141 17872.551 17843.31 4979.80 325.39 325.39 MinPts 6590.36 6351.90 6234.71 28.10 18575.04 3652.25 MinPt-CtCt • 6590.38 6351.88 6234.67 28.10 16575.37 3652.24 MInPt-O-EOU 6590.41 6351.88 6234.66 28.09 16575.59 3652.24 MinPt-O-ADP 6595.04 6356.11 623868 28.561 18580.52 3652.13 MinPt-0SF 7534.86 7310.77 7204.69 34.52 16655.16 3650.49 TD 17876.14 17875.03 17843.33 16037.41 0.00 0.00 Surface , IIKEIMIENZEIMEMEIEE 4996.18 323.80 323.80 MinPts SP22-FN1(P2)(Det P.ar; Pass 17862.31 17858.52 17829.50 471218 325.40 325.40 MinPt-O-SF 1786172 17857.93 17828.87 4715.01 33366 333.66 MinPt-O-SF 17861.17 17857.1 17828.37 4682.55 355.13 355.13 MinPts 1786118 17857. 17828.37 4676.91 356.78 356.78 MinPt-O-EOU 17860.75 17859.52 17827.94 14591.61 0.00 0.00 Surface 17860.75 17858.1 17827. 6995.06 198.80 198.80 MinPts 17860 98 17857. 17828.18 5873.72 248.80 248.80 MinPt-O-EOU I 664656 6361.49 6220.961 23.631 19191.36 3585.70 MinPts SP11-N7(P2)(Def Plan) -/ Pass • I 17848.34 17844.751 1781541 5024.10) 325.41 325.41 MinPts 6775.5 6552.511 6442 8 30.88 15835.31 3669.48 • MinPts 17850.22 17849.00 17817.41 14583.01 0.00 0.00 Surface 6717.03 6500.35 6394.0111 15392.54 3670.55 MinPt-O-SF 1 6697.41 6481.58 6375.69 31.60 15437,92 3670.78 MinPt-CtCt • 6697.43 6481.581 6375.68 31.60 15440.31 3670.80 MinPts 6709.22 649273 6386.50 31. 15520.14 3671.37 MinPt-O-SF 10286.06 10055.44 9940.9 44.9 18172.65 3661.08 MinPt-O-SF 10486.89 10238.32 10114.83 42. 17145.87 3644.26 MinPt-O-SF 10940.55 '10855.24 10513.29 38.53 19191.36 3585.70 TD 10157.61 9937.88 9828.9:1111111 15653.59 3872.32 MinPt-OSF S117-SE2(P2)(Def Plan) Pass 17857.83 17854.02 17825.0 4693.16 325.41 325.41 MinPt-O-SF 17856. 17852.7 17823.7 4676.28 355.20 355.20 MinPts 17856. 17852.7 17823.74 4671.05 356.86 356.86. MinPt-O-EOU 17856.11 17854 89 17823.31 14587.82 0.00 0.00 Surface 17856.11 17853.56 17823.31 6991.31 198.80 198.80 MinPts 17856.3 17853.3 l 17823.56 5861.26 248.80 248.80 MinPt-O-EOU 6950.80 6715.56 6598.4•1 10267.46 3701.82 MinPt-O-SF 6578.99 6364.84 6259.1:® 11071.23 3780.01 MinPt-0SF 6482.74 6265.44 6158.261 12529.35 3774.07 MinPt-0SF 6452.25 6235.18 6128.221®{ 13091.86 3752.50 MinPt-O-SF • 6447.22 6231.97 6126.01 30.41 13155.35 3750.84 MinPt-O-ADP 6446.681 8126.12 30.47 13169.41 3750.42 MinPt-O-EOU 1 6232.26 6127.00 30.80 13197.47 3749.53 MInPt-CtCt 6464.90 8251.0 6145. 30.74 13682.58 3732.85 MinPt-O-ADP 6478.51 8259.5 8151.91 30.07 14164.40 3744.12 MInPt-0-EOU 6478.69 6259.6 6151.91 30.06 14170.66 3744.23 MinPt-O-ADP 6487.08 6264.24 6154.8 29. 14492.19 374827 MinP8-OSF 6527.90 6300.78 6189.1 29. 15173.81 3678.25 MinPt-O-SF 6933.46 6665.28 6533.18 26.23 18222.38 3612.23 TD 6662.89 6426.90 6310.9.MEM 16173.75 3661.05 MinPt-O-SF I 6733.51 6482.74 6359.4.®i1 17146.62 3644.26 MinPt-O-SF 6885.65 6617.89 648615 M13110 18176.02 3615.11 MinPt-O-SF 6119-FN2(P2)(Def Plan) Pass 17859.95 17856.15 17827.1 4700.1,j 32541 325.41 MinPt-0-6F • Drilling Office 2.0.960.0 Nikaitchuq\Oliktok Point\0115-S4\0115-S4\0115-S4(P5) 9/13/2011 2:38 PM Page 9 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 17858.73 1785491 17825.92 4678.82 355.16 355.16 MlnPts 17858.73 1785491 17825.92 4673.48 356.82 356.82 MinPt-O-EOU 1785830 17857.07 1782549 14589.61 0.00 0.00 Surface 17858.3 17855.7 17825.4 6993.13198.80 198.80 MinPts 17858.5 17855. 17825.74 5865.55 248.80 248.80 MinPt-O-EOU 6913.31 6628.09 6487.441 24.561•19191.36 3585.70 MinPts • SP16-FN3(P2)(Def Plan) Pass 17857 13 17853 31 17824 32 4682.561 325.41 325.41 MinPt-0-SF 17855.80 17851.97�I 17822.9911 4668.73 356.87 356.87 MinPts 17855 35 17854 13 17822 55 14587.20 0.00 0.00 Surface MEM 17852 80 6990.69 198.80 198.80 MinPts 17855.57 MEM 17822.76 5951.17 243.80 243.80 MinP1-0-EOU 7094.84 684425 6720.85 28.73 17438.27 364548 MinPt-CtCt 7095.84 mama 6718.95 28.51 17520.83 3645.95 MinPt-O-EOU 7097.08 6843.57 MIR 28.41 17563.32 3646.20 MinPt-O-ADP 7104.34 6846.8:MEM= 27.99 17730.73 3646.47 MinPt-O-ADP 7263.30 6977.98 6837.23 mom 19191.36 358570 MinPt-OSF 5120-54(P4)(Def Plan) Paas 17857.0(4 17853.59( 17824.28 5100.08 325.40 325.40 MinPts 17859.14 17857.92 17826.34 14590.30 0.00 0.00 Surface 6492.70 6263.07 6150.27 28.76 16071.82 3663.59 MinPts 8492.71 6263.07®' 28.76 16072.14 3663.58 MinPt-O-ADP • 6498.36 6268.34 6155.36 16081.91 3663.34 MinPt-0SF 6506.57 6276.33 6163.24 16090.06 3663.14 MinPt-0SF 685852 6610.65 8488.61® 17146.53 3644.26 MinPt-O-SF 7264.39 6980.73 6840.72® 19191.36 3585.70 MinPt-OSF SP12-SE3(P2)(Def Plan) Pass 17853.05 1784921 17820.2 4659.751 325.41 325.41 MinPt-O-SF .7851 555 17847 721 17818.7 4662.30 356.95 356.95 MinPts 1 7851.10 17849.87 17818.29 14583.73 0.00 0.00 Surface I II 1785110 17848. 17818.2 6987.15 198.80 198.80 • MinPts 17851.34 17848.3 17818.53 5936.72 243.80 243.80 MinPt-O-EOU 832391 7573.32 7467.017 MEM 189.60 3691.94 MinPt-O-SF 7783.70 7571.92 7467.0 111069.80 3779.87 M1nPt-0SF 7684.36 7469.50 7363 14- 12531.35 3773.85 MinPl-OSF 7652.29 7437.67 7331.54hr„ 13093.42 3752.46 MinPt-0SF 7646.29I 7433.7 MIME 36.41 13159.97 3750.70 MinPt-O-ADP 7645.71 7328.91 36.49 13173.80 3750.28 MinP1-0-EOU 7434.07 7329.80 36.65 13200.08 3749.45 MinPt-C1Ct 7663.9171 MMIE 36.78 13659.51 373285 MinPts 7677.1,MM:131 MEI 35.90 14168.77 3744.20 MinPts 7685.24 7464.71 7355 87M12111 3746.27 MinPt-O-SF 7726.51 7501.39 7390.36,®'. 15174.06 3678.23 MinPt-O-SF 1 7277.43 7039.89 6922.85 3108 16879.82 3647.53 MinPt-CtCt 7278.79 7039.05 6920.94 30.80 16970.01 3646.42 MinPt-O-EOU 728064 7039.41 6920.55 30.61 17031.86 3645.66 MinPt-0-ADP 7292.13 7047.68 6927.27 30.26 17182.26 364405 MinPt-O-SF 7328. 7075.35 6950.61 29.36 17574.44 3646.26 MinPt-CtCt 7331.1 7073.1 6945.95 28.81 17765.76 364568 MinPt-O-EOU 733256 7073.3 6945.65 28.69 17809.76 3644.09 MinPt-O-ADP 7360.13 709651 8986.571 28.31 17987.79 363122 MinPt-O-SF 7384.25 7120.21 6990.08 28.36 18003.03 362988 TD I 7384.981 7120.941 6990.801 28.361 18003.03 3629.88 MinPte SP01-SE7(P2)(Def Plan) Pass 1784256 17838.70 17809.7 ®1 325.40 325.40 MinP1.0SF 17842.508 17838.66 17809,70 4640.50 330.41 330.41 MinPt-O-EOU 1 17842.5 17838.661 17809.88 4644.60 332.08 332.08 MinPts 17842.48 17841.26 17809.67 14576.69 0.00 0.00 Surface MOM 17838.81 4971.61 298.80 298.80 MinPts 12605.19 12394.12 12289..: 59.99 11071.88 3780.07 MinPt-O-SF 12506.65 12292.78 12186.3.MIRE 12531.33 3773.85 MinPt-O-SF 12470.43 12257.78 12151.'MIEJC11 13093.67 3752.45 MinPt-0.SF 12462.77 12252.91 59.66 13156.70 3750.80 MinPt-0-ADP 12462.0•MEM 12148.61 59.81 13169.09 3750.43 MinP1-0-EOU EI60151.. 12253.33 12149.70 60.12 13193.83 3749.65 MinPt-CtCt 12484.3.MEM EERIE 60.42 1366474 3732.85 MinPts 12498.. MEM 12178.54 58.78 14170.68 3744.23 MinPt-O-EOU 12499.01 12285.0.MEMIE 58.68 14196.69 3744.52 MinPt-O-ADP 12507.83 12289.96 12181.5. figs 14500.03 3746.30 MinPt-O-SF 12509.18 12291.29 12182.8.EM131 14519.61 3746.26 MinP1-0-8F 12512.50 12294.55 12186.0 imam 14563.09 3745.57 MinPt-OSF 12516.28 12298.25 12189.7'mmo 14606.51 3744.08 MinPt-0SF 12555.05 12331.93 12220.::mos 15174.17 3878.22 MinPt-O-SF 12588.37 12367.81 IMEEIM 57.33 15329.72 3671.21 MinPt-O-ADP 12588. 17SE55554& 1225804 57.34 15331.88 3671.17 MinP1-0-EOU 12368.21 12258.83 57.54 15355.61 3670.79 MinPt-CtCt ELME 7209.32 7097.58 33.26 16404.95 3655.98 MinPtCtCt 7436.19=En 7097.44 33.24 16406.40 3655.95 MinPt-O-EOU 7436.26 7209.27 ME= 33.23 16406.89 3655.93 MinP1-0-ADP 7494.23 7263.74 7150.20 MEMO 16457.52 3654.82 MinPt-O-SF 11105.55 10853.95 10729.09 44.47 17477.38 3645.70 TD 8 11110.171 10858.54 10733.721 44.48 17477.37 3645.70 MinPts SI13-FN4(P2)(Del Plan) Pass Drilling Office 2.0.960.0 Nikaitchuq\Oliktok Point\0115-S4\0115-S4\0115-S4(P5) 9/13/2011 2:38 PM Page 10 of 13 I I I Offset Trajectory Separation Allow Sep. Reference TrajectorySeparation Factor Alert Status Ct-Ct(ft)I EOU(ft) Dev.(ft) Fact. MD(ft) I TVD(ft) Alert I Minor I Major 17854.94 17851.12 17822.13 4671.23 325.41 32541 MinPt-O-SF [17853.531 17849.711 17820.7 4665.42 356.91 356.91 MinPts 17853.09 17851.86 17820.28 14585 35 0.00 0.00 Surface 17853. 17850.5 17820.2 6988.85 198.80 198.80 MinPts 17853.31 17850.31 1782051 5943.73 243.80 243.80 MInPt-O-EOU I 7175.09 6929.16 6808.06 29.61 1723091 364427 MinPt-CtCt 7175.52 6928.76 8807.25 29.51 17266.92 364448 MinPt-O-EOU 7176.04 6928.85 6807.14 29.46 17285.28 364459 MinPt-O-ADP 7317.61 7050.97 6919.51 27.82 18187.61 3614.32 MinPt-OSF 7585 44 7300.07 7159.24 26.921 19191.36 3585.70 MinPt-O-SF S102-SE6(P2)(Def Plan) Pass 17845 23 17841 36 17812 42 4620.8 325.41 325.41 MinPt-O-SF 17843.64 17839.80 17810 83 4649.00 357.09 35709 MinPts 17843.6 17839.8 17810 83 4645.28 358.76 358.76 MinPt-O-EOU 17843.18 17841.96 17810.37 14577.26 0.00 0.00 Surface 17843.1 17840.6 17810.3 6980.58 198.80 198.80 MinPts 17843. 17840.41 17810.57 6008.94 238.80 238.80 MinPt-O-EOU 1 1140162 11190.14 11084.8'MEM 11071.90 3780.07 MinPt-OSF 11303.41 11089.04 10982. '�'1 12531.14 3773.87 MinPt-0SF 11267.95 11054.61 10948..'malm 13092.79 3752.47 MinPt-O-SF 11260.49 11049.8 maim... 53.70 13158.43 3750.75 MinPt-O-ADP 11259 86' 11049.71 10945.13 53.83 13170.84 3750.37 MinPt-O-EOU • ® 11050.23 10946.15 54.09 13195.63 3749.59 MinPt-CtCt 11280.98 MIIME 10968.51 54.32 13665.73 3732.85 MinPts I 11295.01 11080.52 10973.77 52.90 14172.24 374425 MinPt-O-EOU 11295.56 11080.70 EIMIT, 52.81 14197.96 3744.53 MinPt-O-ADP 11311.42 11092.60 10983.6 14600.75 3744.33 MinPt-O-SF ' 11315.08 11096.19 10987.2 14642.37 3742.25 MinPt-O-SF 11348.84 11125.01 11013.6.man 15172.85 3678.32 MinPt-0SF ' 7459.62 7232.55 7120.67 33.32 1644053 3855.20 MinPt-CtCt 7459.72 7232.50 7120.54 33.30 16443.06 3655.14 MinPt-O-EOU 7459.79 7232.51 7120.52 33.29 16443.92 3655.12 MinPt-O-ADP 7552.44 7319.79 7205.17 32.931 16562.13 3652.53 MinPt-O-SF 10013.26 9756.90 9630.00 39.44 17702.65 3646.79 TD 11408.81MOM .I: I�'r'1 16172.11 3661.09 MlnPts 1111=MEM WIEERMEICI 17702.64 3646.79 MinPts SP05-FN7(P2)(Def Plan) Pap 17847.33 17843.48 17814.5' Y. 325.41 325.41 MinPt-O-SF 17845. 17841.8• 17812.: 4652.41 357.05 357.05 MinPts 17845. 17841.8' 17812.86 4648.47 358.72 358.72 MinPt-O-EOU 17845.20 17843.98 17812.39 14578.91 0.00 000 Surface 17845.2 17842. 17812.3 6982.31 198.80 198.80 MinPts 17845.41 17842. 1781260 6015.77 238.80 238.80 MinPt-O-EOU I 7392.67 7161.61 7047.77 32.45 16586.75 3651.99 MinPt-CtCt 7392.87 7161.41 7047.36 32.40 16599.09 3651.72 MinPt-O-EOU 7393.04 7161.44 7047.33 32.38 16603.29 3651.63 MinPt-O-ADP 7578.73 7332.88 7211.43 31.24 17143.80 3644.29 MinPt-O-SF 7791.18 7539.94 7416.1'ISD 17418.77 3645.36 MinPt-O-SF 8087.24 7825.27 7898.0. 31.2 17937.91 363561 MinPt-O-SF 9025.83 8740.70 8599.71 32.00 19191.36 3585.70 TD SP04-SE5(P2)(Det Plan) Pap 17844.61 17840.76 17811.81=DEE 325.40 325.40 MinPt-0SF 17844. 1781175 4641.97 330.40 33040 MinPt-O-EOU ISI 17840.71 Egling 4646.09 332.07 332.07 MinPts 17844.53 17843.31 17811.72 14578.36 0.00 0.00 Surface r17844.531 17840 9 MEW 4973.03 298.80 298.80 MinPts 7386.65 7156.97 704381 32.62 16514.48 3653.58 MinPt-CICt 7386.79 7156.86 7043.58 32.59 16520.69 3653.44 MinPt-O-EOU 7386.94 7156.89 7043.56 32.57 16523.85 3853.37 MinPt-O-ADP 7447.92 7212.53 70966 32.1 16686.56 3649.91 MinPt-O-SF 7640.64 7396.60 7278.37 31.76 17008.01 3645.96 MinPt.O-SF 8733.58 8476.69 8349.82 34.41 17698.72 3646.81 TD 10213.48 10003.73 9899. 'mail 1107149 3780.03 MinPt-O-SF 10121.77 9909.02 9803.1.MZE 12530.73 3773.92 MinPt-O-SF 10091.23 9879.19 9773.6 NEM 13091.01 3752.52 MinPt-O-SF 10085 95 9875.9. 48.26 13148.04 3751.05 MinPt-O-ADP I9910085 40 875.791 9771.54 48.38 13160.48 3750.89 MinPt-O-EOU 876.22 9772 42 48.57 13184.09 3749.96 MinPt-CtCt 10109.1 I 9900 97 9797.61 48.89 13656.30 3732.86 MinPt-O-EOU 10109.31 9901.00 9797.561 48.86 13668.48 3732.85 MinPI-O-ADP 10125." 9911.06 9804.76 47.62 14171.19 374424 MinPts 10135.52 9917.39 9809.0 MEM 14500.56 3746.30 MinPt-OSF 10137.37 9919.18 9810.:. 14527.23 3748.15 MinPt-O-SF 10140.72 9922.43 9814.0. 14570.87 3745.36 MinPt-O-SF 10183.15 9959.84 9848.9 IIMME, 15172.57 3678.34 MinPt-O-SF MEM MOM 15576.49 3671.77 MinPts 5108-FN6(P2)(Def Plan) Pap 17848.14 17844.29 17844.29 17815.3. w1 325.40 325.40 MinPt-O-SF 17848.0 178442 17815.27 4646.31 330.39 330.39 MinPt-O-EOU U 17848 0 17844.2 17815.271 4649.49 332.05 332.05 MinPts 17848.06 17846.84 17815.25 14581.24 0.00 0.00 Surface [7848.06 17844.4 Erne 4975.43 298.80 298.80 MinPts 7303.11 706929 8954.11 31.69 16680.18 3650.00 MinPt-CtCt 7303.15 7069.231 6854.00 31.68 1668449 3649.93 MinPt-O-EOU Drilling Office 2.0.960.0 Nikaitchuq\Oliktok Point\0115-S4\0115-S4\0115-S4(P5) 9/13/2011 2:38 PM Page 11 of 13 Offset Trajectory Separation Allow Sep. Reference Trajectory Separation Factor Alert Status Ct-Ct(ft)I EOU(ft) Dev.1ftL Fact. MD(ft) 1 TVD(ft) Alert I Minor I Major 7303.24 7069.25 6953.99 31.67 16687.41 3649.90 MinPt-O-ADP 7303.431 7069.29 6953.96 31.65 16693.33 3649.82 MinPt-O-EOU 7304.54 7069.50 6953.73 31.53 16725.38 3649.43 MinPt-O-ADP 7384.52 7118.41 6997.17 30.36 17145.33 3644.27 MinPt-O-SF 7730.80 7468.75 7339.52 29.90 17940.14 3635.42 MinPt-O-SF 7831.42 7586.02 7435.10 29.89 18120.87 3619.52 MinPt-O-SF 8153.73 7878.95 7743.3 18648.83 3595.15 MinPt-O-SF 8196.25 7920.28 7784.00 30.06 18719.96 3593.16 MinPt-OSF 8463.07 8177.63 8036.58 29.99j 19191.36 3585.70 MinPt-0SF S107SE4(P2)(Def Plan) Pass 17845 50 17845 65 17816 69 4631.3 325.41 325.41 MinPt-O-SF 1 17847 831 17844 00 17815 02 4655.11 357.01 357.01 MinPts 17847 83 17843.99 17815 02 4651.02 358.68 358.68 MinPt-O-EOU 17847.37 1784614 17814.56 14580.68 0.00 0.00 Surface 17847.37 17844.81 1 17814 561 6984.10 198.80 198.80 MinPts 17847.57 17844 61 17814 76 6020 66 238.80 238.80 MinPt-O-EOU 8987.95 8777.08 867226'8 11071.94 3780.07 MinPt-O-SF 8885.86 8672.01 8565.8*MMEE 12531.56 3773.83 MinPt-O-SF 8851.87 8638.36 8532..'M' 1 13091.92 3752.49 MinPt-O-SF 8844.58 8633.4'..n, 42.26 13165.16 3750.55 MinPt-O-ADP 8844.*'MEE 8528.96 42.35 13177.58 3750.17 MinPt-O-EOU 8843.6* 8633.76 8529.82 42.53 13202.43 3749.37 MinPt-CtCt 8862.1'MIME $ 42.64 13667.31 3732.85 MinPts 8874.6i ', 41.60 14166.39 3744.16 MinPts 8882.46 8662.95 8554.2 .: 14490.75 3746.26 MinPt-O-SF 8923.56 8699.18 8588.1 MMEE 15173.07 3678.30 MinP1-0SF 7381.19 7149.58 7035.46 32.32 16632.12 3651.00 MinPt-CtCt 7381.39 7149.34 7035.00 32.26 16646.53 3650.68 MinPt-O{OU 7381.67 7149.39 7034.94 32.23 18653.89 3650.52 MinPt-O-ADP 7522.34 7277.80 7156.9 31.1 17145.04 3644.27 MinPt-O-SF 7856.96 7597.41 7489.41 30.68 17817.51 3643.74 MinPt-O-SF 8065.95 7803.71 7674.32 31.16 17932.13 3636.12 TD 8068.351 7806.111 7676 721 31.171 17932.12 3638.12 MinPts SP1O-FN5(P2)(Def Plan) Pass 17851.57 17847.73 17818.76 4849.0 325.41 325.41 MinPt-O-SF 17850.0 17846.1' 17817.21 4859.43 356.97 356.97 MinPts 17850.0 17846.1' 17817.22 4854.89 358.64 358.64 MinPt-O-EOU 17849.57 17848.34 17816.76 14582.48 0.00 0.00 Surface 17847.01 6985.91 198.80 198.80 MinPts 17849.7,M9; 17816.95 6031.17 238.80 238.80 MinPt-O-EOU • 7297.98 7062.35 6946.27 31.42 16780.22 3648.75 MinPt-CICI 7298.97 7061.64 6944.72 31.20 18844.47 3647.97 MinPt-O-EOU 730029 7061.91 31.07 16884.59 3647.47 MinPt-O-ADP 7332.47 7086.86 6965.''MOE 17181.48 3644.05 MinPt-0SF 7606.78 7341.25 7210.2' 1011 18123.48 3619.27 MinPt-0SF 7834.99 7560.23 7424.6 EINEM 18654,70 3594,92 MinPt-O-SF 8050.89 7765.69 7624.86 MUM 19191.36 3585.70 MinPt-O-SF Nikailchuq 3PB1(Def Survey) Pass ,_1.1:1180 18515.671 18484.8 9420.94 51.00 51.00 MinPts 18518.4-MIME. 18485.63 4950.66 250.80 250.80 MinPt-O-EOU 858.6 1 3957.03 379.33 379.33 MinPts 18518.6 11�'g 18485.86 3923.47 387.98 387.98 MinPt-O-EOU 12098.23 11913.81 11823.47 66.94 12268.79 3798.09 MinPt-CtCt 12098.25 ME11311 11823.45 66.93 12289.62 3798.05 MinPt-O-EOU 12098.26 11913.80 ME1= 66.92 12289.90 3798.03 MinPt-O-ADP 12162.78 11975.40 11883.51 66.16 12410.05 3786.82 MinPt-O-SF 12647.31 12461.95 12370.80 69.36 12563.30 3770.66 TD Nikailchuq 3P82(Def Survey) Pass 18517.64 18515.6 18484.8 9420.94 51.00 51.00 MinPts 18518.44 18514.70 18485.63 4950.66 250.80 250.80 MinPt-O-EOU [18518.64 18513.96 18485.831 3957.03 379.33 379.33 MinPts 18518.67 18513.95 18485.86 3923.47 387.98 387.98 MinPt-O-EOU 1 12098.23 11913.81 11823.47 66.94 12268.79 3798.09 MinPt-CtCt 12098.25 11913.80 11823.45 86.93 12269.62 3798.05 MinPt-0{OU 12098.26 11913.80 11823.44 66.92 12269.90 3798.03 MinPt-O-ADP 12162.78 11975.40 11883.51 66.161 12410.05 3786.82 . MinPt-O-SF 12647.31 12461.95 1237080 69.36 12583.30 3770.66 TD Nikailchuq 3PB3(Def Survey) . Pass 18517.64 18515.67 18484.83 9420.94 51.00 51.00 MinPts 18518.44 18514 70 18485.63 4950.66 250.80 250.80 MinPt-O-EOU 18518.6• 18513.96 8485 831 3957.03 379.33 379.33 MinPts 18518.67 18513.95 1848586 3923.47 387.98 387.98 MinPt-O-EOU 1 12098.23 11913.81 11823.47 66.94 12268.79 3798.09 MinPt-CtCt 12098.25 11913.80 11823.45 66.93 12269.82 3798.05 MinPt-O-EOU 12098.26 11913.80 11823.44 66.92 12269.90 3798.03 MinPt-O-ADP 12162.78 11975.40 11883.51 68.161 12410.05 3786.82 MinPt-O-SF 12647.31 12461.95 12370.80 68.36 12563.30 3770.66 TD Nikaitchuq 3(Def Survey) Paas MIIII 18515.6 =ma 9420.94 51.00 51.00 MinPts 18518.4,iMERIE 18485.63 4950.66 250.80 250.80 MinPt-O-EOU L18518.6. 18513.96 - -- -1 3957.03 379.33 379.33 MinPts 18518.6 11 I$$ 18485.86 3923.47 387.98 387.98 MinPt-0-EOU Drilling Office 2.0.960.0 Nikaitchuq\Oliktok Point\0115-S4\0115-S4\0115-S4(P5) 9/13/2011 2:38 PM Page 12 of 13 1 i 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 • 14458.90 14302.09 14224.57' 93.24 10641.45 374212 MinPt-0SF 1 12098.23 11913.81 11823.47 66.94 12268.79 3798.09 MinPt-CtCt 12098.25 11913.80 11823.45 66.93 12269.62 3798.05 MinP1-0-EOU 12098.26 11913.80 11823.44 66.92 12269.90 3798.03 MinPt-O-ADP 12162.78 11975.40 11883.51 68.161 12410.05 3786.82 MinPt-O-SF 12647.31 12461.95 12370.80 89.36 12563.30 3770.66 TD Nikaitchuq 1(Def Survey) Paas 1.511MIBIEHMMEERTMIEfi 12542.76 3772.66 MinPts .116=MEM MEME11 MEM 12536.30 3773.12 MinPts EmizE12366.39 12274.07 67.97 12533.43 3773.83 MinPts 12554.33 12366.40 Mg 67.97 12533.58 3773.82 MinPt-O-ADP • 12564.15 12375.86 12283.38® 12541.74 3772.77 MinPt-O-SF 13215.14 1302461 12931.0 12818.18 3758.89 MinPt-O-SF 162640. 16067 85 15970.58 83.60 13922.64 3738.30 MinPts 17347.52 17150.43 17052 69 88 74 14305 48 3745.17 TD Nikaitchuq 4PB1(Def Survey) Pets 06 18555.96=MIMI 9441.82 51.00 51.00 MinPts 18558.46• 18525 65 6508.53 165.92 165.92 MinPt-O-EOU 15585 4•' 15 .' 18526 68, 3893.90 404.56 404.55 MinPts 18559.511. 18526.70 3860.55 413.44 413.43 MinPt-O-EOU 12805.97 12621.48 12530.75 70.56 12465.67 3780.88 TD 1 12291.81 12112.45 12024.63 69.97 11964.49 3799.83 MinPt-CtCt 12291.81 12112.441 12024.63 69.96 11964.58 3799.83 MinPts 12295.42 12115.90 12028.00 69.921 11967.76 3799.84 MinPt-O-SF Nikaitchuq 4(Del Survey) Pass 18557.92 18555.96 18525.11 9441.82 51.00 51.00 MinPts 18558.46 18555.61 18525.65 6508.53 165.92 165.92 MinPt-O-EOU F18559.49 18554.73( 18526.61 3893.90 404.56 404.55 MinPts 18559.51 18554 71 18526 70 3860.55 413.44 413.43 MinPt-O-EOU 13412.09 13193.37 13085.73=Ma 14492.25 3746.27 MinPt-O-SF 13468.27 13248.75 13140.69 82.31 14539.79 3746.04 TD I 12301.091 12121.10 12032.96 69.76. 11995.39 3800.00 MinPl-ClCl 12301.1`°11 12121.0 1203290 69.74 11999.31 3800.02 MinPt-O-EOU 12301.15 12121.0 12032.884 69.72 12002.47 3800.04 MInPt-O-ADP MEM 12114.57 12024.93 88.58 12174.41 380078 MinPt-CtCt 12297.80 wan 12024.47 68.40 12201.77 3800.40 MinPt-O-EOU 12298.09 12114.••Ma= 88.31 12215.55 3800.08 MinPt-O-ADP 12303.8.�.r 12022.50 66.47 12528.45 3774.16 MinPt-O-EOU 12303.84 12115.03 MEME 66.45 12531.31 3773.86 MinPt-O-ADP 12312.21 12122.51 12029. • 66.19] 12660.47 3763.61 MinPt-O-SF 12383.94 12187.75 12091. • 64 34 13093.26 3752.46 MinPt-O-SF 13019.81 MIME 65.37 13669.20 3732.85 MinPts 13246.43 13034.77 12930.7.MOO 14143.70 3743.68 MinPt-O-SF Nikaitchuq 2(Def Survey) • Pap 19107.9. 19075.11 4083.58 457.70 457.67 MinPt-O-EOU 19115.02 19092.72 19082.2101 984.03 973.76 MinPt-O-SF 1 16561.66 16400.69 16321.30 104.29 993444 3658.54 MinPt-CtCt 16561.66 16400.68 16321.28 104.28 9934.87 3656.60 MinP8-O-EOU 16561.67 16400.68 16321.28 104.28 9935.09 3658.63 MinPl-0-ADP 16598.21 16436.41 16356.63 104.011 9965.63 3662.86 MinPt-O-SF 20335.00 20176.72 20098.46 129.91 10487.82 3726.70 TD Drilling Office 2.0.960.0 Nikaitchuq\Oliktok Point\0115-S4\0115-S4\0115-S4(P5) 9/13/2011 2:38 PM Page 13 of 13 Schlumberger -TRAVELING CYLINDER PLOT • Client: ENI NoGo Region EOU's based on: Well: 0115-S4 Oriented EOU Dimension N Field: Nikaitchuq Structure: Oliktok Point NoGo Region Anti-Collision rule _ Date: September 08,2011 used:Minor Risk-Separation Factor North 0-900'md 350 0 10 340®�� 20 33�•�70lear 30 -E 3201P� /���/�= , i _. \ 310 ,, 50 j�j i Pi`t • 50 kit �i i'1 A4!f1q ' ç 300 , ,li 1� / ( \ 8-04P61 11, i__ - ,, * ?DJ Ill/(id( 4�i • `i 1P.' 70 1 ► ( 1t E \ i � 011,it iirir09-S1 i ' �l I A.,i' /, ��• `,. -lir► •,-1�,�,1 280 ,'e'w"Z. Ark �`�.'��,- ,0 `. t\\\\\k \ \ �� • 'i„,...,,....,....._ 8P:2/'="�����_���\ \ ' 6.:•-.\ `N\`\\``i//%If ;.:.• •1101-01PB1 /• . r \ \\ \ `., /. 270 LI��I% i�:Z/I�j ,��''�4�\ `= 1 ,I� �, �� S `\ _.i/�I� �I' 90 i�. ♦ -i `I • :1 . IA\0.7:-.0 i�.�.-_.____'►'moi 4P,! i' '; �:� ���' 260 t% �k11111 V �► ,at iii. ,Y�. '?' �� `Nom • `',-6,4•••,.t..:-.....;;;-...—. ' = :.-.•0. 100 *4 4 250 tP7'.11110ir.� , .. 11111;,'',► 110 . ..,, vik i,,t-z,:‘,...,,„-_,,alfill,. tot. 40.,,,,„ ,-; 240 4,41 � flip"/��`�� ��lip #_, 120 Olt " ,230 ; ,,,. / i,,���' ,. ► i.___ •� 4. 40 130 . , '. /;t - -(� +.� 220 ,..4 , 40 / Cl'/ 1 i 140 210**-74*-0A 4/"41APIAI.x'1,147.•441:k Ilk Iso 200 r .,,., jib. 160 190 180 OP1iPB1 Well Ticks Type: MD on 0115-S4(P5) Calculation Method: Normal Plane Ring Interval: 5.00 ft Azimuth Interval: 10.00 deg Scale: 1 INCH=25.00 ft Schlumberger TRAVELING CYLINDER PLOT Client: ENI . NoGo Region EOU's based on: Well: 0115-54 Oriented EOU Dimension - Field: Nikait chug Structure: Oliktok Point NoGo Region Anti-Collision rule A., Date: September 08,2011 used:Minor Risk-Separation ---ww IP' V Factor 4 tfr North 900md- 13-3/8" 0 350 10 340 20 .4k 1.. .„.iwim...... ivror fr 4 7011...74., - . . 13_03 Alk\tiiiik 140 320 0 Ai 4 /1116,...-- •,,,,,t,..-4,.....-...,-/ ,,,..„........ _. . -...:.......„...„ _ ,,,,e...,4 31. Or e• „0„,,,r__41.4741-i ,,,,„,...,„,..„....,,,,,,, , ,• ,494/4v / 4 i frlitillillINVio. r 50 anew .41,4-; --,7,,:<..,, ..vlit"....1111k I 'h* ithrliT;11,;,0,1.,Viklialp\-.. fllipAllp' ilitex \1; fk .1 /ilk Aft ,,„ir ,1414, livt.T41/4 4•A'w '1 /ii. •1‘,FAQ, '' / fir iiii 1314kilikVi%041-4 300 I/AllM A ,,,...,WA;rg A fl .1 .a /11.-•,....Wroki, l'°..!;*.4C. .-... %A_ N,r-yz-ul f• 11,0jilivIV Niailiti . , 104 ,00.111rOtittP: ix1:*14,g1 , ...,..1%.„, 41frgri, ;_' -7- '• ! • N TivTil WW_k. ' e'illif ' .1 till' • i.41 P411191111i* i*V13% 2--i.:C*1•7 (\-:. VAIN,. ' *Ai' 4'iill i AW‘*'.4.--14,. wil \ ;. 290 ft.Olillivv----:V.ik i'V 'I• 5441i'41#* ' 'Icirf.l4 E, !---• -...%!;Alr.4,7° A Al‘ /f1,,,,;::.01-r.'•:::.;, /\ via. 41,4—rt 0.. /4*4 '11*.t.- ,. .‘;0*Al&Wte.. .ois•I' AV ,.4.!;•oali*A‘%0/ / N.410*ilt Opal,'At&INCOVSA:',': !,,:` •:,,tstNte4\b,,tiii 4::". 11 v, ';',..:-_-_-... -, •• ). .00, AI feu ' 41*r47/1106fArr71-ft VO I iigk IPAP.:94V; .- .., ,_-`7--- .8131_01PB1 280 l' '4. w,300i J 11 \ '''..,..,44641leos`,i,...0,‘ Iwo * 4 .‘2- ,„ . - ..,i---- ..:.-_,--,-.--.-.,.., 1 . '.. : 1 I I- ........•.‘slit.,, ..„._ V1/1 ) - --"'-. Tft,c-10-0.."jr.4,iits7..;t:;, k''AsV;#1:j1411.111.1.011 -.•-4.,-IP . "-k\\_ 1!**1* ,4fAk-,ft,*;446%4fiot,:t1.1:1/t:::: `11'Alpv4i Ifjp"..WIIIV r K%-witi: 270 ' ..... _, 4,, 1111.41111P*,_ 411„,4111.t.s..-f- --..." 111111100011111111111100c4 , N....,L., ....,At%.4,16;411114%.,_ 4,4:41p/Iarizieir. .i.-„ 21.7„:.,..a.6,-!.._,T,,,, ..„"..-----•- / ....:74N11111$1,..11W!..:‘`..&%67#41116.:'41e7f4"-10'ef'^v1 , r.---_.--44•11•7'-- (.4, -,,,,-.....„..441.17 ,7_?_,.-41.....,-,:*:-7:-&- ....... ---w. , . _,..._ ......,-„(4.„, \tw.,..;,.. .. 260 411 # - "Illillilk ..".razt1,74. .,..-- 1 • 4$0..t..0*-1:-"rirri'qtN Q0 , '!. ,01.1"..111ftleftrAmIt. 714:'; .''...N66-'11%.•...___ Ail..1 111----—-4 1 . 1.. .......:.....0,-,w..40,.... 1 0 401 •", '•-•:.';;;.=-"""....144.k., O' .. c°' ,A—..r.o.".211111,1_,••••14 %.•:-AM....-%-ler.54:4%,%•, Q. 110 f• '''1. .44/1/WAR 0.:...•„,0'1.:rt I I Wreili4.k! ti 4 . ,.---....•6711111111,-ag.•,7*.,ocd-bli'ro- -vr-j--4!".:•••, o , ."', \ ••••• -. Nair 44r 4-.'''•it.-,,,,00,4.:—-4'-tvii• *I • 08 -8) ,,ey,1/111110'ai.40''.4;•:.;•iii,riOevilAdrd*P4:' ., A 240 ' rf,,j0.111MiliVIIWV/;-*- IRVO./41‘"44:19-jiii 120 30 *1`7 ?1,6fint 1 2 14 Ati ir4 IIL %AI 'Nt,Ntp.,.i...Noas°t.s.At•kiT‘:tt.4N,W4r,•,1:Y'1*74,WZ0•.•1A/1Sw%W.I1a,l4 t.Y04 130 1, air " 1 1 1e *I . •.., fik.k,,,,.. ,a1 •-1101.2*-''',%'''.- ligiroso,_,,,e4.,/',77:;:/•- zo . _ .........„....,,, :1740440,11, _007NAK4aliwaiNI ,4461,4*, A.,,,.... 20 e - - -tv%ap44,z141..,.- 1 • •t,VAIWR8 W2) 190 180 Well Ticks Type: MD on 0115-S4(P5) 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 NoGo Region EOU's based on: Well: 0115-S4 Oriented EOU Dimension 9V Field: Nikaitchuq Structure: Oliktok Point NoGo Region Anti-Collision rul: A= Date: September 08,2011 used:Minor Risk-Separation Factor '4 f�� North 1 3-3/8"-9-5/8" 350 0 10 340 320 20 330 300 �� 30 280 "� 32� _ 260 /////'Ailab, bilk 40 �- ' I. 2r.-.114701/1/10-illi � 310 ll.' -.. A`=r q .1 ! �•�:--von.z% c'90 09 300=s f` ��`- � /, ,I`` ,941 * / ' � kAIL ilk k,\�.' 60 Alik ll'ik IV NI leb0414*.i,-10124 p% 290 /AS. i .. \ 4((0 \itk‘etl,: N 1,114,yitioqvlat-Igii!iz.;,:e-; /c.v. • li• NIO 'ss‘t'llili., ii.1104141,4t4ti'4,-,--224.-iitfi" iteliNt,. i , ib.;‘, ,,‘\,%yo*I ,V4V\t!1 1.04VEllikait,?:411:4-1.V1114 1 p 280 (VIA. 1, ' iiiii1;1110/16.--- 1:31` ;.-_411tr. -.41."----.7:-1.-:!%7: 1071reil'il V744k ItA 141 8° - IFS 40 )s,,,, Vir.:-_,4,11P1-etk--'.. 4Atiii INi 270 k ,, .1. '' Ill I,�,'1// oc20 `Ii` =. ►•''�'``l \ so•^‘;',V.;:. \ 1.61 Illtiri< 0, ,/ 4 03 _ , ‘,Ikb,., 'lb.„,..,_.. 4, .1\ 260iiiiii11 � ' �_,hr��- ./4 , , o o ,`� ��,,�� 100 X11ii.leg _ s ♦♦ S t• --4..i 250 �Sr,�► �1 /fr.��,aWg- •*�.,iti` 1rrV it 110 vi.,...‘,4.70„,.....04...... `►�\ . . \ aiwit • Ii1,��'! .\ %;rh 240 ,20 4 `` 4t, .ate /,./ `°•4;� OP 14-S3 230 a ,�`- =�j'�I�:i OP 1 -01 ' �.�: `1� 220 4,117.,, ' \iI 140 2 '` 0 20 � o 7101111w 190 4111.91 170 Well Ticks Type: MD on 0115-S4(P5) Calculation Method: Normal Plane Ring Interval: 20.00 ft Azimuth Interval: 10.0 deg Scale: 1 INCH= 100.00 ft Schlumberger TRAVELING CYLINDFRPLO T Client: ENI NoGo Region EOU's based on: Well: 0I15-S4 Oriented EOU Dimension N Field: Nikaitchuq Structure: Oliktok Point NoGo Region Anti-Collision rul- 4111Date: September 08,2011 used:Minor Risk-Separation Factor 4 North 9-5/8"-TD 350 0 10 340 �.�ar 80_ 20 33 ' �� 450 �;',I 30 ►•pri 320 ,i00,..---3341' 11101%‘;.-katd.fiRM 1,&420 ; �'/ 40 _ 360 lir r 31044111 '_��• j,- 4 50 Alk 300 0 AO/ 4/',1. ����� � M4%, S 60 OSPIP4‘. I 011W4 Oviak‘ 1 A TP, 41 10, lie, 01 # 90 ;,�b ` / ' , Ili\411114 70 N4S,, `,' ,9055 '�280 / " 1ti�.._ 117,,,A,f ( 400, 80 411110 ' 60 1116.001/111 , 270 .. r ```„ " 3° 90 o to*``��1 mac' ,� � ,4 1 otic ��260 " , a oc, 100 li 7"'" -::-.411 ' 111111111 c.s4 , if V 250 0� . ^ 411 ,■: . cP oww off' w 7 110 240 ` ti!3$%). : ,20 a...-. 14 f 41"111110 2A4i A lop ii,iiioo 140 210 ���50 200 160 190 1Rn 170 Well Ticks Type: MD on 0115-S4(P5) Calculation Method: Normal Plane Ring Interval: 20.00 ft , Azimuth Interval: 10.0 deg Scale: 1 INCH=150.00 ft 1 Schkmdierger 0115-S4(P5)Anti-Collision Report Analysis Method: 3D Least Distance Distance Unit: ft Depth Interval: Every 100.00(ft)Measured Depth Azimuth Unit: deg Step-down Trajectory: Reference Trajectory TC Azimuth Reference: North Analysis Date-24hr Time: September 28,2011-11:46 North Reference: True Analysis Machine: DEC-AKA-980 Client ENI Database I Project: localhost\drilling-nikaitchuq Version/Patch: 2.0.960.0 NOTE:Measured Depth is referenced to individual borehole elevation. TVD,NS,EW are referenced to the reference trajectory's wellhead location and borehole elevation. A minimum of 0.300 m is always included for borehole diameters. All local minima indicated. Results filtered:Depth 11050.00 ft<=MD<=19200.00 ft,Ct-Ct separation<=1500.00 ft Anti-Collision Rules Used Rule Set Name D8M AntiCollision Standard 0002 05.1 Exemption Risk Level: Minor Rule Name Risk Level Rule Tvoe Rule Label NoGo Rule SLB Alert Zone Threshold OSF=5.0 S002 v5.1 Alert Ratio OSF=5.00 SLB Minor Risk Threshold OSF=1.5 S002 v5.1 Minor Ratio OSF=1.50 X SLB Major Risk Threshold OSF=1.0 S002 v5.1 Major Ratio OSF=1.00 SLB Surface Rule 0002 v5.1 Major Fixed MAS=32.81(0) SLB Alert Zone Threshold CtCt<=15m S002 v5.1 Alert Fixed MAS=49.21(0) Drilling Office 2.0.960.0 Nikaitchuq\Oliktok Point\0115-S4\0115-S4\0115-S4(P5) 9/28/2011 11:46 AM Page 1 of 82 Reference Trajectory Summary Field: Nikaitchuq Well: 0115-S4 Structure: Oliktok Point Borehole: Ol15-S4 Slot: OP/5 Trajectory: 0115-S4(P5) Client: ENI Type: Def Plan Coordinate System: NAD27 Alaska State Plane,Zone 04,US Feet North Reference: True Grid Convergence Angle: 0.12836652" Grid Scale Factor: 0.999900315 Magnetic Declination: 20.614° Magnetic Declination Date: April 02,2012 Magnetic Model: BGGM 2011 Reference Point: Northing Easting Elevation Structure Unc.l'led l Slot Unc.11sdl 6036516.890(ftUS) 516640.370(ftUS) 52.200(ft)MSL 0.000(ft) 0.000(ft) Trajectory Error Model:ISCWSAO 3-D 95.000%Confidence 2.7955 sigma Surveying Prog: Description MD From(ft) MD To(ft) EOU Freq(ft) Survey Tool Type Hole Diameter(in) Borehole I Survey 0.000 40.000 1/100.000 SLB_GYRO-MWD-Depth Only-No Global 16.000 0115-S4/0115-S4(P5) 40.000 1350.000 1/100.000 SLB_GYRO-MWD-No Global 18.000 0115-S4/0115-S4(P5) 1350.000 2410.555 1/100.000 SLB_MWD+GMAG-No Global 16.000 0115-S4/0115-S4(P5) 2410.555 11051.615 1/100.000 SLB MWD+GMAG-No Global 12.250 0115-S4/0115-S4(P5) 11051.615 19191.362 1/100.000 SLB_MWD+GMAG-No Global 8.750 0115-S4/0115-S4(P5) Drilling Office 2.0.960.0 Nikaitchuq\Oliktok Point\0115-54\0115-54\0115-S4(P5) 9/28/2011 11:46 AM Page 2 of 82 Offset Trajectory Summary Offset Selection Criteria: Wellhead distance scan:Global within 60201.86 ft Offset Selection Criteria: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 Selection Summary Wells Selected:57 Boreholes Selected:76 Definitive Surveys Selected:39 Non-Def Surveys Selected:3 Definitive Plans Selected:37 Non-Def Plans Selected:0 Total Trajectories:79 Offset wells whose minimum OSF is less than 1500 are displayed in this report. Trajectory Borehole Well Type Nikaitchuq 1 Nikaitchuq 1 Nikaitchuq 1 Def Survey OP23-W W02 OP23•W W02 OP23-W W02 Def Survey OP18-O8PB2 OP18-08PB2 OP18-08 Def Survey 0113-03(P6) 0113-03 0113-03 Def Plan Oliktok Point 1-2 Oliktok Point 1-2 Oliktok Point 1-2 Def Survey OP16-03 OP16.03 OP16-03 Def Survey OP18.08 OP18-08 OP18-08 Def Survey 0PO4-07PB1 0PO4-07P81 OPO4-07 Def Survey Oliktok Point I-1A-108(P5) Oliklok Point 1-1A406 Oliktok Point I-1 Def Plan OP05-06 OP05.06 OP05-06 Def Survey OP10-09 OP10-09 OP10-09 Def Survey OP03-P05PB1 OP03-P05PB1 OP03-P05 Def Survey S120-N4PB1(P1) S120-N4PB1 S120-N4 Def Plan SP113-N5(P3) SP18-N5 SP18-N5 Def Plan SP36-W5(P2) SP36-W5 SP36-W5 Def Plan Tuvaaq ST 1 Tuvaaq ST 1 Tuvaaq ST 1 Def Survey OP09-S1 OP09-S1 OP09-S1 Def Survey OP17-02PB1 OP17-02PB1 OP17-02 Def Survey SD37-DSP1 current SD37-DSP1 SD37-DSP1 Non-Def Survey SP04-SE5(P2) SP04-SE5 SP04-SE5 Def Plan 0l11.01PB1 OP11-01PB1 0111-01 Def Survey Nikaitchuq 3PB2 Nikaitchuq 3PB2 Nikaitchuq 3 Def Survey Oliktok Point l-2PB1 Oliktok Point 1-2PB1 Oliktok Point 1-2 Def Survey 0106-05 current 0106.05 0106-05 Non-Def Survey SP11-N7(P2) SP11-N7 SP11-N7 Def Plan 0107.04 0107-04 0107-04 Def Survey 5119-FN2(P2) S119-FN2 SI19-FN2 Def Plan 5114-N6(P2) $114-N6 S114-N6 Def Plan Oliktok Point 1-1 Ohklok Point 1-1 Oliktok Point I-1 Def Survey S120-S2(P2) S129-S2 S129-S2 Def Plan OP05-06PB2 0P05-06PB2 OP05-06 Def Survey OPO4-07 OPO4-07 OPO4-07 Def Survey SP33-W3(P2) SP33-W3 SP33-W3 Def Plan Nikaitchuq 2 Nikaitchuq 2 Nikaachuq 2 Def Survey SP10-FN5(P2) SP1O-FN5 SP10-FN5 Def Plan 0111-01 0111-01 0111-01 Def Survey SP22-FN1(P2) SP22-FN1 SP22-FN1 Def Plan OP05-08PB1 OP05-06PB1 OP05-06 Det Survey Nikaitchuq 3 Nikaitchuq 3 Nikaitchuq 3 Det Survey Sx34-N Sand(P2) Sx34-N Sand Sx34-N-Sand Det Plan SP24-SE1(P2) SP24-SE1 SP24-SE1 Det Plan OP21-WW01(P3) OP21-WWO1 OP21-WW01 Def Plan OP22-W W03(P1) OP22•W W03 OP22-W W03 Det Plan SP3O-W 1(P2) SP30-W 1 SP3O-W 1 Def Plan SP16-FN3(P2) SP16-FN3 SP16-FN3 Def Plan 0P08-O4PB1 OP08-04PB1 OP08.04 Def Survey SP23-N3(P3) SP23-N3 SP23-N3 Def Plan OP12-01 OP12.01 OP12-01 Def Survey S120-N4(P4) SI20-N4 S120-N4 Def Plan OP26-DSP02 0P26-DSP02 0P26•DSP02 Def Survey OP03-P05 OP03-P05 OP03-P05 Det Survey OP03-P05PB2 OP03-P05P132 OP03-P05 Det Survey SP05-FN7(P2) SP05-FN7 SP05-FN7 Def Plan Kigun 1 PB1 Kigun 1 PB1 Tuvaaq ST 1 Def Survey Nikaitchuq 4PB1 Nikaitchuq 4PB1 Nikaitchuq 4 Det Survey Nikaitchuq 3PB3 Nikaitchuq 3PB3 Nikaitchuq 3 Det Survey SI17-SE2(P2) S117-SE2 5117-SE2 Def Plan $125-N2(P2) SI25-N2 SI25-N2 Def Plan 5135-W4(P2) S135-W4 S135-W4 Def Plan Kigun 1 Kigun 1 Tuvaaq ST 1 Def Survey OP08-04 OP08-04 OP08-04 Def Survey SI08-FN6(P2) 5108-FN6 5108-FN6 Def Plan Nikaitchuq 4 Nikadchuq 4 Nikaitchuq 4 Def Survey Nikaitchuq 3PB1 Nikaitchuq 3PB1 Nikaitchuq 3 Def Survey 5102-SE6(P2) 5102-556 5102-SE6 Def Plan 0P18-O8PB1 OP18-O8PB1 OP18-08 Def Survey SD37-DSP1(P4b) SD37-DSP1 SD37-DSP1 Det Plan 0124-08(P9) 0124.08 0124-08 Det Plan SPO1-SE7(P2) SP01-SE7 SP01-SE7 Def Plan 0106.05(P9c) 0106-05 0106-05 Def Plan SP27-N1(P3) SP27-N1 SP27-N1 Def Plan SI07-SE4(P2) S107-SE4 SI07-5E4 Def Plan 0106-05 MWD-Standard 0106-05 0106-05 Non-Det Survey SP12-SE3(P2) SP12-SE3 SP12-SE3 Def Plan Oliktok Point l-2PB2 Oliktok Point I-2PB2 Oliktok Point 1-2 Def Survey 5132-W2(P2) SI32-W2 S132-W2 Def Plan OP14-S3 OP14-S3 OP14-S3 Def Survey 5113-FN4(P2) SI13-FN4 5113-FN4 Def Plan iI 0120-07(P14) 0120-07 0120-07 Def Plan Drilling Office 2.0.960.0 Nikaitchuq\Oliktok Point\O115S4\0115-S4\0115-54(P5) 9/28/2011 11:46 AM Page 3 of 82 Field: Nikaitchuq Well: OP10-08 Structure: O9ktok Point Borehole: OPIO-08 Slot: OP10 Trajectory: OP10-08 Client: ENI Type: Oaf Survey Coordinate System: NAD27 Alaska State Plane,Zone 04,US Feet North Reference: True Grid Convergence Angle: 0.12874865' Grid Scale Factor: 0.999900316 Magnetic Declination: 21.27r Magnetic Declination Date: January 25,2011 Magnetic Model: BGGM 2010 Reference Point: Northing Eastina Elevation Structure Unc.(1sd) Slot Unc.(tsd) 6036543.170(ftUS) 516889.840(ftUS) 53.130(ft)MSL 0.000(ft) 0.000(9) Traiectory Error Model:ISCWSAO 3-D 95.000%Confidence 2.7965 sigma Surveying Pros: Description MD From(ft) MD To(ft) EOU Freq Survey Tool Type Hole Diameter(in) Borehole I Survey 0.000 40.930 Act-Stns SLB_GYRO-MWD-Depth Only-No Global 16.000 OP10-09 I OP10-09 40.930 1016.850 Ad-Stns SLB_GYRO-MWD-No Global 16.000 OP10.09 I OP10-09 • 1016.850 2404.150 Ad-Stns SLB_MWD+GMAG-No Global 16.000 OP10-09 I OP10-09 2404.150 11191.730 Act-Stns SLB_MWD+GMAG-No Global 12.250 OP10-091 OP10.09 11191.730 19146.000 Act-Stns SLB_MWD+GMAG-No Global 8.750 OP10-09 I OP10-09 Reference Cylinder North EOU-EOU Intersection MD Reference TVD Reference NS Reference EW Offset MD Offset TVD Offset NS Offset EW Azim Ct-Ct Distance Clearance OSFAngle Trace S (II) (ft) (ft) (ft) (ft) (ft) (ft) (ft) (°) (F) (ft) ( All local minima indicated. Results filtered:Depth 11050.00 ft<-MD<=19200.00 8 Results filtered:Cl-Ct separation<=1500.00 ft Results highlighted:Ct-Ct separation r_1320.00 ft 13663.94 3732.85 9847.23 -6022.24 12936.95 3698.02 8896.82 -6675.90 215.93 1154,02 891.16 440 3.58 1 13700.00 3733.08 9867.50 -6052.06 12964.90 3696.18 8912.59 -6698.91 216.05 1153.96 891.23 4.40 4.74 1 14490.71 3746.26 10313.09 -6705.09 13768.37 3679.01 9365.89 -7361.40 217.75 1154.31 872.35 4.10 1.65 1 14504.56 3746.30 10320.91 -6716.53 13776.81 3678.84 9370.69 -7368.35 217.69 115426 872.49 4.11 1.07 1 1470000 3738.15 10429.63 -6878.66 13913.96 3680.10 9444.50 -7483.90 216,48 1157.66 876.90 4.13 6.71 1 15760.54 3671.35 10978.22 -7780.68 14996.37 3658.36 10059.56 -8372.36 210.51 1092.78 784.59 3.55 3.10 1 16100.00 3662.89 11147.39 -8074.86 15280.92 364096 10204.76 -8616.41 211.06 1087.34 777.39 3.52 2.98 1 16171.23 3661.11 11182,89 -8136,59 15342.01 3636.22 10234.94 -8669.31 211.23 1087.67 777.32 3.51 2.74 1 16200.00 3660,47 11197.20 -8161.54 15366.92 3634.60 10247.11 -8690.99 211.21 1087.96 777.46 3.51 2.16 1 16600.00 3651.70 11396.15 -8508.44 15742.90 3632.55 10417.99 -9025.66 210.87 1106.66 789.17 3.49 1.99 1 17500.00 3645.83 11841.48 -929047 16556.01 '3634.24 10747.97 -9768.09 209.87 1193.32 865.01 3.64 5.76 1 18000.00 3630.15 12085.38 -9726.28 17071.71 3628.36 10945.53 -10244.32 209.57 1252.04 908.52 3.65 5.47 1 18600.00 3597.07 12376.98 -10249.47 17693.51 3596.11 11189.53 -10814.90 209.34 1315.20 954.13 3.65 4.15 1 18900.00 3590.31 12523.52 -10511.14 17996.20 3587.59 11318.19 -11088.73 209.47 1336.57 967.73 3.63 4.02 1 19191.36 3585.70 12866.05 -10765.22 18264.30 3577.29 11425.70 -11334.07 209.72 1364.60 991.21 3.66 4.76 1 End of results • Drilling Office 2.0.960.0 Nikaitchuq\Oliktok Point\0115-S4\0115-S4\0115-S4(P5) 9/28/2011 11:46 AM Page 14 of 82 Field: Nikaitchuq Well: 0111-01 Structure: Oliklok Point Borehole: 0111-0I Slot: OP// Trajectory: 0111-01 Client: ENI Type: Del Survey Coordinate System: NAD27 Alaska State Plane,Zone 04,US Feet North Reference: True Grid Convergence Angle: 0.12869420` Grid Scale Factor: 0.999900316 Magnetic Declination: 21.434' Magnetic Declination Date: October 07,2010 Magnetic Model: BGGM 2010 Reference Point: Northinc Eastino Elevation Structure Unc.(1sd) Slot Unc.(1sd) 6036539.390(ftUS) 516682.790(ftUS) 53.250(8)MSL 0.000(fl) 0.000(ft) Trajectory Error Model:ISCWSAO 3-D 95.000%Confidence 2.7955 sigma Surveying Pros: Description MD From(ft) MD To(ft) EOU Freq Survey Tool Type Hole Diameter(In) Borehole I Survey 0.000 41.050 Act-Stns SLB_GYRO-MWD-Depth Only-No Globe 16.000 OP11-01PB1/0111-01PB1 41.050 1306.760 Act-Stns SLB_GYRO-MWD-No Globe 16.000 OP11.O1PB1/0111-01PB1 1306.760 2267.280 Act-Stns SLB_MWD+GMAG-No Globe 16.000 OP11-01PB1/0111-01PB1 2287.280 4890.650 Act-Stns SLB_MWD+GMAG-No Globe 12.250 OP11.OIPB1/0111-01PB1 4890.650 5917.000 Act-Stns SLB_MWD+SAG-No Globe 12.250 OP11.01PB1/0111-01PB1 5917.000 6317.770 Act-Stns SLB_MWD+GMAG-No Globe 8.500 OP11.01PBI/Olit-01PB1 6317.770 10594.000 Act-Stns SLB MWD+GMAG-No Globe 8.500 0111-01/0111.01 Reference Cylinder North EOU-EOU Intersection MD Reference TVD Reference NS Reference EW Offset MD Offset TVD Offset NS Offset EW Azim Ct-Ct Distance Clearance OSFAngle Trace# (ft) (ft) (ft) (ft) (ft) (ft) (ft) (ft) (`) (9) (ft) () All local minima indicated. Results filtered:Depth 11050.00 fl<=MD<=19200.00 ft Results filtered:Ct-Ct separation<=1500.00 ft Results highlighted:Ct-Ct separation<=1320.00 ft 1105161 3778.30 8235.57 -3971.73 10594.00 3686.56 7051.43 -4234.07 222.27 1218.31 108140 9.07 9.89 1 11071.61 3780.04 8248.37 -3987.00 10594.00 3686.56 7051.43 -4234.07 222.27 1225.75 1092.66 927 9.89 1 11100.00 3782.34 826693 -4008.69 10594.00 3686.56 7051.43 -4234.07 222.54 1239.54 1109.04 9.56 9.43 1 11200.00 3787.70 8330.26 -4085.56 10594.00 3686.56 7051.43 -4234.07 223.60 1291.39 1169.88 10.71 8.14 1 11222.61 3788.32 8344.60 -4103.03 1059490 3686.56 7051.43 -4234.07 223.86 1303.78 1184.26 1099 7.92 1 11300.00 3790.05 8393.65 -4162.88 10594.00 3686.56 7051.43 -4234.07 223.88 1348.09 1235.24 12.04 7.92 1 11400.00 3792.29 8457.03 -4240.18 10594.00 3888.56 7051.43 -4234.07 223.86 1409.59 1304.03 13.59 7.92 1 11500.00 3704.52 8520.42 -4317.49 10594.00 3888.56 7051.43 -4234.07 223.86 1475.31 1378.31 15.36 7.92 1 End of results • Drilling Office 2.0.960.0 Nikaitchuq\Oliktok Point\OI15-S4\0115-S40i15-S4(P5) 9/28/2011 11:46 AM Page 39 of 82 Field: Nikaitchuq Well: OP08-04 Structure: Oliktok Point Borehole: OP08-04 Slot: OP08 Trajectory: OP08-04 Client: ENI Type: Def Survey Coordinate System: NAD27 Alaska State Plane,Zone 04,US Feet North Reference: True Grid Convergence Angle: 0.12885757° Grid Scale Factor: 0 999900317 Magnetic Declination: 21.564° Magnetic Declination Date: July08,2010 Magnetic Model: BGGM 2010 Reference Point: Northing Eeetjg9 Elevation Structure Unc.(lsdj Slot Unc.11sd) 6036550.670(ftUS) 516703.940(SUS) 53.300(ft)MSL 0.000(ft) 0.000(ft) Trajectory Error Model:ISCWSAO 3-D 95.000%Confidence 2.7955 sigma Surveying Prog: Description MD From(ft) MD To(ft) EOU Freq Survey Tool Type Hole Diameter(in) Borehole I Survey 0.000 41.100 Act-Stns SLB_GYRO-MWD-Depth Only-No Globe 16.000 OP08-04PB1/OP08-04PB1(Projected-Up) 41.100 41.100 Act-Stns SLB_GYRO-MWD-Depth Only-No Gbba 16.000 OP08-04PBI/OP08-04PB1 41.100 834.520 Act-Stns SLB_GYRO-MWD-No Globe 16.000 OP08-04PB1/OP08-04PB1 834.520 2261.410 Act-Stns SLB_MWD+GMAG-No Gbba 16.000 OP08-04PB1/OP08-04PB1 2261.410 4954.890 Act-Stns SLB_MWD+GMAG-No Globe 12.250 OP08.O4PB1/OP08-O4PBI 4954.890 8059.610 Act-Stns SLB_MWD+GMAG-No Gbba 8.500 OP08-O4PB1/OP08-04PB1 8059.610 11240.000 Act-Stns SLB_MWD+GMAG-No Globe 8.500 OP08-04/OP08-04 Reference Cylinder North EOU-EOU Intersection . MD Reference ND Reference NS Reference EW Offset MD Offset TVD Offset NS Offset EW Azim Ct-Ct Distance Clearance OSF Angle Trace# (ft) (It) (S) (ft) (6) (8) (ft) (ft) (°) (ft) (ft) (°) All brat minima indicated. Results filtered:Depth 11050.00 ft<=MD<=19200.00 ft Results filtered:Ct-Ct separation<=1500.00 8 Results highlighted:Ct-Ct separation<=1320.00 ft 11051.61 3778.30 8235.57 -3971.73 11240.00 3704.87 7670.77 -2896.50 46.68 1216.77 1097.87 10.31 18.18 1 11071.61 3780.04 8248.37 -3987.00 11240.00 3704.87 7670.77 -2896.50 46.68 1236.31 1117.88 10.52 16.18 1 1110000 3782.34 8266.53 -4008.69 11240.00 3704.87 7670.77 -2896.50 43.32 1264.09 1146.30 10.81 1551 1 11200.00 3787.70 8330.26 -4085.56 11240.00 3704.87 7670.77 -2896.50 30.24 1382.23 1246.45 11.86 13.20 1 11222.61 3788.32 8344.80 -4103.03 11240.00 3704.87 7670.77 -2896.50 27.08 1384.46 1269.09 12.09 12.89 1 11300.00 3790.05 8393.65 -4182.86 11240.00 3704.87 7670.77 -2896.50 27.08 1480.85 1348.57 12.91 12.89 1 End of results • 1 Drilling Office 2.0.960.0 Nikaitchuq\Oliktok Point\0115-S4\0115-S4\0115-S4(P5) 9/28/2011 11:46 AM Page 64 of 82 Field: Nikaitchuq Well: OP14-S3 Structure: Oliktok Point Borehole: OP14-S3 Slot: OP14 Trajectory: OP14-S3 Client: ENI Type: Del Survey Coordinate System: NAD27 Alaska State Plane,Zone 04,US Feet North Reference: True Grid Convergence Angle: 0.12842137" Grid Scale Factor: 0.999900315 Magnetic Declination: 21.155° Magnetic Declination Date: April 18,2011 Magnetic Model: BGGM 2010 Reference Point: Northing Eastin Elevation Structure Unc.(lsd) Slot Unc.11sdl 6036520.870(ftUS) 516647.470(ftUS) 53.230(ft)MSL 0.000(ft) 0.000(ft) Trajectory Error Model:ISCWSAO 3-D 95.000%Confidence 2.7955 sigma Surveying Prop: Description MD From(ft) MD To(ft) EOU Freq Survey Tool Type Hole Diameter(In) Borehole I Survey 0.000 41.030 Act-Stns SLB_GVRO-MWD-Depth Only-No Global 16.000 OP14-S3/OP14-S3 41.030 922.460 Act-Stns SLB GYRO-MWD-No Global 16.000 OP14-03/0P14-S3 922.460 2259.120 Act-Stns SLBMWD+GMAG-No Global 16.000 OP14-S3/OP14-S3 2259.120 10384.510 Act-Stns SLB_MWD+GMAG-No Global 12.250 OP14-S3/OP14-S3 10384.510 21340.000 Act-Stns SLB MWD+GMAG-No Global 8.750 OP14-S3/OP14-S3 Reference Cylinder North EOU-EOU Intersection MD Reference TVD Reference NS Reference EW Offset MD Offset TVD Offset NS Offset EW Azim Ct-Ct Distance Clearance OSFAngle Trace t! (5) (ft) (ft) (ft) (ft) (ft) (ft) (5) (`) (It) (ft) (°) All local minima indicated. Results filtered:Depth 11050.00 ft<=MD<=19200.00 ft Results filtered:CI-Ct separation<-1500.00 ft Results highlighted:Ct-Ct separation<=1320.00 ft 11681 77 3798.27 8635.66 -4458.01 13777.17 3849.39 9512.03 -3734.57 42.03 1137.54 930.40 5.51 2.75 1 11800.00 3798.92 8710.79 -4549.30 13860.09 3845.07 9566.20 -3797.19 41.78 1139.96 928.26 5.41 4.18 1 1215623 3800.85 8937.15 -4824.35 14259.35 3824.55 9821.05 -4103.76 40.67 1140.65 922.42 5.25 2.87 1 12300.00 3796.34 9028.55 -493521 14360.57 3819.63 9886.44 -4180.86 40.59 1142.60 918.99 5.13 1.96 1 12400.00 378790 9092.00 -5012.03 14430.15 3815.82 9933.05 -4232.37 40.82 1147.17 920.13 5.07 4.35 1 12600.00 3767.53 9218.56 -5165.54 14560.83 3808.45 10024.41 -4325.48 • 40.63 1164.81 931.47 5.01 7.40 1 14000.00 3740.18 10036.23 -6300.01 16181.46 3811.63 11098.38 -5530.30 37.40 1313.66 1059.20 5.18 2.42 1 14100.00 3742.62 10092.48 -8382.66 16263.36 3811.15 11146.93 -5596.26 37.28 1317.19 1059.32 5.12 3.03 1 14200.00 3744.54 10148.82 -6465.25 16371.91 3809.66 11211.79 5683.29 37.25 1321.22 1061.31 5.10 2.69 1 14400.00 3745.73 10261.83 -6630.26 16664.29 3794.64 11375.70 -5924.79 38.52 1319.39 1059.51 5.09 5.16 1 14504.56 3748.30 10320.91 -6716.53 16893.70 3774.95 11488.86 -6123.24 35.80 1310.31 1056.56 5.18 8.59 1 14900.00 3712.83 10538.62 -7044.38 17247.01 3768.67 11645.83 -6439.40 36.39 1262.85 997.03 4.76 8.04 1 15600.00 3671.94 10900.00 -764050 17946.51 3732.01 11944.16 -707037 31.70 1191.19 910.17 425 2.84 1 16000.00 3665.38 11097.55 -798820 18291.48 3720.43 12119.10 -7387.42 32.50 1196.65 901.41 4.06 1.62 1 16400.00 3656.09 11296.68 -8334.99 18717.14 3721.09 12327.46 -7738.41 32.95 1192.75 889.83 3.95 2.53 1 16662.34 3650.33 11427.18 -8582.51 1893035 3719.16 12437.84 -7920.73 33.07 1199.20 886.29 3.84 2.95 1 16700.00 3649.74 1144590 -8595.17 18980.65 3717.86 12454.22 -7946.20 33.05 1201.05 886.77 3.83 3.51 1 16900.00 364728 11545.39 -8768.65 19122.02 3710.42 12543.87 -8080.14 32.77 121449 892.79 3.78 5.83 1 17182.04 3644.05 11685.62 -9013.33 19469.96 3690.00 12731.84 -8372.14 31.73 1227.93 902.83 3.79 4.34 1 17300.00 3644.67 11743.46 -9116.13 1957434 3682.53 12786.94 -8460.48 31.12 1232.94 903.94 3.76 5.46 1 17800.00 3644.50 11988.31 -9552.04 20149.09 3668.54 13074.74 -8957.41 30.24 1238.71 902.06 3.69 1.44 1 18900.00 3590.31 12523.52 -10511.14 21340.00 3670.78 13581.30 -10033.51 33.35 116341 809.90 3.30 5.93 1 19000.00 3588.73 12572.43 -10598.34 21340.00 3670.78 13581.30 -10033.51 33.35 1159.13 793.69 3.18 5.93 1 19100.00 3587.15 12621.35 -1068555 21340.00 3670.78 13581.30 -10033.51 33.35 1163.46 788.70 3.11 5.93 1 19191.36 3585.70 12666.05 -10765.22 21340.00 3670.78 13581.30 -10033.51 33.35 1174.87 794.01 3.09 5.93 1 End of results Drilling Office 2.0.960.0 Nikaitchuq\Oliktok Point\0115-54\0115-54\0115-S4(P5) 9/28/2011 11:46 AM Page 80 of 82 Tiot eni Schlumberger ALL FIELD(P6) FIELD Nikaitchuq STRUCTUREOIiktok Point MagnNr Parameters Su4ece Coupon NAD27 Alaska State Plane.Zone O4,US Feet Mixelaneow Motley. BGGM2011 Dip: 61046' Date Apnl02,2012 Let: N 70 30 39 431 Nothing-. 6036516 89 BUS Grid Cony:0.12636652' Slot OP15 TVD Rat'. Rota,Tabte(52.26above MSL) Meg Dec:20614' FS: 57645 911 Lon W 149 51 49 194 Engin'. 516640 37 BUS Scale FedL099990031 Plan: 0115-54(P5) S6 Date.September 08,2011 8132-W2 (P2) Tuvaaq ST 1 SP3O-W1 (P2) SP30-W1 (P2) SP36-W5 (P2) SP24-SE1 (P2) S129-S2 (P2) OP09-S1 SI35-W4 (P SI17-SE2 (P2) -1 $00 -10110 -8000 -60$t -400• -20$s 0 I �O�> I t 46 Kicun 1 "1 .rrr -;,, e • �° N. . SI32-W „' ) • 4 Kigu � • a 9 �� .• SP33-W3 (-2) "'a 14000 - 8�OP14-S3 / � _ ► • 14000 t• --W3 (P2) .�° z° 7� ° f" F• • 117-SE2 (P2) 01' 1'S4 - �° hil\ N •• 12000 — ' —W4y°� �►�• ^� ^e •.. ;' _ ••- -44112000 SP24-SE1 (P2) OP10-09 ^` :111111111111rilAl."7 F• P • • • 4 �,� • OP09-S1 SF36-W5 (P2) P,c'°.c'°• , •,, • �6,�.�y,�,o 0113-03(P6) F •• t . �° 8 • �° 10000 — • -, .•,—; - ` a�"o• , 40, 10000 A Q N ^ • `$ �" ,,.c'°• '� •` 129-S2 (P2) a z OP17-02 • 40 $ 0P17-02PB1 46 Mb 4**p�4, 4 N8000 $zf o ••a ••_ - - .". •- b\ •• - — 8000 I ,44 , S ���^ z ° ,� .i • •.' 12-0 •-22 WW03 (P1) • 4 �$ c��o' �q�°o,=.,:ktok `.inti y f v �" '�o��• • �b D'D ' `.4 • OP14-S3 6000 — _ '• yb. 4b..__ • gyp, .".:<86000 (n • y5 •�• '� �° oo'. ,� OP14-S3 •' :-08P62 ,4y\b " se b\� `"C',,N o• ! ^e,,'c�' yr�`Oo • Vo. • '54'\0(Q `• y +,fib•fN • ',.55. '''^ 19�T`D' v • • �y� '' ,c4°,,o' ,a� .0) 1. .ktok P..,t I-2' r t1t,VD • N'''''ti •• .b<61 •c••• <40 i �° • I 1 OP26-DSPO2 <1p D . 4000 — ; a o -s`a5 i• 4000 411\9.,A99q.‘ . • I • •• ry •` . � • 6000 A4 � e•,' , � • ' , 7 '• . • O P23-WW02 b NAL - �y° I! tok �o I-2P� i /�` yy y ".:^ • 2000 — ist �����1111111� M .ervi:11. 2000 I..p...7 1ih..‘. , ir A4I= ee• OP08-04PB1 1 7:1‘.,,,,\.\ . OP08-04 �; ...,* . ,�1P18-08PB1 0 — I I ' '''t ,D D -12000 -10000 -8000 -6000 -4000 -2000 ! aI OP10-09 «< W Scale= 1(in):2000(ft) E >>> OP26-DSP02 Oliktok Point 1-2 OP10-09 Oliktok Point I-2PB1 Oliktok Point I-2PB2 OP21-WW01 (P3) Drilling Hazards Sum_ ary 16" Open Hole / 13-3/8" Casin2 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" Casin2 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 8-3/4" Open Hole / 4-1/2" 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 Drilling Hazards Summary.doc 9/22/2011 9:06:00 AM a liX11 1 .¢h a ! Q Lu FR 0 W Z Z 3 $ a __ �o go= aWo= e � b 2 r... 0 I,z .. (..D 1,..1 h /1 1 .0 1 z=O W \J O J ,- Z J \J Z W l li C¢ • b L,-), .=,..,, nmv� zz� �zolJZ v) I J O I 1 e 11 Crc) g10 �a�� -(2-00 0_10 CC rn 0 0 1- '0 0 Z z 'Y z v, o z `` LS 'c$' `tb° c i j 7 n N -,^) P 3 J 3 axe m<&g LU O Olt'W O V Z a vj 2 Lti > cop 2 W �W Y ''°O1- 1 U Q 11 II i # 1 ILI Z N 0 '-J \ 1 N Q 0 0 + �` � � 0 �-1 I_-, - z ..._ / Q in V OCC I- — — o H m d- - l °m w Q J 3 oCC Lu 0W> o= O o zti Z U n Z I U M Y, t Li g IPfrIiiHiIII_I W Fo i= ii111 1 a a W o Z t i ? l�2 Ii 1 , LLo I I ,__ giII �p w 0. �n in:li„..,...:;::: II (mom nm = W d N nce. __ I' Ili ....,;�lll= OII' -,11 „,,,:„„, , ,,,, P ,c„. I _ ®'�, LJI4I +II 135 PU I ctctz -, t, % a �,o ...6's t 2 rod $ R% , .NRIP t§ p nelE Fs PP�� y U I I <,:,`"-. i „ O 1:\I \_ _CL m Ir 12,, Z o e3 — wJ L 1 Z 4 :,,>,H —_--j-IL : —1 r_ _ N 101 Ld U bj --cr i; \--; A u_< ct J I N N 1.8 .t/l h-,8 kikillirilli vii o N OO v in (1? ' '' ''' I 41 8 , , J - rl - 9u — Air iik' A .. @ 0 i• — 1.. O11� e aid- < vw v ��1Iv 471. p 01 „ 1 .1� • °: �' ► © \ r mum ' 10,4%‘e\ id ,. To 71 t a� wU- • k O io io Tr") (rs as L 0 C c U c0 c2 N Q a> 1 N O c c c co A cr O O O t, p o F°- 0 U 0 cn < C) o 0 0 0 n T T T U) ii > Cl) T T T T cG (/) > C C L " O d- N Tir M O m - ' N a > O en 2 : O - Cr ; Schlumberger CemCAD E*well cementing recommendation for 13.375" Surface Casing Operator : Eni Petroleum Well : 0115-S4 Country : USA Field : Nikaitchuq State : Alaska Prepared for : Mr.Luca Borri Location : Nabors 245E Proposal No. : Draft v1 (P5) Service Point : Prudhoe Bay Alaska Date Prepared : 09-28-2011 Business Phone : (907)659-2434 FAX No. : (907)659-2538 Prepared by : Jeff Long Phone : (907)273-1778 Cell : (907)223-0093 E-Mail Address : JLong1@slb.com D FL 14VATE Disclaimer Notice: Schlumberger submits this document with the benefit of its judgment,experience,and good oilfield practices. This information is provided it 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 DE 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 : 0115-S4 Schlsiergcr 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 : 2410.0 ft BHST : 36 degF Bit Size : 16 in ft (x 1000) psi o- < .1 l > — — — 0 1.0 1 .5 —Frac —Pore Siltstone— o .•.:Sandstone_•_•_ . 0 o 'Shale - • •Sandstone • • Ell o — O . . . ,� • •Sandstone , III 0 0 0 co_ Well Lithology Formation Press. Page 2 oil 5-s4 9-28-11.cfw;09-28-2011; LoadCase Surface Casing;Version wcs-cem482_12 Client : Eni Petroleum Well : 0115-S4 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 20 169.0 18.376 Landing Collar MD : 2330.0 ft Casing/liner Shoe MD : 2410.0 ft Casing/Liner MD OD Joint Weight ID Grade Collapse Burst Thread (ft) (in) (ft) (lb/ft) (in) (psi) (psi) 2410.0 13 3/8 40.0 68.0 12.415 L-80 2270 5020 BTC Mean OH Diameter : 16.000 in Mean Annular Excess : 182.2 Mean OH Equivalent Diameter: 19.912 in Total OH Volume : 866.6 bbl (including excess) Caliper and Hole Size Data MD Caliper Excess Equiv. Diam. (ft) (in) (%) (in) 1903.0 16.000 225.0 20.724 2410.0 16.000 35.0 16.822 Page 3 oil 5-s4 9-28.11.cfw;09-28-2011; LoadCase Surface Casing;Version wcs-cem462_12 Client : Eni Petroleum Well : 0115-S4 Scblbergcr String : 13.375 District : Prudhoe Bay Alaska Country : USA Loadcase : Surface Casing Max. Deviation Angle : 46 deg Max. DLS : 3.526 deg/100ft Directional Survey Data MD TVD Deviation Azimuth Dogleg Sev. (ft) (ft) (deg) (deg) (deg/100ft) 0.0 0.0 0.0 313.0 0.000 100.0 100.0 0.0 313.0 0.000 200.0 200.0 0.0 313.0 0.000 300.0 300.0 0.0 313.0 0.000 325.0 325.0 0.0 313.0 0.000 400.0 400.0 1.1 313.0 1.507 425.0 425.0 1.5 313.0 1.480 500.0 499.9 3.8 313.0 3.000 600.0 599.5 6.8 313.0 3.000 700.0 698.4 9.8 313.0 3.000 800.0 796.5 12.8 313.0 3.000 900.0 893.4 15.8 313.0 3.000 1000.0 988.9 18.8 313.0 3.000 1100.0 1082.7 21.8 313.0 3.000 1200.0 1174.6 24.8 313.0 3.000 1300.0 1264.3 27.8 313.0 3.000 1400.0 1351.5 30.8 313.0 3.000 1400.8 1352.2 30.8 313.0 2.439 1500.0 1437.2 31.3 313.0 0.504 1600.0 1522.4 31.8 313.0 0.500 1700.0 1607.2 32.3 313.0 0.500 1800.0 1691.5 32.8 313.0 0.500 1900.0 1775.4 33.3 313.0 0.500 1992.1 1852.2 33.7 313.0 0.499 2000.0 1858.8 34.0 313.3 3.526 2100.0 1940.2 36.9 316.6 3.496 2200.0 2018.6 39.9 319.5 3.504 2300.0 2093.6 43.0 322.0 3.499 2400.0 2164.9 46.1 324.3 3.502 2410.6 2172.2 46.4 324.5 3.468 Formation Data MD Frac. Pore Name Lithology (ft) (lb/gal) (lb/gal) 713.0 11.35 8.39 SV-4 Siltstone 967.0 11.50 8.40 SV-3 Sandstone 1251.0 11.50 8.41 SV-2 Shale 1807.0 11.70 8.42 SV-1 Sandstone 1903.0 12.00 8.43 Permafrost Base Coal 2207.0 12.30 8.44 Ugnu Top(UG4) Sandstone 2410.6 12.50 8.45 TD Shale Page 4 o115-s4 9-28-11.cfw,09-28-2011: LoadCase Surface Casing:Version wcs-cem462_12 Client : Eni Petroleum Well : 0115-S4 Schlumberger String : 13.375 District : Prudhoe Bay Alaska Country : USA Loadcase : Surface Casing Geothermal Temperature Profile MD TVD Temperature Gradient (ft) (ft) (degF) (degF/100ft) 0.0 0.0 60 0.0 1903.0 1777.9 32 -1.6 2410.6 2172.2 36 -1.1 ft degF T5 70 75 80 85 0- 35 40 45 50 55_ 60 6 — Geoth.Profile —Tubular Fluids —Annulus 0 O— V) O O_ O O '4) O O— N O O u7 N— Temp. Profile At 198 min Page 5 oil 5-s4 9-28-11.cfw,09-28-2011, LoadCase Surface Casing,Version wcs-cem462_12 Client : Eni Petroleum Well : 0l15-S4 Schloberger String : 13.375 District : Prudhoe Bay Alaska Country : USA Loadcase : Surface Casing Section 2: fluid sequence Job Objectives: Cement to Surface in Permafrost,shoe integrity sufficient to drill ahead. Original fluid Mud 9.30 lb/gal k:2.06E-3 Ibf.s^n/ft2 n :0.812 Ty:8.74 Ibf/100ft2 Displacement Volume 348.9 bbl Total Volume 961.9 bbl TOC 0.O 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 Lead Slurry 450.0 1905.4 10.70 k:8.93E-2 Ibf.s^n/ft2 n:0.282 Ty:24.97 Ibf/100ft2 LiteCRETE(12.5) 63.0 504.6 1905.4 12.50 k:7.96E-3 Ibf.s^n/ft2 n:0.895 Ty:14.59 Ibf/100ft2 Mud 348.9 0.0 9.30 k:2.06E-3 lbf.s^n/ft2 n:0.812 Ty:8.74 lbf/100ft2 Static Security Checks: • Frac 5 psi at 160.0 ft Pore 19 psi at 160.0 ft Collapse 2012 psi at 2330.0 ft Burst 5020 psi at 0.0 ft Csg.Pump out 51 ton Check Valve Diff Press 185 psi Page 6 oil 5-s4 9-28-11.cfw,09-28-2011; LoadCase Surface Casing,Version wcs-cem462_12 Client : Eni Petroleum Well : 0115-S4 Scillliberger String : 13.375 District : Prudhoe Bay Alaska Country : USA Loadcase : Surface Casing CemCADE Client : Eni Petroleum Well :0115-S4 String : 13.375"Surface Casing District : Prudhoe Bay Alaska Country : USA lb/gal ft 8 9 10 11 12 13 o _ > 1 -Hydrostatic -Mn.Hydrostatic -Max.Dynanic Mn.Dynamic Frac o Pore o- 8- u7 N O d � E / Y 3 0 > O_ .5 U t N m Q U � i $ (V N ' N- .d 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 Lead Slurry 450.0 bbl 10.70 lb/gal Herschel:k=8.93E-2 Ibf.s^n/ft2 n=0.282 Ty=24.97 Ibf/100ft2 ■LiteCRETE(12.5) 63.0 bbl 12.50 Ib/gal Herschel:k=7.96E-31bf.s^n/ft2 n=0.895 Ty=14.59 Ibf/100ft2 ■Mid 348.9 bbl 9.30 lb/gal Herschel:k=2.06E-3 lbf.s^n/ft2 n=0.812 Ty=8.74 lbf/100ft2 Total Depth = 2410.0 ft Top of Cement= 0.0 ft °Mark of Schlumberger Sii mbrir Page 7 oil 5-s4 9-28-11.cfw,09-28-2011; LoadCase Surface Casing;Version wcs-cem462_12 Client : Eni Petroleum Well : 0115-S4 Schlumberger String : 13.375 District : Prudhoe Bay Alaska Country : USA Loadcase : Surface Casing Section 3: pumping schedule Start Job: Circulate Two Hole Volumes Minimum, Safety Meeting, Test Surface Equipment Pumping Schedule Name Flow Rate Volume Stage Time Cum.Vol Inj. Comments (bbl/min) (bbl) (min) (bbl). Temp. (degF) MUDPUSH II 5.0 100.0 20.0 100.0 80 Spacer Ahead 5.0 0.0 80 Drop Bottom Plug Lead Slurry 5.0 348.0 69.6 348.0 80 Mix&Pump Lead Slurry Lead Slurry 1.0 2.0 2.0 350.0 80 Bottom Plug @ Float Collar Lead Slurry 5.0 10.0 2.0 360.0 80 Mix&Pump Lead Slurry Lead Slurry 3.0 90.0 30.0 450.0 80 Finish Lead Slurry LiteCRETE(12.5) 4.0 60.0 15.0 60.0 80 Mix&Pump Tail Slurry LiteCRETE(12.5) 2.0 3.0 1.5 63.0 80 Finish Tail Slurry 3.0 0.0 80 Drop Top Plug Mud 8.5 10.0 1.2 10.0 80 Kick Out Plug 3.0 0.0 80 Line Up Rig Pumps Mud 8.5 328.9 38.7 338.9 80 Displace Mud 5.0 8.0 1.6 346.9 80 Slow Rate Mud 3.0 2.0 0.7 348.9 80 Bump Plug Shut-In 5.0 0.0 80 Bleed-Off/Check Floats Total 03:13 hr:mn 961.9 bbl End Job: Bump Top Plug, Bleed-off PSI, Check floats Dynamic Security Checks : Frac 0 psi at 160.0 ft Pore 8 psi at 160.0 ft Collapse 2011 psi at 2330.0 ft Burst 4769 psi at 0.0 ft Temperature Results BHCT 58 degF Simulated Max HCT 77 degF Simulated BHCT 76 degF Max HCT Depth 2410.0 ft CT at TOC 71 degF Max HCT Time 02:56:20 hr:mn:sc Static temperatures : At Time (hr:mn) 00:05 hr:mn Geo.Temp. Top of Cement (degF) 71 degF 60 degF Bottom Hole (degF) 76 degF 36 degF Page 8 oil 5-04 9-28-11 cfw:09-28-2011, LoadCase Surface Casing,Version wcs-cem462_12 Client : Eni Petroleum Well : 0115-S4 Schieeberger String : 13.375 District : Prudhoe Bay Alaska Country : USA Loadcase : Surface Casing ECD Modeled at the shoe: o Depth= 2410 ft ctir Ln N -Hydrostatic 0Dynamic Frac -Fore LO O O O O i to v O tri- la o cd 0 30 60 90 120 150 180 210 Time(min) ECD Modeled at the Conductor Shoe: Depth= 160 ft Fluids at 2410 ft 0 i N— — _ Hydrostatic Dynamic Frac i OFore ,...cs_, ,,, a,____,....,________.... ....„_____I r I 0 OS_ , in 1 I 0 cd 0 30 60 90 120 150 180 210 Time(min) Page 9 oi15-s4 9-28-11.cfw;09-28-2011; LoadCase Surface Casing;Version wcs-cem462_12 I Client : Eni Petroleum Well : 0115-S4 Sabine' String : 13.375 District : Prudhoe Bay Alaska Country : USA Loadcase : Surface Casing BHCT Model: 0 tp First Sack Terrp. Last Sack Terrp. _O iP le le I n- QQ 0 30 60 90 120 150 180 210 Time(min) Surface Pressure Prediction: Calc.pump P-ess. Calc.Ceml-P 0 rn d 0 d- ci .+ M O N - d 1.11 • 0 30 60 90 120 150 180 210 Time(min) Page 10 oi15-s49-28-11.cfw:09-28-2011: LoadCase Surface Casing Version wcs-ceni462_12 Client : Eni Petroleum Well : 0115-S4 Schlobergcr String : 13.375 District : Prudhoe Bay Alaska Country : USA Loadcase : Surface Casing Returns Rate: Fluids at 2410 ft Q out Qr, CO r ^c r ro N L 0 30 60 90 120 150 180 210 Time (min) Anullar Velocity: Depth= 2410 ft RAnnular Velocity pW r 8- 8 0 0 30 60 90 120 150 180 210 Time (min) Page 11 m15-s4 9-28-11.cfw;09-28-2011; LoadCase Surface Casing;Version wcs-cem462_12 Client : Eni Petroleum Well : 0l15-S4 ScII��r�er String : 13.375 District : Prudhoe Bay Alaska Country : USA Loadcase : Surface Casing Section 4: fluid description Mud DESIGN Fluid No: 1 Density :9.30 lb/gal Rheo. Model : HERSCHEL_B. k :2.06E-3 Ibf.s^n/ft2 At temp. :80 degF n :0.812 Ty :8.74 lbf/100ft2 Gel Strength :38.42 Ibf/100ft2 MUD Mud Type :WBM Job volume : 348.9 bbl Water Type : Fresh VOLUME FRACTION Solids :7.0% Oil :0.0% Water :93.0% 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 :(Ibf/100ft2) Job volume : 100.0 bbl Lead Slurry DESIGN Fluid No:3 Density : 10.70 lb/gal Rheo. Model : HERSCHEL_B. k :8.93E-2 Ibf.s^n/ft2 At temp. :69 degF n :0.282 Ty :24.97 Ibf/100ft2 Gel Strength : 11.88 I bf/100ft2 DESIGN BLEND SLURRY Name : B809(1001b) Mix Fluis : I. -•_•-1/sk Job volume :450.0 bbl Dry Density : 106.82 lb/ft3 :2.34 ft k Quantity : 1077.84 sk Sack Weight : 100 lb S. id Fraction : 39.9% BASE FLUID Type : Fresh water Density :8.32 lb/gal Base Fluid : 10.532 gal/sk Page 12 oil 5-s4 9-28-11.cfw,09-28-2011; LoadCase Surface Casing;Version wcs-cem462_12 Client : Eni Petroleum Well : 0115-S4 Schimergcr String : 13.375 District : Prudhoe Bay Alaska Country : USA Loadcase : Surface Casing LiteCRETE(12.5) DESIGN Fluid No:4 Density : 12.50 lb/gal Rheo. Model : HERSCHEL_B. k : 7.96E-3 Ibf.s^n/ft2 At temp. :69 degF n :0.895 Ty : 14.59 lbf/100ft2 Gel Strength :52.26 Ibf/100ft2 DESIGN BLEND SLURRY --- Name : 12.5(0.76) Mix Flue . . . .. k Job volume :63.0 bbl Dry Density : 119.32 lb/ft3 Yield : 1.54 ft3/sk Quantity :230.21 sk Sack Weight : 100 lb Solid Fraction : 55.1 'o BASE FLUID Type : Fresh water Density : 8.32 lb/gal Base Fluid :5.165 gal/sk Additives Code Conc. Function D046 0.2000%BWOB Antifoam D065 0.2500%BWOB Dispersant D167 0.2500%BWOB Fluid loss Annulus ID: 13.375 in-OD : 16.000 in 0 o— - LiteCRETE(12.5) Lead Slurry - MUDPUSH 11 O O O O N sZ O_ co Co N 0 C O_ O 117 U .0 �T O M 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 (bbVmin) • Page 13 oi15-s4 9-28-11.cfw;09-28-2011; LoadCase Surface Casing;Version wcs-cem462_12 Client : Eni Petroleum Well : 0115-S4 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 :2390.0 ft Casing Shoe :2410.0 ft NB of Cent. Used :35 NB of Floating Cent. :35 Centralizer Placement Bottom MD Nbr. Cent./ Cent. Name Code Min. STO @ Depth (ft) Joint (%) (ft) 2010.0 25 1/2 NW-TR-13 3/8-8-TR 3 W304 10.4 510.0 2410.0 10 1/1 NW-TR-13 3/8-8-TR 3 W304 72.2 2410.0 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 ft 0 20 40 60 80 100 o j , Betw een Cent. + +At Cent. O O O O a- + o + + o + 4 +- +- 0 O T- O u7 N Well Pipe Standoff Page 14 n115-s4 9-28-11.cfw,09-28-2011: LoadCase Surface Casing:Version wcs-cem462_12 11 Client : Eni Petroleum Well : 0l15-S4 Schlumberger String : 13.375 District : Prudhoe Bay Alaska Country : USA Loadcase : Surface Casing Section 6: WELLCLEAN II ft °,U cyo �l 0 50 100 0 25 50 75 100 E > - --r Std Betw.Cent. Mud Contamination _ -- Cement Coverage - 1 — Uncontaminated Slurry �� Ooo — ttt���fffff777777 K --. .......,_,.. '' \ � O rjj InE '' li Fluid Sequence Cement Coverage Uncontaminated Slurry Fluids Concentrations Risk Mud on the Wall z° 1 i 0-1 -0 0/ — o 200- -200 200- :^ -200 400- -400 400- = `,- -400 I 600- -600 600- .,-) fr~, -600 800- -800 _ _ 800- "= '3 -a0o _ 4 1000- -1000 T ,- 1000- ) �� E. -1000 T s 1200- -1200 r s 1200- ,1 -1200 i 0 1400- -1400 0 0 1400- ., -1400 0 1600- -1600 1600- .. -1&00 1600- -1800 1600- ""?_r -1600 2000- -2000 2000- -2000 2200- -2200 2200- -2200 24001 -2400 24001 -2400 o g m U g m o 0 k o z llMud I I Lead Slurry [ I Hial1 I 1 Lov., LiteCRETE (12.5) Mil MUDPLISH II I 1 Medium I I None Paan 15 oi 1 5-s4 9-28-11.cfw,09-28-2011; LoadCase Surface Casing;Version wcs-cem462_12 Client : Eni Petroleum Well : 0115-S4 SehIkarger 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 107785 lb 1078 sack 100 lb ArcticSET Lite D962 23022 lb 231 sack 100 lb LiteCRETE D182 5551b 23 sack 25 lb D046 46 lb 2 sack 50 lb D031 9527 lb 87 sack 110 lb D065 58 lb 2 sack 50 lb D167 58lb 3 sack 251b Mix Water Requirements : Fresh water 16425 gal MIXING PREPARATION MUDPUSH II Volume : 100.0 bbl Density: 10.10 lb/gal Code Quantity Design Fresh water 92.485 bbl D182 554.912 lb 6.0000 lb/bbl of base fluid D046 20.000 lb 0.2000 lb/bbl of spacer D031 9526.843 lb 95.27 lb/bbl of spacer Lead Slurry Volume :450.0 bbl Density : 10.70 lb/gal Yield :2.34 ft3/sk Dry Phase Liquid Phase Blend : 107784 lb Design Mix Water 270.3 bbl 10.0 bbl LAS Design B809(1001b) 107784.156 Fresh water 270.279 bbl 10.001 bbl lb LiteCRETE(12.5) Volume :63.0 bbl Density : 12.50 lb/gal Yield : 1.54 ft3/sk Dry Phase Liquid Phase Blend: (Ib) Design Mix Water 28.3 bbl 10.0 bbl LAS Design 12.5(0.76) 23021.473 lb Fresh water 28.309 bbl 10.001 bbl D046 46.043 lb 0.2000%BWOB D065 57.554 lb 0.2500%BWOB D167 57.554 lb 0.2500%BWOB Page 16 oil 5-s4 9-28-11.cfw,09-28-2011, LoadCase Surface Casing,Version wcs-cem462_12 Schlumberger CemCAD E*well cementing recommendation for 9 5/8° Intermediate Casing Operator : Eni Petroleum Well : 0115-S4 Country : USA Field : Nikaitchuq State : Alaska Prepared for : Mr.Luca Borri Location : Nabors 245E Proposal No. : Draft v1 (P5) Service Point : Prudhoe Bay Alaska Date Prepared : 09-28-2011 Business Phone : (907)659-2434 FAX No. : (907)659-2538 Prepared by : Jeff Long Phone : (907)273-1778 Cell : (907)223-0093 E-Mail Address : JLong1©slb.com C -9 �UATE 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 : 0115-S4 Schlumberger String : 9 5/8 District : Prudhoe Bay Alaska Country : USA Loadcase : 9 5/8 FP Section 1 : well description Configuration : Casing Stage : Single Rig Type : Land Mud Line : 50.0 ft Total MD : 11052.0 ft BHST : 70 degF Bit Size : 12 1/4 in ft Ib/gal �_ • 8 12 16 _Siltstone __ Pyre I , I - .....Sandstone. M .____ riammumminn ICD {CO O O € I . . - • • •Sandstone•.•.• ■ _1 • •Sandstone c. cp— i rn wwwwwwwwwwww 1 . 1 II • •Sandstone • • i- r O - O Well Lithology Formation Press. Page 2 0115-S4 9-28-11.cfw,09-29-2011, LoadCase 9 5/8 FP,Version wcs-cem462_12 Client : Eni Petroleum Well : 0115-S4 Schlumberger String : 9 5/8 District : Prudhoe Bay Alaska Country : USA Loadcase : 9 5/8 FP Previous String MD OD Weight ID (ft) (in) (lb/ft) (in) 2410.0 13 3/8 68.0 12.415 Landing Collar MD : 10971.0 ft Casing/liner Shoe MD : 11051.0 ft Casing/Liner MD OD Joint Weight ID Grade Collapse Burst Thread (ft) (in) (ft) (lb/ft) (in) (psi) (psi) 11051.0 9 5/8 40.0 47.0 8.681 L-80 4760 6870 BTCM Mean OH Diameter : 12.250 in Mean Annular Excess : 50.0 Mean OH Equivalent Diameter: 13.370 in Total OH Volume : 1500.8 bbl (including excess) Caliper and Hole Size Data MD Caliper Excess Equiv. Diam. (ft) (in) (%) (in) 11051.0 12.250 50.0 13.371 11052.0 12.250 0.0 12.252 Max. Deviation Angle : 85 deg Max. DLS : 3.526 deg/100ft Directional Survey Data MD TVD Deviation Azimuth Dogleg Sev. (ft) (ft) (deg) (deg) (deg/100ft) 10600.0 3737.9 84.4 313.8 2.499 10700.0 3747.4 84.8 311.3 2.503 10751.6 3752.0 85.0 310.0 2.504 10800.0 3756.2 85.0 310.0 0.000 10900.0 3764.9 85.0 310.0 0.000 11000.0 3773.6 85.0 310.0 0.000 11052.0 3778.2 85.0 310.0 0.000 Page 3 0115-S4 9-28-11.cfw;09-29-2011, LoadCase 9 5/8 FP;Version wcs-cem462_12 • Client : Eni Petroleum Well : 0l15-S4 Schlumberger String : 9 5/8 District : Prudhoe Bay Alaska Country : USA Loadcase : 9 5/8 FP Formation Data MD Frac. Pore Name Lithology (ft) (lb/gal) (lb/gal) 713.0 11.35 8.39 SV-4 Siltstone 967.0 11.50 8.40 SV-3 Sandstone 1251.0 11.50 8.41 SV-2 Shale 1807.0 11.70 8.42 SV-1 Sandstone 1903.0 12.00 8.43 Permafrost Base Coal 2207.0 12.30 8.44 Ugnu Top(UG4) Shale 2410.6 12.50 8.45 TD Shale 2947.0 12.60 8.50 UG-2 Coal 7214.0 12.70 8.50 Lower Ugnu Shale 7833.0 12.50 8.50 FLT 01-04 Sandstone 8889.0 12.60 8.60 Schrader Bluff Sandstone 9150.0 12.60 8.60 N Seq Top Shale 9366.0 12.60 8.60 N-Sand Top Sandstone 9580.0 12.60 8.70 N Bottom Sandstone 10801.0 12.50 8.70 OA-2 Sandstone 11051.0 12.50 8.70 Casing Pt. Shale 11052.0 12.50 8.70 TD Sandstone Geothermal Temperature Profile MD TVD Temperature Gradient (ft) __ (ft) (degF) (degF/100ft) 0.0 0.0 50 0.0 1909.0 1782.9 32 -1.0 11052.0 3778.2 70 0.5 ft degF 0 30 35 40 45l 50 55 6I 65 70 75 80 815 - Geoth.Prof ile _ - Tubular Fluids -Annulus 1 E- 1 Temp. Profile At 189 min Page 4 On 5-S4 9-28-11.cfw,09-29-2011; LoadCase 9 5/8 FP;Version wcs-cem462_12 Client : Eni Petroleum Well : 0115-S4 Schlumberger String : 9 5/8 District : Prudhoe Bay Alaska Country : USA Loadcase : 9 5/8 FP Section 2: fluid sequence Job Objectives: Cement coverage verifiable to 1000'above the top of the N-Sand(TOC 8366') Original fluid Mud 9.40 lb/gal k : 1.87E-3 Ibf.s^n/ft2 n : 0.832 Ty: 6.23 Ibf/100ft2 Displacement Volume 803.1 bbl Total Volume 1149.1 bbl TOC 8360.2 ft Fluid Sequence Name Volume Ann. Len Top Density Rheology (bbl) (ft) (ft) (lb/gal) Citric Pill 35.0 418.3 6985.8 9.49 k:8.82E-3 lbf.s^n/ft2 n:0.572 Ty:9.46 Ibf/100ft2 MUDPUSH II 80.0 956.1 7404.1 10.50 k:4.94E-2 lbf.s^n/ft2 n:0.369 Ty:18.29 Ibf/100ft2 DeepCRETE(12.5) 231.0 2690.8 8360.2 12.33 k:7.96E-3 Ibf.s^n/ft2 n:0.895 Ty:14.59 Ibf/100ft2 Mud 803.1 0.0 9.40 k:1.87E-3lbf.s^n/ft2 n:0.832 Ty:6.231bf/100ft2 Static Security Checks: Frac 342 psi at 2410.0 ft Pore 105 psi at 2410.0 ft Collapse 4540 psi at 10971.0 ft Burst 6846 psi at 50.0 ft Csg.Pump out 75 ton Float Collar Valve Diff Press 39 psi Page 5 0115-S4 9-28-11 cfw,09-29-2011; LoadCase 9 5/8 FP;Version wcs-cem462 12 Client : Eni Petroleum Well : 0115-S4 Sehhillberger String : 9 5/8 District : Prudhoe Bay Alaska Country : USA Loadcase : 9 5/8 FP CemCADE Client : Eni Petroleum Well :0115S4 String :9 5/8"Intermediate Casing District : Prudhoe Bay Alaska Country : USA ft lb/gal 8 9 10 11 12 13 14 0- -Hydrostatic -Mn.Hydrostatic - Max.Dynamic - Mn.Dynamic - Frac - Fore 8- M 1 � t0 0 0_ •i 3 a LL 8- J u N — N os Fluid Sequence Dynamic Well Security IIICitric Fill 35.0 bbl 9.49 lb/gal Herschel:k=8.82E-3 Ibf.s^n/ft2 n=0.572 Ty=9.46 Ibf/100ft2 ■MUDPUSH II 80.0 bbl 10.50 lb/gal Herschel:k=4.94E-2 Ibf.s^n/ft2 n=0.369 Ty=18.29 Ibf/100ft2 ■DeepCRETE(12.5) 231.0 bbl 12.33 lb/gal Herschel:k=7.96E-3 Ibf.s^n/ft2 n=0.895 Ty=14.59 Ibf/100ft2 ■Mud 803.1 bbl 9.40 lb/gal Herschel:k=1.87E-3 Ibf.s^n/ft2 n=0.832 Ty=6.23 Ibf/100ft2 Total Depth =11052.0 ft Top of Cement= 8360.2 ft *Mark of Schlumberger Slir Page 6 0115-S4 9-28-11.cfw.09-29-2011, LoadCase 9 5/8 FP,Version wcs-cem462_12 r Client : Eni Petroleum Well : 0115-S4 Schlumberger String : 9 5/8 District : Prudhoe Bay Alaska Country : USA Loadcase : 9 5/8 FP Section 3: pumping schedule Start Job: Circulate Two Hole Volumes, Safety Meeting, Test Surface Equipment Pumping Schedule Name Flow Volume Stage Time Cum.Vol lnj. Comments Rate (bbl) (min) (bbl). Temp. (bbl/min (degF) Citric Pill 5.0 35.0 7.0 35.0 80 Pump Citric Pill Ahead 5.0 0.0 80 Line-up Cement Unit MUDPUSH II 5.0 80.0 16.0 80.0 80 Pump Spacer 3.0 0.0 80 Drop Bottom Plug 2.0 0.0 80 Line up to Pump Cement LiteCRETE(12.5) 5.0 231.0 46.2 231.0 80 Mix&Pump Slurry at 3 to 7 BPM 5.0 0.0 80 Drop Top Plug Mud 8.0 10.0 1.3 10.0 80 Kick Out Plug 0.0 0.0 80 Line Up Rig Pumps Mud 8.0 562.0 70.3 572.0 80 Displace w/Rig Pumps Mud 3.0 2.0 0.7 574.0 80 Bottom Plug @ Float Collar Mud 8.0 219.1 27.4 793.1 80 Displace w/Rig Pumps Mud 5.0 8.0 1.6 801.1 80 Slow Rate Mud 3.0 2.0 0.7 803.1 80 Bump Plug Shut-In 0.0 0.0 3.0 0.0 80 Bleed-off/Check Floats Total 03:06 hr:mn 1149.1 bbl End Job: Bump Top Plug, Bleed-off PSI, Check floats Dynamic Security Checks : Frac 252 psi at 11052.0 ft Pore 105 psi at 2410.0 ft Collapse 4422 psi at 350.8 ft Burst 6480 psi at 50.0 ft . Temperature Results BHCT 75 degF Simulated Max HCT 70 degF Simulated BHCT 62 degF Max HCT Depth 225.5 ft CT at TOC 63 degF Max HCT Time 03:03:45 hr:mn:sc Static temperatures : At Time 00:01 hr:mn 00:03 hr:mn Geo.Temp. Top of Cement 63 degF 63 degF 1 63 degF Bottom Hole 62 degF 62 degF 70 degF Page 7 0115-04 9-28-11 cfw;09-29-2011; LoadCase 9 5/8 FP;Version wcs-cem462_12 Client : Eni Petroleum Well : 0115-S4 Minim" String : 9 5/8 District : Prudhoe Bay Alaska Country : USA Loadcase : 9 5/8 FP ECD at the Shoe: o _ ____ Depth= 11051 ft ed 1 in 01 Hydrostatic O Dynamic Frac 1 Pore 10 - lc b O 2 � ,- z z inig ------1711- O ✓ r i oi- O_ di i O T T r O 20 40 60 80 100 120 140 160 180 200 Time (min) ECD at the Surface Casing Shoe: i o __ Depth= 2410 ft Fluids at 11051 ft M1 1 N i o Hydrostatic 1 I t\1- Dynamic Frac Pore in1° ,t1 pppO1 � d j 0 V- _r 1 os O c1- i O 20 40 60 80 100 120 140 160 180 200 Time(min) i 1 Page 8 0115-S49-28-11.cfw;09-29-2011; LoadCase95/8FP;Version wcs-cem462_12 1 Client : Eni Petroleum Well : 0115-S4 ScIierger String : 9 5/8 District : Prudhoe Bay Alaska Country : USA Loadcase : 9 5/8 FP BHCT Temperature Simulation: First Sack Temp. 0 Last Sack Te •. P 8 le- g 8- 8- 0 20 40 60 80 100 120 140 160 180 200 Time (min) Surface Pressure Prediction: Calc.Pump Press. g - Calc.CemHP (D O. a \-- i — / _ __\ ( 0 20 40 60 80 100 120 140 160 180 200 Time (min) Page 9 0115-54 9-28-11 cfw;09-29-2011; LoadCase 9 5/8 FP;Version wcscem482 12 Client : Eni Petroleum Well : 0115-S4 Moberg" String : 9 5/8 District : Prudhoe Bay Alaska Country : USA Loadcase : 9 5/8 FP Returns Rate: Fluids at 11051 ft -Q Out -Q In CO t�- (0- E• L g - N- o I — 0 20 40 60 80 100 120 140 160 180 200 Time (min) Anullar Velocity: Depth= 11051 ft 8 Annular Velocity $- 0ODD_ O C 1 E g, 8- R- 0_ -Ri- O_ O —T 0 20 40 60 80 100 120 140 160 180 200 Time(min) Page 10 0115-54 9-28-11.cfw,09-29-2011, LoadCase 9 5/8 FP,Version wcs-cem462_12 Client : Eni Petroleum Well : 0115-S4 Schlumberger String : 9 5/8 District : Prudhoe Bay Alaska Country : USA Loadcase : 9 5/8 FP Section 4: fluid description Mud DESIGN Fluid No: 1 Density : 9.40 lb/gal Rheo. Model : HERSCHEL_B. k : 1.87E-3lbf.s^n/ft2 At temp. :80 degF n :0.832 Ty :6.231bf/100ft2 Gel Strength :21.35 Ibf/100ft2 MUD Mud Type : OBM Job volume : 803.1 bbl Water Type : Fresh VOLUME FRACTION Solids : 13.5% Oil :60.0% Water :26.5 MUDPUSH II DESIGN Fluid No:2 Density : 10.50 lb/gal Rheo. Model : HERSCHEL_B. k : 4.94E-2 lbf.s^n/ft2 At temp. : 58 degF n : 0.369 Ty : 18.29 lbf/100ft2 Gel Strength : 40.56 Ibf/100ft2 Job volume : 80.0 bbl DeepCRETE (12.5) DESIGN Fluid No:4 Density : 12.33 lb/gal Rheo. Model : HERSCHEL_B. k : 7.96E-3 lbf.s^n/ft2 At temp. : 58 degF n : 0.895 Ty : 14.59 lbf/100ft2 Gel Strength : 21.02 Ibf/100ft2 DESIGN BLEND SLURRY Name : 12.5(0.76) Mix Fluid : 5.662 gal/sk Job volume : 231.0 bbl Dry Density : 119.32 lb/ft3 Yield : 1.60 ft3/sk Quantity : 808.76 sk Sack Weight : 100 lb Solid Fraction : 52.8% BASE FLUID Type : Fresh water Density : 8.32 lb/gal Base Fluid : 5.662 gal/sk Additives Code Conc. Function D046 0.2000%BWOB Antifoam D065 0.2500%BWOB Dispersant D167 0.2500%BWOB Fluid loss D153 0.1000%BWOB Antisettling Page 11 on 5-S4 9-28-11.cfw.09-29-2011. LoadCase 9 5/8 FP;Version wcs-cem462_12 Client : Eni Petroleum Well : 0115-S4 Schlumberger String : 9 5/8 District : Prudhoe Bay Alaska Country : USA Loadcase : 9 5/8 FP Citric Pill DESIGN Fluid No: 5 Density : 9.49 lb/gal Rheo. Model : HERSCHEL_B. k : 8.82E-3 Ibf.s^n/ft2 At temp. : 58 degF n : 0.572 Ty :9.46 lbf/100ft2 Gel Strength :(lbf/100ft2) Job volume : 35.0 bbl Annulus ID : 9.625 in-OD : 12.250 in 0 N= Citric Fill DeepCRETE(12.5) — MIDPUSHII — Mid 0 O— I— O0— i..,. O j O • O N O U � LL O (Ni 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 oil 5-S49-28-11.cfw;09-29-2011; LoadCase 95/8 FP;Version wcs-cem482_12 Client : Eni Petroleum Well : 0115-S4 Schlumberger String : 9 5/8 District : Prudhoe Bay Alaska Country : USA Loadcase : 9 5/8 FP Section 5: centralizer placement Top of centralization :50.0 ft Bottom Cent. MD :11041.0 ft Casing Shoe :11051.0 ft NB of Cent. Used :52 NB of Floating Cent. :52 Centralizer Placement Bottom MD Nbr. Cent.I Cent. Name Code Min.STO @ Depth (ft) Joint (%) (ft) 8891.0 0 0/0 0.0 8909.3 9891.0 25 1/1 NW-TR-9 5/8-6-TR 3A W090 0.0 9879.8 10011.0 0 0/0 0.0 9891.0 11011.0 25 1/1 NW-TR-9 5/8-6-TR 3A W090 0.0 10022.2 11051.0 2 2/1 NW-TR-9 5/8-6-TR 3A W090 82.1 11051.0 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-9 5/8-6-TR 3A W090 9 5/8 12.850 11.591 No Hannover 11.625 775.59 5626.97 ft 0 20 40 60 80 100 0- A > I I 1 Betw een Cent. + +At Cent. w O O O M O O CO 8- O _ - O 0 Well Pipe Standoff Page 13 0115-S4 9-28-11.ctw;09-29-2011; LoadCase 9 5/8 FP;Version wcscem462_12 Client : Eni Petroleum Well : 0115-S4 Schlumberger String : 9 5/8 District : Prudhoe Bay Alaska Country : USA Loadcase : 9 5/8 FP Section 6: WELLCLEAN II ft 0 59— CementtdBe .Coveragent. 100 0 -- Mud Contamination Uncontaminated 25 50 75 100 > -H — Std Betw.Cent. Mud ted Slurry I ---� lt') L----c. 1_ I 3--- Z Fluid Sequence Cement Coverage Uncontaminated Slurry Fluids Concentrations Risk Mud on the Wall ° z z 7000 - - 7000 7000-1 (__ -7000 7500 7500 7500- ti fr. -7500 MOO 8000 B000 -8000 -E. 8500 t 8500 L 8500 1 18500 £ 9000 9000 £ £ 9000 -9000 £ 4 4 0 9500 9500 c c 9500 -9500 c 10000 7 _ 10000 10000 -10000 10500 10500 10500 ! -10500 1 1900 11000 1 1900_i -11000 4 0 44 4 0 0 Z 2 = Mud = High = Low I I DeepCRETE 112.5) I- I Medium = None I I MUDPUSH II I I Citric Pill I Page 14 0115-S49-28-11.cfw.09-29-2011; LoadCase95/8FP;Version wcs-cem462_12 f Client : Eni Petroleum Well : 0115-S4 Schl bergcr String : 9 5/8 District : Prudhoe Bay Alaska Country : USA Loadcase : 9 5/8 FP Section7: operator summary TOTAL MATERIAL REQUIREMENTS Additives Total Item Pack. Packaging Comments Quantity Quantity Name D962 80877 lb 809 sack 100 lb D047 8.0 gal 2 can 5.0 gal D182 560 lb 23 sack 251b F103 160.0 gal 33 can 5.0 gal D031 9437 lb 86 sack 110 lb D046 162 lb 4 sack 50 lb D065 202 lb 5 sack 50 lb D167 202 lb 9 sack 251b D153 81 lb 4 sack 251b D122A 17.5 gal 4 _ can 5.0 gal Mix Water Requirements : Fresh water 178 bbl Citric Pill 35 bbl MIXING PREPARATION MUDPUSH II Volume :80.0 bbl Density: 10.50 lb/gal Code Quantity Design Fresh water 68.572 bbl D047 8.000 gal 0.1000 gal/bbl of spacer D182 560.000 lb 7.0000 Ib/bbl of spacer F103 160.000 gal 2.0000 gal/bbl of spacer D031 9436.544 lb 117.96 lb/bbl of spacer DeepCRETE (12.5) Volume :231.0 bbl Density : 12.33 lb/gal Yield : 1.60 ft3/sk Dry Phase Liquid Phase Blend: (lb) De_s_ign Mix Water 109.0 bbl 10.0 bbl LAS Design 12.5(0.76) 80876.484 lb Fresh 109.037 10.001 bbl water bbl D046 161.753 lb 0.2000%BWOB D065 202.191 lb 0.2500%BWOB D167 202.191 lb 0.2500%BWOB D153 80.876 lb 0.1000%BWOB Page 15 0115-54 9-28-11.cfw;09-29-2011; LoadCase 9 5/8 FP;Version wcs-cem462_12 vos Oliktok Point Nikaitchuq Field o ' ( petroleum 0115-S4 (P5) Alaska DIR/LWD FORM DEPTH HOLE CASING MUD INFO Drilling MWD MD TVD SIZE SPECS Hazards Cement to Surface 20" Hole Angle X-65 00 20"Conductor Shoe 160' 160' N/A Welded/Driven N/A 0 GR/Res - Surface Csq Dir -o 13-3/8" in Base Permafrost 1,903' 1,778' a 68 lbs/ft MW(ppg) Wellbore Stability cn Mud Motor rr L-80,BTC 9.2-9.5 Lost Circulation Hole Cleaning 13-3/8"Casing Point 2,410' 2.173' . 16" 50°F WBM GR/RES PWD Inter.Casing Wellbore Stability 9-5/8" Lost Circulation Xceed 900 _ 40 lbs/ft MW(ppg) Hole Cleaning L-80.Hydril 563 9.4 Torque&Drag TOC 8,36.'/ . c "N"Sand Top 9.366' Injection Packer 9.852' aill' NOTE:Injectors REQUI 3E CBL on Intermediate Casing TOL 10.852' 'D m 9-5/8"Casing Point 11,052' 3,779' 12-1/4" 85"F LSND GR/RES Periscope/PWD Wellbore Stability SONIC Lost Circulation Schrader Bluff Liner Hole Cleaning Lateral 4-1/2" Torque&Drag 11.6 lbs/ft MW(ppg) Xceed 675 L-80,Hydril 521 9.4 (Geo-Steering) 4-1/2"Liner TD 19,191' 3,586' 8-1 2" 85"F OBM 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 = x 10 +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 E niii 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 I/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 Enii 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 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. -,q S P E O IDENTIFICATION CODE PAG 209 OF 338 �� ENI S.p.A. EMI E&P Division REVISION STAP-P-1-M-6140 0 1 fillit LEAK-OFF TEST REPORT Report N° Date: WELL NAME: WELL CODE: CONTRACTOR: RIG NAME: RIG CODE: Open hole depth(m): 825 Mud T}pe: FWGELS Rig type: J.UPs Hole CIameter(in): 12"1/4 Weight(KgA): 1.3 R.K.B.elewit on(m). 26 Last Csg.Shoe(m): 797 Marsh Viscosity(seo/ot). 44 Water Depth(m): 24 Csg.diameter(in): 13'3/8 P.V.(cps): 19 Pumps: 12-P-160 Grade: J.55 Y.P.1b/100 R'): 5 Liners On): 6.5" Weight Ob/t): 61 Gelo b/100 V): 2/8 Flow Rate(bpi): 0.25 Man.Burst pres(psi): 3103 W.L(ccRD min): 10.5 Lithology Shale Expected EMVV 1.68 Kg/cm2I10 m 1 Time Volume Pressure Time Volume Pressure Time Volume Pressure (min) (bd) (Psi) (min) (bbl) (Psi) (min) (bbl) (Psi) 1 025 50 9 2 490 16 2 435 2 050 100 95 2 480 3 0.75 200 10 2 470 4 1.00 300 10.5 2 463 5 125 400 11 2 455 .- ., 6 150 500 11.5 2 450 7 1.75 570 12 2 445 8 200 600 13 2 440 8 200 550 14 2 437 8.5 200 505 15 2 435 Note. Pumped with a constant low rate of(b bl)' V fume pumped(bbl): plume returned(bbl). (psi) 1000 - 900 • 800 . stop pump P 700 • r ----„,:.. e 600 shut in curve S 500 �+ . S ~r—•--•— • a • • LI 400 - • - r 8 minutes e 300 • - - 200 • 100 - . 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(Obi) 4 lb Time mins RESULTS: (P res s.mw+Press:.uo.)x10rD epth=[(1.3 x 797/10)+(430 x 0.07))x1 0/797=1.68(Kg/cm2/10 m) Note. I Company Representative Figure 15-1 - Leak-Off Test Report REV DATE BY CK APP DESCRIPTION REV DATE BY L:n APP DESCRIPTION 1 12/16/08 MRT AJR Add New Well Conductors 4-24 2 12/23/08 JFC JMS Add New Well Conductor OP26 Oliktok OLIKTOK vl 1 5 Point 0 INTAKE DOCK OPP THIS MODULE OP a PR0 ck /5 SURVEYS5 ON • „„ �t� DS-3R DEW UNE ~/ Ina , SITE 0 SW , a OUKTOK POINT MODULES ------1-/ N_ DC STAGING AREA•, T13N, R9E 18 'DS-3Q �, J �,. illoi � 1::o11'` 15 SCALE: r,,_ / Li ; ,, i 0 • \�r Ds 30 1 = 150' tJ 19 — ' 21�1 r \ A. ,_2,, STP P A > VICINITY MAP o,o SCALE: 1” = 1 Mile o °'0x0-0 0 0.0 0.0\." 0. moo0"3 ` 00 O-o �� eP \o� aSo \\\.\\ 000000�i> G0- 0000.0 O,a Oi9�S�O � `\ <�O 00.0^3." s \ 'L qz_____--)? o���,-' \ O \ / \ 02 ` OLIKTOK POINT PAD \ 0- go \ ,..s \ 0 I n9t \ J \ / \ \ SEE SHEET 3 FOR NOTES / o Existing Conductor ---' LOUNSBURY & ASSOCIATES, INC. • Conductor Asbuilt this survey / SURVEYORS ENGINEERS PLANNERS / AREA: MODULE: UNIT: ri LIKTK PONT PA � - Eno• Pctji"iroll�tuiiri fiS OWELLO CO DIUC ORD CMI ASBUILT LOCATIONS CADD FILE NO. DRAWING NO: PART: REV: LK680D1 10/9/08 NSK 6.80—di I 1 OF 3 I 2 REV DATE BY CK APP DESCRIPTION 'REV DATE BY .: APP DESCRIPTION 1 12/16/08 MRT AJR Add New Well Conductors 4-24 2 12/23/08 JFC J JMS Add New Well Conductor OP26 PROTRACTED SECTION 5, T. 13 N., R. 9 E., UMIAT MERIDIAN AK STATE PLANE(NAD83) LATITUDE(N) LONGITUDE(W) SEC. LINE PAD O.G. WELL NO. 'y' 'x NAD83 NAD83 OFFSET ELEV. ELEV. F.N.L. F.E.L. OP-11 6,036,332.70 1,656,791.89 70°30'39.015" 149°51'57.587" 2,052 1,519 12.1 4.0 OP-12 6,036,328.85 1,656,784.83 70°30'38.977" 149°51'57.795" 2,056 1,526 12.2 4.0 0P03-P05 6,036,325.10 1,656,777.76 70°30'38.940" 149°51'58.004" 2,059 1,533 12.2 4.0 0PO4-P07 6,036,321.43 1,656,770.69 70°30'38.904" 149°51'58.212" 2,063 1,541 12.2 3.8 OP05 6,036,317.71 1,656,763.67 70°30'38.868" 149°51'58.419" 2,067 1,548 12.2 3.7 OP06 6,036,313.96 1,656,756.55 70°30'38.831" 149°51'58.629" 2,070 1,555 12.2 3.6 OP07 6,036,306.41 1,656,742.45 70°30'38.757" 149°51'59.045" 2,078 1,569 12.2 3.5 OP08 6,036,302.66 1,656,735.36 70°30'38.720" 149°51'59.254" 2,082 1,576 12.2 3.5 OP09 6,036,298.90 1,656,728.32 70°30'38.683" 149°51'59.462" 2,085 1,583 12.2 3.5 OP10 6,036,295.16 1,656,721.26 70°30'38.647" 149°51'59.670" 2,089 1,590 12.2 3.7 OP11 6,036,291.38 1,656,714.21 70°30'38.610" 149°51'59.878" 2,093 1,597 12.2 3.8 OP12 6,036,287.63 1,656,707.14 70°30'38.573" 149°52'00.086" 2,097 1,604 12.2 4.0 OP13 6,036,276.37 1,656,685.97 70°30'38.463" 149°52'00.711" 2,108 1,626 12.2 3.6 OP14 6,036,272.66 1,656,678.89 70°30'38.426" 149°52'00.920" 2,112 1,633 12.2 3.5 OP15 6,036,268.88 1,656,671.79 70°30'38.389" 149°52'01.129" 2,115 1,640 12.2 3.4 OP16 6,036,265.11 1,656,664.75 70°30'38.353" 149° 52'01.337" 2,119 1,647 12,2 3.3 OP17 6,036,261.36 1,656,657.70 70°30'38.316" 149° 52'01.545" 2,123 1,654 12.2 3.2 OP18 6,036,257.62 1,656,650.62 70°30'38.279" 149° 52'01.753" 2,127 1,681 12.2 3.1 OP19 6,036,250.09 1,656,636.50 70° 30'38.205" 149°52'02.170" 2,134 1,675 12.2 2.5 OP20 6,036,246.31 1,656,629.41 70° 30'38.168" 149°52'02.379" 2,138 1,682 12.2 2.2 OP21 6,036,242.57 1,656,622.39 70°30'38.132" 149°52'02.586" 2,141 1,689 12.2 1.9 OP22 6,036,238.82 1,656,615.39 70°30'38.095" 149°52'02.793" 2,145 1,696 12.2 1.7 OP23 6,036,235.05 1,656,608.27 70°30'38.058" 149°52'03.003" 2,149 1,703 12.2 1.5 OP24 6,036,231.36 1,656,601.27 70°30'38.022" 149°52'03.209" 2,153 1,710 12.2 1.3 DISPOSAL WELLS AK STATE PLANE(NAD83) LATITUDE(N) LONGITUDE(W) SEC. LINE PAD O.G. WELL NO. 'y' 'x NAD83 NAD83 OFFSET ELEV. ELEV. F.N.L. F.E.L. OP25 6,036,004.35 1,656,510.91 70°30'35.791" 149°52'05.885" 2,380 1,802 12.2 -2.7 OP26 6,036,012.10 1,656,525.47 70°30'35.867" 149°52'05.456" 2,372 1,787 12.2 -2.7 LOUNSBURY & ASSOCIATES, INC. SURVEYORS ENGINEERS PLANNERS AREA: MODULE: UNIT: fra • ((�� JL _.. Eno Peturollktu��ro WELL CONDUCTOR PAD Chill E C DUCTOR ASBUILT LOCATIONS CADD FILE NO. DRAWING NO: PART: REV: LK68OD1 10/9/08 NSK 6.80-di 2 of 3 2 REV DATE BY CK APP DESCRIP11ON REV DATE BY .t APP DESCRIPTION 1 12/16/08 MRT AJR Add New Well Conductos 4-24 2 12/23/08 JFC I JMS Add New Well Conductor OP26 NOTES 1. COORDINATES SHOWN ARE A.S.P. ZONE 4, NAD 83. DISTANCES SHOWN ARE TRUE HORIZONTAL DISTANCES. 2. GEODETIC COORDINATES SHOWN ARE NAD 83. 3. BASIS OF LOCATIONS ARE DERIVED FROM OPUS SOLUTIONS. 4. CONDUCTORS ARE LOCATED WITHIN PROTRACTED SECTION 5, TOWNSHIP 13 NORTH, RANGE 9 EAST, UMIAT MERIDIAN. 5. ALL ELEVATIONS SHOWN ARE B.P.M.S.L. DATUM. 6. SEE LOUNSBURY DOCUMENT L-2539 FOR NAD27 INFORMATION. SURVEYOR'S CER TI FI CA TE / J.— .` ••� i , ' ., ' h \ / I HEREBY CERTIFY THAT I AM PROPERLY I r,,, if.. 0 REGISTERED AND LICENSED TO PRACTICE 0 W 0 .., LAND SURVEYING IN THE STATE OF I - ALASKA AND THAT THIS PLAT REPRESENTS / v• J. ROOKUS / o r A SURVEY DONE BY ME OR UNDER MY VA 'nTF LS-803,,p ..-:_• 1 Jam,= DIRECT SUPERVISION AND THAT ALL I. <<`o p*0.3 f18o'�,p 4 DIMENSIONS ASA OF DECEMBER 23, 2008. ,DINER DETAILS ARE ++,IlIk\"���►�PEssi ♦�•• 0LOUNSBURY . & ASSOCIATES, INC. SURVEYORS ENGINEERS PLANNERS AREA: MODULE: UNIT: itZa OLIKTOK POINT 77-51- Cir ii PPt� rollktu��nn WELL CONDUCTOR D Clnlil ASBUILT LOCATIONS CAD FILE NO.LK680D1 10/9/08 DRAWING NO: NSK 6.80—d1 PART: REV: 3 OF 3 2 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 LETTERjCHECKLIST WELL NAME 0:11�. �J - PTD# "l l Development Service Exploratory Stratigraphic Test Non-Conventional Well FIELD: 1ikcifrcJiwq lPOOL: Sckra cf &Lu Check Box for Appropriate Letter/ Paragraphs to be Included in Transmittal Letter CHECK ADD-ONS WHAT (OPTIONS) TEXT FOR APPROVAL LETTER APPLIES MULTI LATERAL The permit is for a new wellbore segment of existing well (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. Rev:9/09/2011 V ma 0 r- .g O g 3 vm 3 m - j-a o N o _ rn No 0 o 0 -R-3 m 3 W W co W W W W C..) � CJ N N IV N N IV N N N N - CO 00 V 0) 07 .1). 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