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Home My WebLink About211-130Nolan Vlahovich Hilcorp Alaska, LLC Geotech 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 564-4558 E-mail: nolan.vlahovich@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal. Received By: Date: Date: 2/4/2026 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20260204 Well API #PTD #Log Date Log Company Log Type AOGCC E-Set# BRU 223-34T 50283202060000 225059 12/31/2025 AK E-LINE Perf T41308 BRU 244-27 50283201850000 222038 1/2/2026 AK E-LINE Perf T41309 CLU 11RD 50133205590000 225013 1/2/2026 YELLOWJACKET SCBL T41310 CLU 11RD 50133205590000 225013 12/19/2025 YELLOWJACKET SCBL T41310 END 1-25A 50029217220100 197075 11/7/2025 HALLIBURTON COILFLAG T41311 END 1-25A 50029217220100 197075 12/26/2025 READ PressTempSurvey T41311 END 2-40 50029225270000 194152 12/18/2025 READ PressTempSurvey T41312 END 2-52 50029217500000 187092 12/24/2025 HALLIBURTON MFC40 T41313 END 2-56A 50029228630100 198058 1/1/2026 HALLIBURTON COILFLAG T41314 END 2-56A 50029228630100 198058 1/19/2026 READ CaliperSurvey T41314 KALOTSA 3 50133206610000 217028 1/14/2026 YELLOWJACKET PERF T41315 KALOTSA 3 50133206610000 217028 1/9/2026 YELLOWJACKET PERF T41315 KALOTSA 8 50133207050000 222003 12/18/2025 YELLOWJACKET PERF T41316 KBU 44-06 50133204980000 200179 12/22/2026 YELLOWJACKET CBL T41317 KBU 44-06 50133204980000 200179 11/12/2025 YELLOWJACKET PLUG T41317 KU 24-07RD 50133203520100 205099 1/6/2026 AK E-LINE CBL T41318 KU 24-07RD 50133203520100 205099 1/6/2026 AK E-LINE Plug/Cement T41318 KU 24-07RD 50133203520100 205099 1/1/2026 AK E-LINE Plug/Cement/TubingPunch T41318 MPI-36 50029236770000 220047 1/19/2026 READ CaliperSurvey T41319 MPI-36 50029236770000 220047 1/19/2026 READ LeakDetectLog T41319 NCIU A-19 50883201940000 224026 1/7/2025 AK E-LINE Perf T41320 NFU 42-35 50231200460000 214170 1/8/2026 YELLOWJACKET PERF T41321 NIK OI24-08 50029234570000 211130 1/19/2026 HALLIBURTON COILFLAG T41322 ODSN-04 50703206700000 213037 1/20/2026 HALLIBURTON LDL T41323 ODSN-22 50703207080000 215054 12/20/2025 READ LeakDetection T41324 PBU 15-11D 50029206530400 225112 1/18/2026 HALLIBURTON RBT-COILFLAG T41325 PBU 15-43 50029226760000 196083 12/21/2025 HALLIBURTON RBT T41326 PBU B-30B 50029215420200 225009 1/24/2026 HALLIBURTON RBT-COILFLAG T41327 PBU C-33B 50029223730200 225096 12/16/2025 HALLIBURTON RBT-COILFLAG T41328 NIK OI24-08 50029234570000 211130 1/19/2026 HALLIBURTON COILFLAG Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2026.02.05 09:10:43 -09'00' Nolan Vlahovich Hilcorp Alaska, LLC Geotech 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 564-4558 E-mail: nolan.vlahovich@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal. Received By: Date: PBU D-26B 50029215300200 206098 12/20/2025 HALLIBURTON ISAT T41329 PBU D-26B 50029215300200 206098 12/19/2025 BAKER SPN T41329 PBU F-21A 50029219490100 225019 1/18/2026 HALLIBURTON RBT-COILFLAG T41330 PBU J-21A 50029217050100 225106 1/21/2026 HALLIBURTON RBT-COILFLAG T41331 PBU L-291 50029237790000 224002 12/26/2025 HALLIBURTON RBT T41332 PBU L-291 50029237790000 224002 12/9/2025 YELLOWJACKET RCBL T41332 PBU S-107A 50029220440200 225083 12/8/2025 HALLIBURTON RBT-COILFLAG T41333 PBU S-201A 50029229870100 219092 1/21/2026 HALLIBURTON WFL-TMD3D T41335 PBU S-24B 50029220440200 203163 12/22/2025 HALLIBURTON RBT T41334 PBU S-24B 50029230230100 203163 12/23/2025 HALLIBURTON WFL-TMD3D T41334 SRU 223-15 50133207410000 225123 1/29/2026 YELLOWJACKET GPT-PERF T41336 SRU 223-15 50133207410000 225123 1/20/2026 YELLOWJACKET SCBL T41336 SRU 233-10 50133207400000 225113 12/30/2026 AK E-LINE CBL T41337 SRU 233-10 50133207400000 225113 1/10/2026 YELLOWJACKET SCBL T41337 SRU 233-10 50133207400000 225113 1/6/2026 YELLOWJACKET SCBL T41337 SRU 34-28 50133101580000 163007 1/7/2026 YELLOWJACKET Gamma Ray T41338 SU 32-16 50133207380000 225095 1/17/2026 YELLOWJACKET GPT-PLUG-PERF T41339 SU 32-16 50133207380000 225095 11/22/2025 YELLOWJACKET SCBL T41339 SU 43-10 50133207390000 225107 12/10/2025 YELLOWJACKET SCBL T41340 TBU A-12RD 50883200320100 171029 1/2/2026 AK E-LINE StripGun T41341 TBU D-24A 50733202240100 174064 12/4/2025 AK E-LINE TubingPunch T41342 Please include current contact information if different from above. Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2026.02.05 09:11:00 -09'00' CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:Wallace, Chris D (OGC) To:AOGCC Records (CED sponsored) Subject:FW: Operable: PWI OI24-08 (PTD:2111300) Passing CMIT-TxIA Date:Tuesday, January 20, 2026 11:09:55 AM From: Ryan Thompson <Ryan.Thompson@hilcorp.com> Sent: Tuesday, January 20, 2026 11:03 AM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Cc: Regg, James B (OGC) <jim.regg@alaska.gov>; Sara Hannegan <shannegan@hilcorp.com> Subject: Operable: PWI OI24-08 (PTD:2111300) Passing CMIT-TxIA Mr. Wallace, PWI well OI24-08 (PTD# 2111300) passed an AOGCC witnessed CMIT-TxIA on 1/20/2026 per AIO 36.011. The well is now re-classified as Operable and will be placed back on injection. Please respond with any questions. Thank you, Ryan Thompson Milne / Islands / WNS Well Integrity Engineer 907-564-5005 From: Stephen Soroka <steve.soroka@hilcorp.com> Sent: Wednesday, December 31, 2025 7:13 AM To: chris.wallace@alaska.gov Cc: jim.regg <jim.regg@alaska.gov>; Ryan Thompson <Ryan.Thompson@hilcorp.com>; Alaska NS - Wells Integrity <AKNSWellsIntegrity@hilcorp.com> Subject: Not Operable: PWI OI24-08 (PTD:211130), Missed 2-Year Witnessed CMIT-TxIA Mr. Wallace PWI well OI24-08 (PTD: 2111300) will be shut in and made Not Operable tonight 12/31/25 for missing its 2-year CMIT-TxIA in December. A witnessed CMIT-TxIA will be scheduled once the well is returned to injection and stable. Please respond with any questions. Thank You Steve Steve Soroka Hilcorp Alaska LLC Field Well Integrity Steve.Soroka@hilcorp.com P: (907) 830-8976 Alt: Chris Casey 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. 1. Operations Susp Well Insp Plug Perforations Fracture Stimulate Pull Tubing Operations shutdown Performed: Install Whipstock Perforate Other Stimulate Alter Casing Change Approved Program Mod Artificial Lift Perforate New Pool Repair Well Coiled Tubing Ops Other: Patch Set_ Development Exploratory Stratigraphic Service 6. API Number: 7. Property Designation (Lease Number):8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071):10. Field/Pool(s): 11. Present Well Condition Summary: Total Depth measured 18670 feet N/A feet true vertical 3429 feet N/A feet Effective Depth measured 18660 feet 8647 feet true vertical 3429 feet 3498 feet Perforation depth Measured depth 8993-18660 feet True Vertical depth 3516-3429 feet Tubing (size, grade, measured and true vertical depth)4.5"L-80 8640 3497 Packers and SSSV (type, measured and true vertical depth)HES PHL 8647 3498 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13a. Prior to well operation: Subsequent to operation: 13b. Pools active after work: 15. Well Class after work: Daily Report of Well Operations Exploratory Development Service Stratigraphic Copies of Logs and Surveys Run 16. Well Status after work: Oil Gas WDSPL Electronic Fracture Stimulation Data GSTOR GINJ SUSP SPLUG Sundry Number or N/A if C.O. Exempt: Authorized Name and Giorgio Iannucci 1/22/2024 Digital Signature with Date:Contact Name:Amjad Chaudhry Contact Email:amjad.chaudhry@eni.com Authorized Title:Well Operations Project Manager Contact Phone:907-865-3300 measured TVD Production Liner 8993 8775 Casing Structural 3516 4.5" 8993 18660 3429 Plugs Junk measured 2413 2135 20" 13.375" Size 160 9.625" ICD's 5210 6890 Burst Collapse 2480 4790 N/A 5. Permit to Drill Number:2. Operator Name 4. Well Class Before Work: ADL 355024, 373301, 391283 Nikaitchuq/Schrader Bluff ENI US Operating Co. Inc. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 211-130 50-029-23457-00-00 3700 Centerpoint Dr. Ste 500, Anchorage, AK, 99503 3. Address: OI24-08 MD 154 measured true vertical Packer Representative Daily Average Production or Injection Data Casing Pressure Tubing Pressure N/A 4823507 N/A Length 160 2413 160Conductor Surface Intermediate 324-002 Sr Pet Eng: ICD's Sr Pet Geo:Sr Res Eng: WINJ WAG N/A Water-BblOil-Bbl 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Gas-Mcf 0 0N/A 0 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) N/A p k ft t Fra O s 211 6.A G L PG , Form 10-404 Revised 10/2022 Due Within 30 days of Operations Submit in PDF format to aogcc.permitting@alaska.gov rgio Iannucci By Grace Christianson at 11:17 am, Jan 23, 2024 RBDMS JSB 013024 DSR-1/26/24 13-3/8" 68 ppf,Surf. Casing,2,413' MD, ' 2,135' TVD45º Inc9-5/8" 40 ppf, H563,Intermediate Casing,8,993' MD, 3,516' TVD,90º Inc4-½”,12.6 ppf,H563, Production Tubing4-½” 11.6 ppf, H521Production Liner,18,660' MD, 3,429' TVD91º IncZonal Isolation PackersInjection Control DevicesPHL Retr. Packer, 8,647' MD, 3,498' TVD, 84º IncMDK 06/11/12Nikaitchuq Field – Oliktok Point PadUpdatedJan 19, 20242,358' MD, 2,097 ' TVD, 46º Inc - 4-½” x 1" KBMG GLM, DV installed 2,265 MD, 2,031 TVD - 3.81" X-nipple for possible injection valve8,680' MD - HAL Mirage Plug with Auto-fill valve 8,594' MD - 3.81" X-nipple VIT, 3 joints, 4-½” x 6", approx 100'OI24-08 Injector Monobore with Injection Control8,801' MD , 3,513' TVD– Bottom of entry guide8,666' MD - 3.725" XN 8,775' MD – Top of SLZXP Liner Hanger/Packer Item MD(ft) Item MD(ft)ICD#1 18405 ICD#10 13359ICD#2 17910 ICD#11 12822ICD#3 17533 ICD#12 11996ICD#4 16743 ICD#13 11579ICD#5 16244 ICD#14 11166ICD#6 15706 ICD#15 10258ICD#7 15170 ICD#16 9922ICD#8 14424 ICD#17 9411ICD#9 13891Item MD(ft)4Ͳ1/2"SwellPkr#1 169784Ͳ1/2"SwellPkr#2 147734Ͳ1/2"SwellPkr#3 122674Ͳ1/2"SwellPkr#4 107304Ͳ1/2"SwellPkr#5 96844-½” Ecc-NoseGuide ShoeBaker 45KB Retrievable Tubing Patch:Top of patch: 1884.4' ELMDBottom of patch: 1930.4' ELMDID: 2.40" Well Name: OI24-08 OR Wellbore Name: OI24-08 Well Code: 26154 Job: RIGLESS WCEI Level: N/A Daily Report Date: 1/16/2024 Report #: 1 Page: 1 of 1 Well Header Permit/Concession N° ADL-388583 Operator ENI PETROLEUM Subsidiary ENI Petroleum Co. Inc. Initial Lahee Code WATER INJECTION WELL Rotary Table Elevation (ft) 53.15 Ground Level (ft) 12.20 First Flange (ft) 16.19 RKB - Base Flange (ft) 36.96 RKB - Tubing Spool (ft) Rig Information Rig Name Contractor Rig Type Rig Num Daily Information Weather Blowing snow Temperature (°F) -21.0 Wind NE@ 33 MPH Days LTI (days) 1,473.00 Days RI (days) POB 22.0 Daily Summary Operations 24h Forecast Stand down for weather to pass. High winds and poor visibility. When operations resume run BHA #1 with 3.79" drift & 4.5" brush to 2500' and make 5 cleaning passes from 2000' - 1850'. Run BHA #2 with 45KB Baker patch and set. 24h Summary MIRU rig-less operations and all support equipment. Install upper swab valve and wire line valves. Waiting on weather. Operation at 07.00 Waiting on weather. Time Log Start Time End Time Dur (hr) Cum Dur (hr)Phase Opr. Act. Plan Oper. Descr. 00:00 10:00 10.00 10.00 PROD- MAN A 1 P Snow removal and scrap pad. Held pre job safety meeting with all crews. MIRU rig-less operations and all support equipment. Lay out herculite for spill protection & set up exclusion zones. 10:00 11:00 1.00 11.00 PROD- MAN R 25 TS03 Halliburton E-line trouble shooting firing panel and no connectivity to the tool string. 11:00 13:00 2.00 13.00 PROD- MAN R 5 P Re-head cable head. NU upper swab valve and wire line valve on well. Shut down due to incoming weather with high winds and low visibility. 13:00 00:00 11.00 24.00 PROD- MAN R 22 TW01 Waiting on weather. Daily Contacts Position Contact Name Company Title Email Office Mobile Eni representative Jody Cornell ASRC Energy Services Co. Man jody.cornell@external.eni.com 907-685-0710 Eni representative Craig Smith ASRC Energy Services Co. Man craig.smith@external.eni.com 907-685-0710 Safety Representative Lonnie Kalar ASRC Energy Services HSE lonnie.karlar@external.eni.com 812-968-4595 Last Casing Seat Cas. Type OD (in) ID (in) Grade Top (ftKB) Bottom (ftKB) TVD Bot. (ftKB) Landing Date LINER 4 1/2 L80 8,775.8 18,660.0 3,423.3 6/8/2012 Well Name: OI24-08 OR Wellbore Name: OI24-08 Well Code: 26154 Job: RIGLESS WCEI Level: N/A Daily Report Date: 1/17/2024 Report #: 2 Page: 1 of 1 Well Header Permit/Concession N° ADL-388583 Operator ENI PETROLEUM Subsidiary ENI Petroleum Co. Inc. Initial Lahee Code WATER INJECTION WELL Rotary Table Elevation (ft) 53.15 Ground Level (ft) 12.20 First Flange (ft) 16.19 RKB - Base Flange (ft) 36.96 RKB - Tubing Spool (ft) Rig Information Rig Name Contractor Rig Type Rig Num Daily Information Weather Clear Temperature (°F) 5.0 Wind SE @ 30 MPH Days LTI (days) 1,474.00 Days RI (days) POB 20.0 Daily Summary Operations 24h Forecast Fluid pack IA with LVT for MIT test.Rig down tools and equipment. 24h Summary Wait on weather. Function test wire line valves, make up brush and pressure test lubricator, run in the hole and correlate tie in points, perform brush and flush over patch setting area, pull out of hole and lay down tools, pick up patch, pressure test lubricator, run in hole and correlate tie in points, set patch, pull out of hole. Operation at 07.00 Waiting on weather. Time Log Start Time End Time Dur (hr) Cum Dur (hr)Phase Opr. Act. Plan Oper. Descr. 00:00 09:00 9.00 9.00 PROD- MAN R 22 TW01 Wait for the weather due to high winds. 09:00 10:00 1.00 10.00 PROD- MAN R 1 P Attend DWOP teams meeting with contractors and Anchorage office. 10:00 12:00 2.00 12.00 PROD- MAN R 12 P ENI Company Rep Witness Function test wire line valve. Make up 3.79-gauge ring, 4.5” brush, CCL and stab on lubricator. Pressure test lubricator to 1,000 PSI low and 2,000 PSI high. 12:00 16:00 4.00 16.00 PROD- MAN R 15 P Run hole with 3.79-gauge ring, 4.5” brush, and CCL to 2,500’ WLM. Pull out of hole while logging to 2,260’ WLM. Perform logging run with same interval a total of 3 times. Perform brush and flush from 2,000’ WLM to 1,850’ MD 5 times while pumping @ 0.5 BBLS/minute. 15 total BBLS pumped. Pull out of hole and lay down gauge ring/brush BHA. 16:00 20:00 4.00 20.00 PROD- MAN R 15 P ENI Company man witness tool lengths, Pick up lubricator LRS P/T Lubricator 500 psi low/ 2,000 psi high, Run in the hole with BHA #2 tubing patch assembly to 2,500 wlm. Length of Patch BHA with running tool engaged – 50.10’. Correlate up pass #1 to 1,638.2 wlm. Run in the hole to 2,500 wlm correlate pass no #2' to 1,640 wlm, Run in the hole to 2,500 correlate up pass #3 to 2,258, Merge 3 passes and gauge run pass on caliber logs. 20:00 21:00 1.00 21.00 PROD- MAN R 1 P Teams meeting with ENI reps, Baker Hughes, discuss tubing patch correlation setting Depth. 21:00 22:30 1.50 22.50 PROD- MAN R 15 P POOH to setting depth with CCL @ 1882' with top of patch @ 1891' BTM of patch @ 1925.5' HW-1,000 LBS P/U wt 1100 LBS Fire Baker 10 @ 2212 hrs. 30 seconds, with a wt, loss 430 LBS, HW-350ibs wait 3 min for setting sequence, slack off and set 100 IBS. on patch 22:30 00:00 1.50 24.00 PROD- MAN R 15 P POOH pick up wt,- 600 IBS, HW-570 to surface, Little red services began filling the back side with LVT for MIT test Daily Contacts Position Contact Name Company Title Email Office Mobile Eni representative Craig Smith ASRC Energy Services Co. Man craig.smith@external.eni.com 907-685-0710 Safety Representative Lonnie Kalar ASRC Energy Services HSE lonnie.karlar@external.eni.com 812-968-4595 Last Casing Seat Cas. Type OD (in) ID (in) Grade Top (ftKB) Bottom (ftKB) TVD Bot. (ftKB) Landing Date LINER 4 1/2 L80 8,775.8 18,660.0 3,423.3 6/8/2012 Well Name: OI24-08 OR Wellbore Name: OI24-08 Well Code: 26154 Job: RIGLESS WCEI Level: N/A Daily Report Date: 1/18/2024 Report #: 3 Page: 1 of 1 Well Header Permit/Concession N° ADL-388583 Operator ENI PETROLEUM Subsidiary ENI Petroleum Co. Inc. Initial Lahee Code WATER INJECTION WELL Rotary Table Elevation (ft) 53.15 Ground Level (ft) 12.20 First Flange (ft) 16.19 RKB - Base Flange (ft) 36.96 RKB - Tubing Spool (ft) Rig Information Rig Name Contractor Rig Type Rig Num Daily Information Weather Partly Cloudy Temperature (°F) 30.0 Wind NW @ 17 MPH Days LTI (days) 1,475.00 Days RI (days) POB 20.0 Daily Summary Operations 24h Forecast Rigless Operations completed. 24h Summary MIT test. Rig down Halliburton wireline equipment and secure well head with tree cap. Offload 49 bbl of LVT from Worley vacuum truck to Little Red Services pump truck. Stage Little Red pump truck, Worley vacuum truck and crane and secure. Prepare well handover to production.Rigless Operations completed. Operation at 07.00 Rigless Operations completed. Time Log Start Time End Time Dur (hr) Cum Dur (hr)Phase Opr. Act. Plan Oper. Descr. 00:00 17:30 17.50 17.50 PROD- MAN R 9 P Fluid pack IA and Pressure test to 1,650 psi high. IA Pressure bleeding off 100 psi every 5 min, after 45 min went down to 0 psi. Attempted this testing process several times, 10 plus. Failed each time, after 45 min went down to 0 psi. 17:30 00:00 6.50 24.00 PROD- MAN A 1 P Worley crane remove wire line BOP'S and Secondary swab valve, Rig down Halliburton wire line equipment and secure well head with tree cap. Offload 49 Bbl. of LVT from Worley vacuum truck to Little Red Services pump truck. Stage Little Red pump truck, Worley vacuum truck and crane and secure. Prepare well handover to production. Rig-Less Operations Completed.Daily Contacts Position Contact Name Company Title Email Office Mobile Eni representative Craig Smith ASRC Energy Services Co. Man craig.smith@external.eni.com 907-685-0710 Safety Representative Lonnie Kalar ASRC Energy Services HSE lonnie.karlar@external.eni.com 812-968-4595 Last Casing Seat Cas. Type OD (in) ID (in) Grade Top (ftKB) Bottom (ftKB) TVD Bot. (ftKB) Landing Date LINER 4 1/2 L80 8,775.8 18,660.0 3,423.3 6/8/2012 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: OI24-08 AA Request (PTD#211-130) Date:Friday, January 19, 2024 11:34:48 AM Attachments:image001.png From: Wallace, Chris D (OGC) Sent: Thursday, January 18, 2024 1:58 PM To: Lopez Keith <Keith.Lopez@eni.com>; Regg, James B (OGC) <jim.regg@alaska.gov>; AOGCC Reporting (CED sponsored) <aogcc.reporting@alaska.gov> Cc: Burgess Larry <Larry.Burgess@eni.com>; Morgan Michael <Mike.Morgan@eni.com>; Zuber Joshua <Joshua.Zuber@eni.com>; Province Robert <Robert.Province@eni.com>; Pitzalis Francesco <Francesco.Pitzalis@eni.com>; Lyden Dan <Dan.Lyden@eni.com>; Dexheimer Stephen <Stephen.Dexheimer@eni.com>; Iannucci Giorgio <Giorgio.Iannucci@eni.com>; Keppers Craig <Craig.Keppers@eni.com> Subject: RE: OI24-08 AA Request (PTD#211-130) Keith, We are progressing the admin approval request - so nothing else is needed. Thanks and Regards, Chris Wallace, Sr. Petroleum Engineer, Alaska Oil and Gas Conservation Commission, 333 West 7th Avenue, Anchorage, AK 99501, (907) 793-1250 (phone), (907) 276-7542 (fax), chris.wallace@alaska.gov 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 Chris Wallace at 907-793-1250 or chris.wallace@alaska.gov. From: Lopez Keith <Keith.Lopez@eni.com> Sent: Thursday, January 18, 2024 1:25 PM To: Regg, James B (OGC) <jim.regg@alaska.gov>; Wallace, Chris D (OGC) <chris.wallace@alaska.gov>; AOGCC Reporting (CED sponsored) <aogcc.reporting@alaska.gov> Cc: Burgess Larry <Larry.Burgess@eni.com>; Morgan Michael <Mike.Morgan@eni.com>; Zuber Joshua <Joshua.Zuber@eni.com>; Province Robert <Robert.Province@eni.com>; Pitzalis Francesco <Francesco.Pitzalis@eni.com>; Lyden Dan <Dan.Lyden@eni.com>; Dexheimer Stephen <Stephen.Dexheimer@eni.com>; Iannucci Giorgio <Giorgio.Iannucci@eni.com>; Keppers Craig <Craig.Keppers@eni.com>; Lopez Keith <Keith.Lopez@eni.com> Subject: RE: OI24-08 AA Request (PTD#211-130) Mr. Wallace, Eni has procured the tubing patch and installed it across the anomaly found with the acoustic log between 1,903’ – 1,918’. Unfortunately, it did not fix the communication between the tubing and the inner annulus. I believe this Administrative Approval request is still valid as written. Please let me know if you need any additional information in considering this 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 Keith.Lopez@eni.com From: Lopez Keith <Keith.Lopez@eni.com> Sent: Wednesday, December 20, 2023 2:42 PM To: jim.regg@alaska.gov; Wallace, Chris D (CED) <chris.wallace@alaska.gov>; AOGCC Reporting (DOA sponsored) <aogcc.reporting@alaska.gov> Cc: Burgess Larry <Larry.Burgess@eni.com>; Morgan Michael <Mike.Morgan@eni.com>; Zuber Joshua <Joshua.Zuber@eni.com>; Province Robert <Robert.Province@eni.com>; Pitzalis Francesco <Francesco.Pitzalis@eni.com>; Lyden Dan <Dan.Lyden@eni.com>; Dexheimer Stephen <Stephen.Dexheimer@eni.com>; Iannucci Giorgio <Giorgio.Iannucci@eni.com>; Keppers Craig <Craig.Keppers@eni.com>; Lopez Keith <Keith.Lopez@eni.com> Subject: OI24-08 AA Request (PTD#211-130) Dear AOGCC: Eni is requesting per AIO 36, Rule 6 Administrative Approval to allow Nikaitchuq Schrader Bluff injection well OI24-08 (PTD 211-130) to remain in water injection service with known tubing by inner annulus communication. With the proposed operating and monitoring plan the well will meet the criteria of 20 AAC 25.412 for continued enhanced recovery operations. Should you have any additional questions or require any additional information, please contact me at 907-865-3300. 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 Keith.Lopez@eni.com ------------------------------------------------------------------------------------------------------------------------- ----------------------------------------------- Message for the recipient only, if received in error, please notify the sender and read http://www.eni.com/disclaimer/ 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 CasingOther: Rigless Tubing Patch installation__ 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?N/A Yes No OI24-08 9. Property Designation (Lease Number):10. Field: Schrader Bluff Schrader Bluff 11. Total Depth MD (ft):Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: Junk (MD): 18,670 18660 3429 948 N/A N/A Casing Collapse Structural Conductor Surface 2480 Intermediate 4790 Production Liner ICD's 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: Amjad Chaudhry Giorgio Iannucci 1/3/2024 Contact Email:amjad.chaudhry@eni.com Contact Phone:907-865-3300 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 12-Jan-24 186608775 4.5 3429 HES PHL Perforation Depth MD (ft): L-80 8647/3498 8801 8993 2413 8993 8993-18660 4.5 3516-3429 Perforation Depth TVD (ft): 160 2413 20 13.375 160 9.625 PRESENT WELL CONDITION SUMMARY Tubing MD (ft): MD 6890 5210 3516 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL 355024, 373301, 391283 211-130 Proposed Pools: 3700 Centerpoint Dr. Ste 500, Anchorage, AK, 99503 50-029-23457-00-00 ENI US Operating Co. Inc. AOGCC USE ONLY ICD's Tubing Grade: 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: 3429 TVD BurstLengthSize Nikaitchuq Well Operations Project Manager Subsequent Form Required: Suspension Expiration Date: Tubing Size: 160 2135 m n P s Othher: R 2 6 5 6 t _ N Form 10-403 Revised 06/2023 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov nnucci true and the procedure a By Grace Christianson at 9:12 am, Jan 04, 2024 VTL 01/16/2024 Victoria Loepp 01/13/2024 SFD 1/11/2024 X X 10-404 JLC 1/16/2024 Brett W. Huber, Sr. Digitally signed by Brett W. Huber, Sr. Date: 2024.01.16 10:34:04 -09'00'01/16/24 RBDMS JSB 011624 3700 Centerpoint Drive Suite 500 Anchorage, Alaska 99503 Phone (907) 865-3300 January 3, 2024 Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Application for Sundry Approval for OI24-08 Rigless Intervention: Patch Installation Commissioners, ENI US Operating Co. Inc. hereby applies for a Sundry for well OI24-08. OI24-08 was drilled and completed on Spy Island June 2012 with an injection completion set at a depth of 8,801’ MD.Tubing to inner annulus hydraulic communication was suspected. Eni performed Rigless intervention in December 2023 to diagnose communication and result indicated there’s possible tubing to annulus communication at 1910.8’MD. A slickline/E-Line intervention is planned to install a tubing patch. This work scope has an estimated date for beginning work January 12th, 2024. Please find attached for review commission form 10-403 and supporting documentation. Questions or requests for supplemental information can be directed to: Amjad Chaudhry, 907-865-3300. Sincerely, Giorgio Iannucci Well Operations Project Manager incerely, ii i OI24-08 Intervention – Proposal Summary and Wellbore Schematic OI24-08 Slickline/E-line Tubing Patch Installation PTD#:211-130 Status Well OI24-08 is currently shut in waiting for tubing patch work. Scope of Work Eni is planning to perform a rig less intervention on OI24-08 to cure the leak point in the tubing with a tubing patch. General Well Info Reservoir Pressure/TVD: Maximum initial shut-in pressure of approximately 948 psi based on a 1,300 psi BHP (3,516’ TVD) Wellhead type/pressure rating: Vault, MB-247/5000 psi Well type: Injector Estimated start date: January 12th, 2024. Intervention Unit: Slickline / Eline Sr. Drilling Engineer: Amjad Chaudhry amjad.chaudhry@eni.com Work: 907-865-3300 Well Operations Project Manager: Giorgio Iannucci giorgio.iannucci@eni.com Work: 907-865-3300 Procedure Summary Rig up slickline unit over OI24-08. Drift to the XN nipple at 8666’ MD. RIH with brush WRthe patch setting depth ~1910.8’MD. (Contingent) Set 2-7/8”nipple reducer in XN nipple at 8666’. Rig down slickline unit. Rig up Eline unit. PU tubing patch and set the tubing patch at the definitive leak point ~1910.8’MD. DOff critical path and to “cure”the patch as per product procedure, bring on the well at standard injection rates and temperatures for 24 hours. Rig down Eline unit Once patch is cured, perform MITIA to 1650 psi to confirm successful patch installation. Current Completion Schematic Vetco Gray, MB-247/5000 psi 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:Loepp, Victoria T (OGC) To:Chaudhry Amjad Subject:Re: Sundry Application OI24-08 (PTD:211-130) Date:Saturday, January 13, 2024 1:53:00 PM Ahmjad, Approval is granted to proceed with the tubing patch. Victoria Sent from my iPhone On Jan 12, 2024, at 8:59ௗAM, Chaudhry Amjad <Amjad.Chaudhry@eni.com> wrote: Good Morning Victoria, I was wondering if you can please tell me the status of a Rigless intervention Sundry application for a tubing patch in OI24-08 (PTD: 211-130), I submitted this application on January 4th, 2024? Thanks Best regards Amjad <image002.jpg> From: Chaudhry Amjad Sent: Thursday, January 4, 2024 9:03 AM To: 'AOGCC Permitting (CED sponsored)' <aogcc.permitting@alaska.gov> Subject: Sundry Application OI24-08 (PTD:211-130) Hello Grace, Please see attached Sundry application and supporting documents for the Nikaitchuq Injector well OI24-08 well, this is a Rigless operation for a tubing patch installation. Thanks Best Regards Amjad Chaudhry P.Eng Sr. Drilling Engineer Eni US Operating Co. Inc. 3700 Centerpoint Dr., Suite 500 Anchorage, AK 99503 : 907-865-3379 D : 907-346-0591 M E.mail: amjad.chaudhry@eni.com <image001.jpg> This document and any files or e-mail messages attached to it contain data or information that is confidential, privileged or otherwise restricted from disclosure. If you are not the intended recipient, be aware that any disclosure, copying, distribution or use of any of the data or information contained herein or in any of the attachments is strictly prohibited. If you have received this document or transmission in error, please immediately notify the sender and destroy, delete or erase this document and all attachments. --------------------------------------------------------------------------------------------------------- --------------------------------------------------------------- Message for the recipient only, if received in error, please notify the sender and read http://www.eni.com/disclaimer/ <10-403 Full Sundry_20240301.pdf> Eni US Operating Co, Inc WELL LOG/DATA TRANSMITTAL To: AůaƐŬa Oiů anĚ GaƐ ConƐerǀation CoŵŵiƐƐio 333 W. 7th Ave, Anchorage, AK 99501 December 19, 2023 Well:OI24-08 LWD/MWD Logs PDF LAS DLIS Excel Mudlogs E-line logs 4.5" Multifinger Caliper Log x x 4.5" ACX 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: 211-130 T38234 12/19/2023 Kayla Junke Digitally signed by Kayla Junke Date: 2023.12.19 11:41:36 -09'00' 1. Operations Susp Well Insp Plug Perforations Fracture Stimulate Pull Tubing Operations shutdown Performed: Install Whipstock Perforate Other Stimulate Alter Casing Change Approved Program Mod Artificial Lift Perforate New Pool Repair Well Coiled Tubing Ops Other: Rigless Diagnostic_ Development Exploratory Stratigraphic Service 6. API Number: 7. Property Designation (Lease Number):8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071):10. Field/Pool(s): 11. Present Well Condition Summary: Total Depth measured 18670 feet N/A feet true vertical 3429 feet N/A feet Effective Depth measured 18660 feet 8647 feet true vertical 3429 feet 3498 feet Perforation depth Measured depth 8993-18660 feet True Vertical depth 3516-3429 feet Tubing (size, grade, measured and true vertical depth)4.5"L-80 8640 3497 Packers and SSSV (type, measured and true vertical depth)HES PHL 8647 3498 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13a. Prior to well operation: Subsequent to operation: 13b. Pools active after work: 15. Well Class after work: Daily Report of Well Operations Exploratory Development Service Stratigraphic Copies of Logs and Surveys Run 16. Well Status after work: Oil Gas WDSPL Electronic Fracture Stimulation Data GSTOR GINJ SUSP SPLUG Sundry Number or N/A if C.O. Exempt: Authorized Name and Giorgio Iannucci 12/14/2023 Digital Signature with Date:Contact Name:Amjad Chaudhry Contact Email:amjad.chaudhry@eni.com Authorized Title:Well Operations Project Manager Contact Phone:907-865-3300 323-634 Sr Pet Eng: ICD's Sr Pet Geo:Sr Res Eng: WINJ WAG N/A Water-BblOil-Bbl 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Gas-Mcf MD 154 measured true vertical Packer Representative Daily Average Production or Injection Data Casing Pressure Tubing Pressure 0 -14N/A N/A 4823507 -7 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) N/A MFC/ACX will be uploaded on SFTP site 5. Permit to Drill Number:2. Operator Name 4. Well Class Before Work: ADL 355024, 373301, 391283 Nikaitchuq/Schrader Bluff ENI US Operating Co. Inc. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 211-130 50-029-23457-00-00 3700 Centerpoint Dr. Ste 500, Anchorage, AK, 99503 3. Address: OI24-08 N/A Length 160 2413 160Conductor Surface Intermediate 20" 13.375" Size 160 9.625" ICD's 5210 6890 measured TVD Production Liner 8993 8775 Casing Structural 3516 4.5" 8993 18660 3429 Plugs Junk measured 2413 2135 Burst Collapse 2480 4790 p k ft t Fra O s 211 6. A G L PG , Form 10-404 Revised 10/2022 Due Within 30 days of Operations Submit in PDF format to aogcc.permitting@alaska.gov Giorgio Iannucci By Grace Christianson at 9:12 am, Dec 21, 2023 DSR-1/26/24 RBDMS JSB 122823 13-3/8" 68 ppf, Surf. Casing, 2,413' MD, ' 2,135' TVD45º Inc9-5/8" 40 ppf, H563,Intermediate Casing, 8,993' MD, 3,516' TVD, 90º Inc4-½”,12.6 ppf, H563, Production Tubing4-½” 11.6 ppf, H521Production Liner, 18,660' MD, 3,429' TVD91º IncZonal Isolation PackersInjection Control DevicesPHL Retr. Packer, 8,647' MD, 3,498' TVD, 84º IncConfidentialAC 12/11/23Nikaitchuq Field – Oliktok Point PadAs Completed6/11/20122,358' MD, 2,097 ' TVD, 46º Inc - 4-½” x 1" KBMG GLM, 2,000 psi A to T shear valve 2,265 MD, 2,031 TVD - 3.81" X-nipple for possible injection valve8,680' MD - HAL Mirage Plug with Auto-fill valve 8,594' MD - 3.81" X-nipple VIT, 3 joints, 4-½” x 6", approx 100'OI24-08 Injector Monobore with Injection Control8,801' MD , 3,513' TVD– Bottom of entry guide8,666' MD - 3.725" XN 8,775' MD – Top of SLZXP Liner Hanger/Packer ItemMD (ft)ItemMD (ft)ICD #118405ICD #1013359ICD #217910ICD #1112822ICD #317533ICD #1211996ICD #416743ICD #1311579ICD #516244ICD #1411166ICD #615706ICD #1510258ICD #715170ICD #169922ICD #814424ICD #179411ICD #913891Item MD (ft)4-1/2" Swell Pkr #1 169784-1/2" Swell Pkr #2 147734-1/2" Swell Pkr #3 122674-1/2" Swell Pkr #4 107304-1/2" Swell Pkr #5 96844-½” Ecc-Nose Guide ShoeACX indicated possible leak at 1910.8' MD (12/08/2023) Well Name: OI24-08 OR Wellbore Name: OI24-08 Well Code: 26154 Job: RIGLESS WCEI Level: N/A Daily Report Date: 11/29/2023 Report #: 1 Page: 1 of 1 Well Header Permit/Concession N° ADL-388583 Operator ENI PETROLEUM Subsidiary ENI Petroleum Co. Inc. Initial Lahee Code WATER INJECTION WELL Rotary Table Elevation (ft) 53.15 Ground Level (ft) 12.20 First Flange (ft) 16.19 RKB - Base Flange (ft) 36.96 RKB - Tubing Spool (ft) Rig Information Rig Name Contractor Rig Type Rig Num Daily Information Weather Partly Cloudy Temperature (°F) 7.0 Wind W at 5 MPH Days LTI (days) 2,275.00 Days RI (days) POB 12.0 Daily Summary Operations 24h Forecast Install wire line valves and remaining pressure control equipment. Perform 3.79" gauge ring run on S-line to 2500' MD. Set slip stop catcher on S-line at 2500' MD. Remove shear out valve in GLM at 2358' and install dummy valve. Perform MIT on A-Annulus. 24h Summary Mobilize Equipment to location, Received well from Production group. Held lift meeting, pre job safety meeting, reviewed detail operating procedure for wire line rig up/rig down, performed EIP walk down. Spot in Halliburton equipment, LRS, and Worley crane. Lay out lubricator and rig up pressure control equipment. Function test hydraulic hoses to pressure control equipment. Operation at 07.00 Install wire line valve and function test. Time Log Start Time End Time Dur (hr) Cum Dur (hr)Phase Opr. Act. Plan Oper. Descr. 06:00 07:00 1.00 1.00 PROD- MAN A 2 P Mobilize Halliburton, LRS, and Worley crane crew to location.. 07:00 10:30 3.50 4.50 PROD- MAN R 1 P Received well from Production group. Held lift meeting with ENI HSE, Worley, LRS, Production Operator, and Halliburton. Pre job safety meeting with all personnel. Reviewed detail operating procedure for wire line rig up/rig down. Perform EIP walk down with Production Operator. Install lock on lock box. 10:30 20:00 9.50 14.00 PROD- MAN R 1 P Lay out containment and spot in equipment. Laid out lubricator. Installed secondary swab valve with night cap. Rig up pressure control equipment. ENI Company representative witnessed function test wire line valves and check hose alignment to pressure control equipment, good function test. Prepare 3.79" gauge ring BHA. 20:00 00:00 4.00 18.00 PROD- MAN R 1 P No operations at this time. Daily Contacts Position Contact Name Company Title Email Office Mobile Company Representative Paul Dillon ASRC Energy Services Co. Man Paul.Dillon@external.eni.com 907-670-6606 Safety Representative Jack Potter ASRC Energy Services HSE Jack.Potter@External.eni.com 970-685-1434 Last Casing Seat Cas. Type OD (in) ID (in) Grade Top (ftKB) Bottom (ftKB) TVD Bot. (ftKB) Landing Date LINER 4 1/2 L80 8,775.8 18,660.0 3,423.3 6/8/2012 Well Name: OI24-08 OR Wellbore Name: OI24-08 Well Code: 26154 Job: RIGLESS WCEI Level: N/A Daily Report Date: 11/30/2023 Report #: 2 Page: 1 of 1 Well Header Permit/Concession N° ADL-388583 Operator ENI PETROLEUM Subsidiary ENI Petroleum Co. Inc. Initial Lahee Code WATER INJECTION WELL Rotary Table Elevation (ft) 53.15 Ground Level (ft) 12.20 First Flange (ft) 16.19 RKB - Base Flange (ft) 36.96 RKB - Tubing Spool (ft) Rig Information Rig Name Contractor Rig Type Rig Num Daily Information Weather Partly Cloudy Temperature (°F) 14.0 Wind SW at 9 MPH Days LTI (days) 2,276.00 Days RI (days) POB 12.0 Daily Summary Operations 24h Forecast Install dummy valve in GLM #1 at 2358' MD. Perform MIT on A-Annulus. Retrieve 4-1/5" slip stop catcher at 2500' MD. Rig down Slick line. 24h Summary Remove night cap. Install wire line valves and function test. Run in hole with 3.79" gauge ring to 2550' SLM. Run in hole with 4.5" slip stop catcher to 2492' SLM. Run in hole with OK-6 kick over tool with 1.25" JDC pulling tool and locate GLM at 2336' SLM. Unable to latch shear out valve. Run in hole with 3.79" and 4.5" brush to 2336' SLM. Perform brush and flush to clean GLM at 2358' MD with 10 BBLs of LVT. Run in hole with OK-6 kick over tool with 1.25" JDC pulling tool and locate GLM at 2336' SLM. Retrieve shear out valve. Lay down lubricator. Secure well with night cap. Operation at 07.00 Run in hole with dummy valve on Slick line. Time Log Start Time End Time Dur (hr) Cum Dur (hr)Phase Opr. Act. Plan Oper. Descr. 00:00 06:00 6.00 6.00 PROD- MAN R 1 P No operations at this time. 06:00 07:00 1.00 7.00 PROD- MAN R 1 P Pre job safety meeting with crews. Obtain permit to work from operations and well pressures. SITP -6 PSI, A-Annulus 10 PSI, B-Annulus 180 PSI. 07:00 08:30 1.50 8.50 PROD- MAN R 5 P Remove night cap. Install wire line valves and function test. 08:30 10:00 1.50 10.00 PROD- MAN R 9 P Pre job safety meeting with crews. Starting pressure on A-Annulus 10 PSI, Tubing -6 PSI, B-Annulus 180 PSI. Filled A- Annulus with 6 BBLs of LVT before catching pressure. Estimated fluid level was at 107’. Continue pumping at lowest rate possible 0.1 BPM to 770 PSI. A-Annulus pressure was 695 PSI in 5 minutes, 633 PSI in 10 minutes, 560 PSI in 15 minutes, 516 PSI in 20 minutes, 463 PSI in 25 minutes, and 420 PSI after 30 minutes, total fluid pumped 7.4 BBLs. Increased A- Annulus pressure back to 770 PSI with 0.4 BBLs pumped before disengaging pump. Bleed off pressure with 1.8 BBLs back at surface.10:00 12:00 2.00 12.00 PROD- MAN R 12 P Pickup lubricator and stab onto well. Pressure test to 500 PSI low for 5 minutes and 2000 PSI for 10 minutes, good test. 12:00 17:30 5.50 17.50 PROD- MAN R 15 P S-line Run #1: 3.79" gauge ring, 1.875" long stroke spang jars, 1.75" oil jars and weight bars, Overall length 27.83', 211 LBS, Max OD 3.79". Run in hole with 3.79" gauge ring to 2550' SLM. Pull out of hole with S-line. S-line Run #2: 4.5" slip stop catcher, 1.875" long stroke spang jars, 1.75" oil jars and weight bars, Overall length 28.38', 245 LBS, Max OD 3.71". Run in hole with 4.5" slip stop catcher to 2492' SLM. Pull out of hole with S-line. S-line Run #3: OK-6 kick over tool with 1.25" JDC pulling tool, 1.875" long stroke spang jars, 1.75" oil jars and weight bars, Overall length 29.92', 220 LBS, Max OD 3.71". Run in hole with OK-6 kick over tool with 1.25" JDC pulling tool and locate GLM at 2336' SLM. Unable to latch shear out valve. Pull out of hole with S-line. Estimated fluid level in tubing 320'. 17:30 18:30 1.00 18.50 PROD- MAN R 15 P S-line Run #4: 3.79" gauge ring and 4.5" brush, 1.875" long stroke spang jars, 1.75" oil jars and weight bars, Overall length 29.83', 226 LBS, Max OD 3.79". Run in hole with 3.79" and 4.5" brush to 2336' SLM. Perform brush and flush to clean GLM at 2358' MD with 10 BBLs of LVT. 18:30 20:00 1.50 20.00 PROD- MAN R 15 P S-line Run #5: OK-6 kick over tool with 1.25" JDC pulling tool, 1.875" long stroke spang jars, 1.75" oil jars and weight bars, Overall length 29.92', 220 LBS, Max OD 3.71". Run in hole with OK-6 kick over tool with 1.25" JDC pulling tool and locate GLM at 2336' SLM. Retrieve shear out valve. Pull out of hole with S-line. 20:00 21:00 1.00 21.00 PROD- MAN R 5 P Lay down lubricator. Secure well with night cap. 21:00 00:00 3.00 24.00 PROD- MAN R 1 P No operations at this time. Daily Contacts Position Contact Name Company Title Email Office Mobile Company Representative Paul Dillon ASRC Energy Services Co. Man Paul.Dillon@external.eni.com 907-670-6606 Safety Representative Jack Potter ASRC Energy Services HSE Jack.Potter@External.eni.com 970-685-1434 Last Casing Seat Cas. Type OD (in) ID (in) Grade Top (ftKB) Bottom (ftKB) TVD Bot. (ftKB) Landing Date LINER 4 1/2 L80 8,775.8 18,660.0 3,423.3 6/8/2012 Well Name: OI24-08 OR Wellbore Name: OI24-08 Well Code: 26154 Job: RIGLESS WCEI Level: N/A Daily Report Date: 12/1/2023 Report #: 3 Page: 1 of 1 Well Header Permit/Concession N° ADL-388583 Operator ENI PETROLEUM Subsidiary ENI Petroleum Co. Inc. Initial Lahee Code WATER INJECTION WELL Rotary Table Elevation (ft) 53.15 Ground Level (ft) 12.20 First Flange (ft) 16.19 RKB - Base Flange (ft) 36.96 RKB - Tubing Spool (ft) Rig Information Rig Name Contractor Rig Type Rig Num Daily Information Weather Partly Cloudy Temperature (°F) 10.0 Wind NE at 3 MPH Days LTI (days) 2,277.00 Days RI (days) POB 12.0 Daily Summary Operations 24h Forecast Install dummy valve in GLM #1 at 2358' MD. Perform MIT on A-Annulus. Retrieve 4-1/5" slip stop catcher at 2500' MD. Rig down Slick line. 24h Summary Run in hole with OK-1 Kickover tool with dummy valve and set dummy valve in GLM at 2336' SLM. Perform MIT to on A-Annulus, dummy valve leaking. Run in hole with OK-6 kick over tool and retrieve dummy valve. Run in hole with OK-6 kick over tool with pocket brush to 2336' SLM. Perform brush and flush to clean GLM pocket at 2358' MD with 10 BBLs of LVT. Run in hole with OK-1 Kickover tool with dummy valve and set dummy valve in GLM at 2336' SLM. Pull out of hole with Slick line with dummy valve still attached. Lay down lubricator. Secure well with night cap. Operation at 07.00 Prepare to run in hole with dummy valve on Slick line. Time Log Start Time End Time Dur (hr) Cum Dur (hr)Phase Opr. Act. Plan Oper. Descr. 00:00 06:00 6.00 6.00 PROD- MAN R 1 P No operations at this time. 06:00 07:00 1.00 7.00 PROD- MAN R 1 P Pre job safety meeting with crews. Obtain permit to work from operations and well pressures. SITP -1 PSI, A-Annulus -10 PSI, B-Annulus 180 PSI. 07:00 07:30 0.50 7.50 PROD- MAN R 12 P Pickup lubricator and stab onto well. Pressure test to 500 PSI low for 5 minutes and 2000 PSI for 10 minutes, good test. 07:30 09:30 2.00 9.50 PROD- MAN R 15 P S-line Run #6: OK-1 Kickover tool with 1.25" JDC and dummy valve, 1.875" long stroke spang jars, 1.75" oil jars and weight bars, Overall length 26.46', 194 LBS, max OD 3.71". Run in hole with OK-1 Kickover tool with dummy valve and set dummy valve in GLM at 2336' SLM. Pull out of hole with Slick line. 09:30 12:00 2.50 12.00 PROD- MAN R 9 P Pre job safety meeting with crews. Perform MIT to on A-Annulus. Starting pressure on A-Annulus -10 PSI, Tubing -1 PSI, B- Annulus 180 PSI. Production filled A-Annulus with 6.17 BBLs of diesel. Estimated fluid level was at 107’. Swap lines to LRS. Start pumping down A-Annulus at 0.25 BPM with 0.7 PSI and 8.75 PSI SITP, increased pump rate to 0.5 BPM with 1.7 PSI and 13.2 PSI SITP, increased pump rate to 0.75 BPM with 6 PSI and 15.75 PSI SITP, increased pump rate to 1 BPM with 11 PSI and 20.6 PSI SITP, Dummy valve leaking. 12:00 15:00 3.00 15.00 PROD- MAN R 15 P S-line Run #7: OK-6 kick over tool with 1.25" JDC pulling tool, 1.875" long stroke spang jars, 1.75" oil jars and weight bars, Overall length 29.92', 220 LBS, Max OD 3.71". Run in hole with OK-6 kick over tool with 1.25" JDC pulling tool and locate GLM at 2336' SLM. Pull dummy valve and pull out of hole. Dummy valve had small amount of debris on it. 15:00 18:00 3.00 18.00 PROD- MAN R 15 P S-line Run #8: OK-6 kick over tool with pocket brush, 1.875" long stroke spang jars, 1.75" oil jars and weight bars, Overall length 29.96', 220 LBS, Max OD 3.71". Run in hole with OK-6 kick over tool with pocket brush to 2336' SLM. Perform brush and flush to clean GLM pocket at 2358' MD with 10 BBLs of LVT. Pull out of hole with Slick line. 18:00 20:00 2.00 20.00 PROD- MAN R 15 P S-line Run #9: OK-1 Kickover tool with 1.25" JDC and dummy valve, 1.875" long stroke spang jars, 1.75" oil jars and weight bars, Overall length 26.46', 194 LBS, max OD 3.71". Run in hole with OK-1 Kickover tool with dummy valve and set dummy valve in GLM at 2336' SLM. Apply 750 PSI on A-Annulus to confirm seal on dummy valve before releasing from tool, good test. Bleed A-Annulus down to 50 PSI and attempt to release from dummy valve. Pull out of hole with Slick line with dummy valve still attached. 20:00 22:00 2.00 22.00 PROD- MAN R 5 P Lay down lubricator. Secure well with night cap. 22:00 00:00 2.00 24.00 PROD- MAN R 1 P No operations at this time. Daily Contacts Position Contact Name Company Title Email Office Mobile Company Representative Paul Dillon ASRC Energy Services Co. Man Paul.Dillon@external.eni.com 907-670-6606 Safety Representative Jack Potter ASRC Energy Services HSE Jack.Potter@External.eni.com 970-685-1434 Last Casing Seat Cas. Type OD (in) ID (in) Grade Top (ftKB) Bottom (ftKB) TVD Bot. (ftKB) Landing Date LINER 4 1/2 L80 8,775.8 18,660.0 3,423.3 6/8/2012 Well Name: OI24-08 OR Wellbore Name: OI24-08 Well Code: 26154 Job: RIGLESS WCEI Level: N/A Daily Report Date: 12/2/2023 Report #: 4 Page: 1 of 1 Well Header Permit/Concession N° ADL-388583 Operator ENI PETROLEUM Subsidiary ENI Petroleum Co. Inc. Initial Lahee Code WATER INJECTION WELL Rotary Table Elevation (ft) 53.15 Ground Level (ft) 12.20 First Flange (ft) 16.19 RKB - Base Flange (ft) 36.96 RKB - Tubing Spool (ft) Rig Information Rig Name Contractor Rig Type Rig Num Daily Information Weather Partly Cloudy Temperature (°F) 16.0 Wind NE at 32 MPH Days LTI (days) 2,278.00 Days RI (days) POB 12.0 Daily Summary Operations 24h Forecast Install dummy valve in GLM #1 at 2358' MD. Perform MIT on A-Annulus. Retrieve 4-1/5" slip stop catcher at 2500' MD. Rig down Slick line. 24h Summary Remove 100' of Slick line wire and retie rope socket. LRS loaded pump truck with LVT and positioned truck in place. Preparing to pick up tool string. Suspend lifting operations due to high wind above 30 MPH. Operation at 07.00 Prepare to run in hole with dummy valve on Slick line. Time Log Start Time End Time Dur (hr) Cum Dur (hr)Phase Opr. Act. Plan Oper. Descr. 00:00 06:00 6.00 6.00 PROD- MAN R 1 P No operations at this time. 06:00 07:00 1.00 7.00 PROD- MAN R 1 P Pre job safety meeting with crews. Obtain permit to work from operations and well pressures. SITP -2.8 PSI, A-Annulus -11.4 PSI, B-Annulus 180 PSI. 07:00 09:00 2.00 9.00 PROD- MAN R 5 P Remove 100' of Slick line wire and retie rope socket. Add additional weight bar to OK-1 Kickover tool with 1.25" JDC and dummy valve tool string, LRS loaded pump truck with LVT and positioned truck in place. Preparing to pick up tool string. 09:00 18:00 9.00 18.00 PROD- MAN R 22 TW01 Suspend lifting operations due to high wind above 30 MPH. 18:00 00:00 6.00 24.00 PROD- MAN R 1 P No operations at this time. Daily Contacts Position Contact Name Company Title Email Office Mobile Company Representative Paul Dillon ASRC Energy Services Co. Man Paul.Dillon@external.eni.com 907-670-6606 Safety Representative Jack Potter ASRC Energy Services HSE Jack.Potter@External.eni.com 970-685-1434 Last Casing Seat Cas. Type OD (in) ID (in) Grade Top (ftKB) Bottom (ftKB) TVD Bot. (ftKB) Landing Date LINER 4 1/2 L80 8,775.8 18,660.0 3,423.3 6/8/2012 Well Name: OI24-08 OR Wellbore Name: OI24-08 Well Code: 26154 Job: RIGLESS WCEI Level: N/A Daily Report Date: 12/3/2023 Report #: 5 Page: 1 of 1 Well Header Permit/Concession N° ADL-388583 Operator ENI PETROLEUM Subsidiary ENI Petroleum Co. Inc. Initial Lahee Code WATER INJECTION WELL Rotary Table Elevation (ft) 53.15 Ground Level (ft) 12.20 First Flange (ft) 16.19 RKB - Base Flange (ft) 36.96 RKB - Tubing Spool (ft) Rig Information Rig Name Contractor Rig Type Rig Num Daily Information Weather Overcast Temperature (°F) 17.4 Wind NE at 12 MPH Days LTI (days) 2,279.00 Days RI (days) POB 12.0 Daily Summary Operations 24h Forecast Rig up E-line and pressure control equipment. Perform 3.79" gauge ring run on E-line to XN nipple at 8666' MD. 24h Summary Run in hole with OK-1 Kickover tool with dummy valve and set dummy valve in GLM at 2336' SLM. Pull out of hole with Slick line with dummy valve still attached. Run in hole with OK-1 Kickover tool with GA-2 and 1" bottom integral latch dummy valve. Set dummy valve in GLM at 2336' SLM. Perform MIT to on A-Annulus. Run in hole with GS pulling tool and attempt to latch 4.5" slip stop catcher at 2492' SLM. Run in hole with GR pulling tool and retrieve 4.5" slip stop catcher at 2492' SLM. Lay down lubricator. Secure well with night cap. Rig down Slick line. Operation at 07.00 Rig up E-line and pressure control equipment. Time Log Start Time End Time Dur (hr) Cum Dur (hr)Phase Opr. Act. Plan Oper. Descr. 00:00 06:00 6.00 6.00 PROD- MAN R 1 P No operations at this time. 06:00 07:00 1.00 7.00 PROD- MAN R 1 P Pre job safety meeting with crews. Obtain permit to work from operations and well pressures. SITP -4 PSI, A-Annulus -11 PSI, B-Annulus 180 PSI. 07:00 08:30 1.50 8.50 PROD- MAN R 12 P Pickup lubricator and stab onto well. Pressure test to 500 PSI low for 5 minutes and 2000 PSI for 10 minutes, good test. 08:30 12:30 4.00 12.50 PROD- MAN R 15 P S-line Run #10: OK-1 Kickover tool with 1.25" JDC and dummy valve, 1.875" long stroke spang jars, 1.75" oil jars and weight bars, Overall length 29.46', 221.6 LBS, max OD 3.71". Run in hole with OK-1 Kickover tool with dummy valve and set dummy valve in GLM at 2336' SLM. Apply 762 PSI on A-Annulus to confirm seal on dummy valve before releasing from tool, good test. Bleed A-Annulus down to 50 PSI and attempt to release from dummy valve. Pull out of hole with Slick line with dummy valve still attached. 12:30 15:30 3.00 15.50 PROD- MAN R 15 P S-line Run #11: OK-1 Kickover tool with GA-2 and 1" bottom integral latch dummy valve, 1.875" long stroke spang jars, 1.75" oil jars and weight bars, Overall length 29.46', 221.6 LBS, max OD 3.71". Run in hole with OK-1 Kickover tool with GA-2 and 1" bottom integral latch dummy valve. Set dummy valve in GLM at 2336' SLM. Pull out of hole with Slick line. Pumped 20 BBls of LVT down A-Annulus while RIH to flush mandrel pocket. 15:30 16:30 1.00 16.50 PROD- MAN R 9 P Pre job safety meeting with crews. Perform MIT to on A-Annulus. Starting pressure on A-Annulus 14.5 psi, Tubing 4.4 psi, B- Annulus 180 psi. Pumping down A-Annulus to 760 psi. Monitored pressure for 30 minutes. A-Annulus pressure was 685 psi in 5 minutes, 621 psi in 10 minutes, 560 psi in 15 minutes, 505 psi in 20 minutes, 453 psi in 25 minutes, and 404 psi after 30 minutes, total fluid pumped 1.6 bbls. Increased A-Annulus pressure back to 760 psi with 0.8 bbls pumped before disengaging pump. Bleed off pressure with 1.5 bbls back at surface. 16:30 19:00 2.50 19.00 PROD- MAN R 15 P S-line Run #12: GS pulling tool, 1.875" long stroke spang jars, 1.75" oil jars and weight bars, Overall length 25.63', 215 LBS, max OD 3.62". Run in hole with GS pulling tool and attempt to latch 4.5" slip stop catcher at 2492' SLM. Pull out of hole with Slick line. S-line Run #13: GR pulling tool, 1.875" long stroke spang jars, 1.75" oil jars and weight bars, Overall length 25.63', 215 LBS, max OD 3.62". Run in hole with GR pulling tool and retrieve 4.5" slip stop catcher at 2492' SLM. Pull out of hole with Slick line. 19:00 21:00 2.00 21.00 PROD- MAN R 5 P Lay down lubricator. Secure well with night cap. Rig down Slick line. 21:00 00:00 3.00 24.00 PROD- MAN R 1 P No operations at this time. Daily Contacts Position Contact Name Company Title Email Office Mobile Company Representative Paul Dillon ASRC Energy Services Co. Man Paul.Dillon@external.eni.com 907-670-6606 Safety Representative Jack Potter ASRC Energy Services HSE Jack.Potter@External.eni.com 970-685-1434 Last Casing Seat Cas. Type OD (in) ID (in) Grade Top (ftKB) Bottom (ftKB) TVD Bot. (ftKB) Landing Date LINER 4 1/2 L80 8,775.8 18,660.0 3,423.3 6/8/2012 Well Name: OI24-08 OR Wellbore Name: OI24-08 Well Code: 26154 Job: RIGLESS WCEI Level: N/A Daily Report Date: 12/4/2023 Report #: 6 Page: 1 of 1 Well Header Permit/Concession N° ADL-388583 Operator ENI PETROLEUM Subsidiary ENI Petroleum Co. Inc. Initial Lahee Code WATER INJECTION WELL Rotary Table Elevation (ft) 53.15 Ground Level (ft) 12.20 First Flange (ft) 16.19 RKB - Base Flange (ft) 36.96 RKB - Tubing Spool (ft) Rig Information Rig Name Contractor Rig Type Rig Num Daily Information Weather Overcast Temperature (°F) 6.6 Wind NE at 16 MPH Days LTI (days) 2,280.00 Days RI (days) POB 12.0 Daily Summary Operations 24h Forecast Perform 3.81" CAT standing valve run on E-line to XN nipple at 8666' MD. Perform combo MIT. 24h Summary Rig up E-line. Pickup lubricator and pressure test. Run in hole with 3.79" gauge ring and Welltec 318 tractor to XN-nipple at 8666' MD. Pickup and correlate to X-nipple at 8594' MD. Pull out of hole with E-line. Lay down lubricator. Remove 3.79" gauge ring and Welltec tractor. Secure well with night cap. Operation at 07.00 Prepare to run in hole with CAT standing valve on E-line. Time Log Start Time End Time Dur (hr) Cum Dur (hr)Phase Opr. Act. Plan Oper. Descr. 00:00 06:00 6.00 6.00 PROD- MAN R 1 P No operations at this time. 06:00 07:00 1.00 7.00 PROD- MAN R 1 P Pre job safety meeting with crews. Obtain permit to work from operations and well pressures. SITP -4 PSI, A-Annulus -11 PSI, B-Annulus 180 PSI. 07:00 14:00 7.00 14.00 PROD- MAN R 1 P Rig up E-line. Installed Jib on crane. Laid out lubricator and re-head rope socket through grease head. Rig up pressure control equipment. Function test wire line valves and check hose alignment to pressure control equipment, good function test. Prepare 3.79" gauge ring and Welltec 318 tractor for drift run on E-line. Function test Welltec tractor, good test. 14:00 15:00 1.00 15.00 PROD- MAN R 12 P Pickup lubricator and stab onto well. Pressure test to 500 PSI low for 5 minutes and 2000 PSI for 10 minutes, good test. 15:00 20:30 5.50 20.50 PROD- MAN R 15 P E-line Run #1; 3.79" gauge ring, and Welltec 318 tractor, BHA length 31.35', 431 LBS, Max OD 3.79", CCL offset 25.06'. Run in hole with 3.79" gauge ring, and Welltec 318 tractor, deviate out at 3,425'. Engage tractor and tractor in hole at 40-50 FPM to XN-nipple at 8666' MD. Pickup and correlate to X-nipple at 8594' MD. Pull out of hole with E-line. 20:30 22:00 1.50 22.00 PROD- MAN R 5 P Lay down lubricator. Remove 3.79" gauge ring and Welltec tractor. Secure well with night cap. 22:00 00:00 2.00 24.00 PROD- MAN R 1 P No operations at this time. Daily Contacts Position Contact Name Company Title Email Office Mobile Company Representative Paul Dillon ASRC Energy Services Co. Man Paul.Dillon@external.eni.com 907-670-6606 Safety Representative Jack Potter ASRC Energy Services HSE Jack.Potter@External.eni.com 970-685-1434 Last Casing Seat Cas. Type OD (in) ID (in) Grade Top (ftKB) Bottom (ftKB) TVD Bot. (ftKB) Landing Date LINER 4 1/2 L80 8,775.8 18,660.0 3,423.3 6/8/2012 Well Name: OI24-08 OR Wellbore Name: OI24-08 Well Code: 26154 Job: RIGLESS WCEI Level: N/A Daily Report Date: 12/5/2023 Report #: 7 Page: 1 of 1 Well Header Permit/Concession N° ADL-388583 Operator ENI PETROLEUM Subsidiary ENI Petroleum Co. Inc. Initial Lahee Code WATER INJECTION WELL Rotary Table Elevation (ft) 53.15 Ground Level (ft) 12.20 First Flange (ft) 16.19 RKB - Base Flange (ft) 36.96 RKB - Tubing Spool (ft) Rig Information Rig Name Contractor Rig Type Rig Num Daily Information Weather Haze Temperature (°F) 7.5 Wind SW at 12 MPH Days LTI (days) 2,281.00 Days RI (days) POB 13.0 Daily Summary Operations 24h Forecast Perform 40 arm caliper run on E-line to XN nipple at 8666' MD and log to surface. 24h Summary Make up 3.81" CAT standing valve, Welltec 312 stroker, and Welltec 318 tractor for run on E-line. Pickup lubricator and pressure test. Run in hole with 3.81" CAT standing valve, Welltec 312 stroker, and Welltec 318 tractor to XN-nipple at 8666' MD. Perform Combo MIT. Pull out of hole with E-line. Lay down lubricator. Remove 3.81" CAT standing valve, Welltec 312 stroker, and Welltec 318 tractor. Secure well with night cap. Operation at 07.00 No operations at this time. Time Log Start Time End Time Dur (hr) Cum Dur (hr)Phase Opr. Act. Plan Oper. Descr. 00:00 06:00 6.00 6.00 PROD- MAN R 1 P No operations at this time. 06:00 07:00 1.00 7.00 PROD- MAN R 1 P Pre job safety meeting with crews. Obtain permit to work from operations and well pressures. SITP -5 PSI, A-Annulus -13 PSI, B-Annulus 180 PSI. 07:00 09:00 2.00 9.00 PROD- MAN R 5 P Make up 3.81" CAT standing valve, Welltec 312 stroker, and Welltec 318 tractor for run on E-line. Function test Welltec tractor and Welltec 312 stroker, good test. 09:00 10:00 1.00 10.00 PROD- MAN R 12 P Pickup lubricator and stab onto well. Pressure test to 500 PSI low for 5 minutes and 2000 PSI for 10 minutes with 60° LVT, good test. 10:00 17:00 7.00 17.00 PROD- MAN R 15 P E-line Run #2; 3.81" CAT standing valve with GR pulling tool, Welltec 312 stroker, and Welltec 318 tractor, BHA length 62.65', 1444 LBS, Max OD 3.75", CCL offset 55.7'. Run in hole with 3.81" CAT standing valve, Welltec 312 stroker, and Welltec 318 tractor, deviate out at 3,405'. Engage tractor and tractor in hole at 40-50 FPM to XN-nipple at 8666' MD. Pickup and correlate to X-nipple at 8594' MD. Engaged stroker and seat CAT standing valve in XN-nipple at 8666' MD with 5K force, 131 MM (5.1") travel to seat. Note: Set down at 3816', 3855', 3978', 4264', 4303', 4463', 4580', 4661', 4947', 5069', 5110', 5141', 5269', 5390' 5593', 6961', 7691', and 7815' WLM running in hole. Worked tractor to pass. Max line tension 2500 LBS pickup. 17:00 20:30 3.50 20.50 PROD- MAN R 9 P Pre job safety meeting. LRS rigged up to pump down tubing for MIT. Start pressures; SITP -0.5 PSI, A-Annulus -13 PSI, B- Annulus 180 PSI. Engage pump at 1/4 BPM and pressure up tubing to 1633 PSI with 7.1 BBLs LVT pumped, A-Annulus - 13.07 PSI. B- Annulus 180 PSI. After 15 minutes tubing 586 PSI, A-Annulus -12.7 PSI, B-Annulus 180 PSI. After 30 minutes tubing 198 PSI, A-Annulus -12.6 PSI, B-Annulus 180 PSI. Bleed off pressure, 1.8 BBLs back. Perform Combo MIT. Start pressures; SITP -1.07 PSI, A-Annulus -12.39 PSI, B-Annulus 180 PSI. Engage pump at 1/4 BPM and pressure up A-Annulus to 1648 PSI with 12.1 BBLs LVT pumped ( 5.1 BBLs to fill A-Annulus), SITP 1647 PSI. B- Annulus 260 PSI. After 15 minutes SITP 1618 PSI, A-Annulus 1619 PSI, B-Annulus 210 PSI. After 30 minutes SITP 1607 PSI, A-Annulus 1607 PSI, B-Annulus 200 PSI. Bleed off pressure, 5.7 BBLs back. 29 PSI loss in first 15 MIN, 12 PSI loss in second 15 MIN, good test. 20:30 23:00 2.50 23.00 PROD- MAN R 15 P Unseat CAT standing valve with Welltec 318 stroker. Pull out of hole with E-line. 23:00 00:00 1.00 24.00 PROD- MAN R 5 P Lay down lubricator. Remove 3.81" CAT standing valve with GR pulling tool, Welltec 312 stroker, and Welltec 318 tractor. Secure well with night cap. Daily Contacts Position Contact Name Company Title Email Office Mobile Company Representative Paul Dillon ASRC Energy Services Co. Man Paul.Dillon@external.eni.com 907-670-6606 Safety Representative Jack Potter ASRC Energy Services HSE Jack.Potter@External.eni.com 970-685-1434 Last Casing Seat Cas. Type OD (in) ID (in) Grade Top (ftKB) Bottom (ftKB) TVD Bot. (ftKB) Landing Date LINER 4 1/2 L80 8,775.8 18,660.0 3,423.3 6/8/2012 Well Name: OI24-08 OR Wellbore Name: OI24-08 Well Code: 26154 Job: RIGLESS WCEI Level: N/A Daily Report Date: 12/6/2023 Report #: 8 Page: 1 of 1 Well Header Permit/Concession N° ADL-388583 Operator ENI PETROLEUM Subsidiary ENI Petroleum Co. Inc. Initial Lahee Code WATER INJECTION WELL Rotary Table Elevation (ft) 53.15 Ground Level (ft) 12.20 First Flange (ft) 16.19 RKB - Base Flange (ft) 36.96 RKB - Tubing Spool (ft) Rig Information Rig Name Contractor Rig Type Rig Num Daily Information Weather Frost Temperature (°F) -8.0 Wind SE at 8 MPH Days LTI (days) 2,282.00 Days RI (days) POB 13.0 Daily Summary Operations 24h Forecast Lay down lubricator. Remove 40 arm caliper logging tools, and Welltec 218 tractor. Secure well with night cap. Perform ACX run on E-line to XN nipple at 8666' MD and log to surface. 24h Summary Make up 40 arm caliper logging tools, and Welltec 218 tractor for run on E-line. Pickup lubricator and pressure test. Run in hole with 40 arm caliper and Welltec 218 tractor to XN-nipple at 8666' MD. Pull out of hole performing 40 arm caliper log from 8666' MD to 6203' MD. Wire Line was not spooling correctly on drum. Run in hole with 40 arm caliper and Welltec 218 tractor to XN-nipple at 8666' MD. Pull out of hole performing 40 arm caliper log from 8666' MD to surface. Operation at 07.00 No operations at this time. Time Log Start Time End Time Dur (hr) Cum Dur (hr)Phase Opr. Act. Plan Oper. Descr. 00:00 08:30 8.50 8.50 PROD- MAN R 1 P No operations at this time. 08:30 09:30 1.00 9.50 PROD- MAN R 1 P Pre job safety meeting with crews. Obtain permit to work from operations and well pressures. SITP -8 PSI, A-Annulus -13 PSI, B-Annulus 180 PSI. 09:30 13:30 4.00 13.50 PROD- MAN R 5 P Make up 40 arm caliper logging tools, and Welltec 218 tractor for run on E-line. Function test Welltec tractor and logging tools, good test. 13:30 14:30 1.00 14.50 PROD- MAN R 12 P Pickup lubricator and stab onto well. Pressure test to 500 PSI low for 5 minutes and 2000 PSI for 10 minutes with 60° LVT, good test. 14:30 19:30 5.00 19.50 PROD- MAN R 15 P E-line Run #3; 40 arm caliper and Welltec 218 tractor, BHA length 47.93', 404 LBS, Max OD 2.75", CCL offset 20.3'. Run in hole with 40 arm caliper and Welltec 218 tractor, deviate out at 3,589'. Engage tractor and tractor in hole at 60 FPM to XN- nipple at 8666' MD. Pickup and correlate to X-nipple at 8594' MD. Pull out of hole performing 40 arm caliper log from 8666' MD to 6203' MD. Wire Line was not spooling correctly on drum. 19:30 22:30 3.00 22.50 PROD- MAN R 15 TD04 Engage tractor and tractor in hole to 8500'. Respot logging unit to align better with well. Engage tractor and tractor in hole at 60 FPM to XN-nipple at 8666' MD. Pickup and correlate to X-nipple at 8594' MD. Pull out of hole performing 40 arm caliper log from 8666' MD to 6203' MD. 22:30 00:00 1.50 24.00 PROD- MAN R 15 P Pull out of hole performing 40 arm caliper log from 6203' MD to surface. Daily Contacts Position Contact Name Company Title Email Office Mobile Company Representative Paul Dillon ASRC Energy Services Co. Man Paul.Dillon@external.eni.com 907-670-6606 Safety Representative Jack Potter ASRC Energy Services HSE Jack.Potter@External.eni.com 970-685-1434 Last Casing Seat Cas. Type OD (in) ID (in) Grade Top (ftKB) Bottom (ftKB) TVD Bot. (ftKB) Landing Date LINER 4 1/2 L80 8,775.8 18,660.0 3,423.3 6/8/2012 Well Name: OI24-08 OR Wellbore Name: OI24-08 Well Code: 26154 Job: RIGLESS WCEI Level: N/A Daily Report Date: 12/7/2023 Report #: 9 Page: 1 of 1 Well Header Permit/Concession N° ADL-388583 Operator ENI PETROLEUM Subsidiary ENI Petroleum Co. Inc. Initial Lahee Code WATER INJECTION WELL Rotary Table Elevation (ft) 53.15 Ground Level (ft) 12.20 First Flange (ft) 16.19 RKB - Base Flange (ft) 36.96 RKB - Tubing Spool (ft) Rig Information Rig Name Contractor Rig Type Rig Num Daily Information Weather Clear Temperature (°F) 2.7 Wind E at 8 MPH Days LTI (days) 2,283.00 Days RI (days) POB 15.0 Daily Summary Operations 24h Forecast Continue ACX log to surface on E-line. Lay down lubricator. Remove ACX logging tools and Welltec 218 tractor. Rig down pressure control equipment and secondary swab valve. Install tree cap and secure well. Rig down wire line equipment, crane, and Welltec. Prepare to hand well over to Production group. 24h Summary Lay down lubricator. Remove 40 arm caliper logging tools and Welltec 218 tractor. Secure well with night cap. Make up ACX logging tools, and Welltec 218 tractor for run on E-line. Pickup lubricator and pressure test. Run in hole with ACX logging tool and Welltec 218 tractor to XN-nipple at 8666' MD. Pull out of hole performing ACX log from 8666' MD to 8000' MD. Making stationary stops to investigate possible leak. No operations at this time. Monitor well with crane operator and Halliburton. Operation at 07.00 No operations at this time. Time Log Start Time End Time Dur (hr) Cum Dur (hr)Phase Opr. Act. Plan Oper. Descr. 00:00 02:00 2.00 2.00 PROD- MAN R 5 P Lay down lubricator. Remove 40 arm caliper and Welltec 218 tractor. Secure well with night cap. 02:00 10:00 8.00 10.00 PROD- MAN R 1 P No operations at this time. 10:00 11:00 1.00 11.00 PROD- MAN R 1 P Pre job safety meeting with crews. Obtain permit to work from operations and well pressures. SITP -1.8 PSI, A-Annulus -13.2 PSI, B-Annulus 180 PSI. 11:00 13:00 2.00 13.00 PROD- MAN R 5 P Make up ACX logging tools, and Welltec 218 tractor for run on E-line. Function test Welltec tractor and logging tools, good test. 13:00 14:00 1.00 14.00 PROD- MAN R 12 P Pickup lubricator and stab onto well. Pressure test to 500 PSI low for 5 minutes and 2000 PSI for 10 minutes with 60° LVT, good test. 14:00 17:00 3.00 17.00 PROD- MAN R 15 P E-line Run #4; ACX and Welltec 218 tractor, BHA length 63.03', 460 LBS, Max OD 2.36", CCL #1 offset 34', CCL #2 offset 5.34. Run in hole with ACX logging tool and Welltec 218 tractor, deviate out at 3621'. Engage tractor and tractor in hole at 60 FPM to XN-nipple at 8666' MD. Pickup and correlate to X-nipple at 8594' MD. 17:00 22:00 5.00 22.00 PROD- MAN R 15 P Pre job safety meeting with crews for pumping while logging operations. SITP -1.8 PSI, A-Annulus -13.2 PSI, B-Annulus 180 PSI. Apply pressure on A-Annulus maintaining 500 PSI to 750 PSI above tubing PSI while performing ACX log. Pull out of hole performing ACX log from 8666' MD to 8000' MD. Making stationary stops to investigate possible leak. 22:00 00:00 2.00 24.00 PROD- MAN R 1 P No operations at this time. Monitor well with crane operator and Halliburton. Daily Contacts Position Contact Name Company Title Email Office Mobile Company Representative Paul Dillon ASRC Energy Services Co. Man Paul.Dillon@external.eni.com 907-670-6606 Safety Representative Jack Potter ASRC Energy Services HSE Jack.Potter@External.eni.com 970-685-1434 Last Casing Seat Cas. Type OD (in) ID (in) Grade Top (ftKB) Bottom (ftKB) TVD Bot. (ftKB) Landing Date LINER 4 1/2 L80 8,775.8 18,660.0 3,423.3 6/8/2012 Well Name: OI24-08 OR Wellbore Name: OI24-08 Well Code: 26154 Job: RIGLESS WCEI Level: N/A Daily Report Date: 12/8/2023 Report #: 10 Page: 1 of 1 Well Header Permit/Concession N° ADL-388583 Operator ENI PETROLEUM Subsidiary ENI Petroleum Co. Inc. Initial Lahee Code WATER INJECTION WELL Rotary Table Elevation (ft) 53.15 Ground Level (ft) 12.20 First Flange (ft) 16.19 RKB - Base Flange (ft) 36.96 RKB - Tubing Spool (ft) Rig Information Rig Name Contractor Rig Type Rig Num Daily Information Weather Clear Temperature (°F) 5.7 Wind N at 10 MPH Days LTI (days) 2,284.00 Days RI (days) POB 15.0 Daily Summary Operations 24h Forecast Rig down wire line equipment and crane. Hand well over to Production group. 24h Summary Pull out of hole performing ACX log from 8000' MD to surface. Made stationary stops to investigate possible leak. Lay down lubricator. Remove ACX logging tools and Welltec 218 tractor. Retrieve data from logging tool. Rig down lubricator, wire line valves, and secondary swab valve. Install tree cap. Secure well. Operation at 07.00 Rig down wire line equipment and crane. Time Log Start Time End Time Dur (hr) Cum Dur (hr)Phase Opr. Act. Plan Oper. Descr. 00:00 07:00 7.00 7.00 PROD- MAN R 1 P No operations at this time. Monitor well with crane operator and Halliburton. 07:00 08:00 1.00 8.00 PROD- MAN R 1 P Pre job safety meeting with crews. Obtain permit to work from operations and well pressures. SITP -0.5 PSI, A-Annulus -13 PSI, B-Annulus 180 PSI. 08:00 16:30 8.50 16.50 PROD- MAN R 15 P Pre job safety meeting with crews for pumping while logging operations. SITP -0.5 PSI, A-Annulus -13 PSI, B-Annulus 180 PSI. Apply pressure on A-Annulus maintaining 750 PSI to 1000 PSI above tubing PSI while performing ACX log. Pull out of hole performing ACX log from 8000' MD to surface. Made stationary stops to investigate possible leak at 8656', 8602', 8480', 7856', 6497', 2366', 2273', 1923', and 1916' MD. Total 26.13 BBLs injected in A-Annulus while performing ACX log at average loss rate of 2.09 BBL/HR. 16:30 20:30 4.00 20.50 PROD- MAN R 5 P Lay down lubricator. Remove ACX logging tools and Welltec 218 tractor. Retrieve data from logging tool. 20:30 22:00 1.50 22.00 PROD- MAN R 5 P Rig down lubricator, wire line valves, and secondary swab valve. Install tree cap. Secure well. 22:00 00:00 2.00 24.00 PROD- MAN R 1 P No operations at this time. Daily Contacts Position Contact Name Company Title Email Office Mobile Company Representative Paul Dillon ASRC Energy Services Co. Man Paul.Dillon@external.eni.com 907-670-6606 Safety Representative Jack Potter ASRC Energy Services HSE Jack.Potter@External.eni.com 970-685-1434 Last Casing Seat Cas. Type OD (in) ID (in) Grade Top (ftKB) Bottom (ftKB) TVD Bot. (ftKB) Landing Date LINER 4 1/2 L80 8,775.8 18,660.0 3,423.3 6/8/2012 Well Name: OI24-08 OR Wellbore Name: OI24-08 Well Code: 26154 Job: RIGLESS WCEI Level: N/A Daily Report Date: 12/9/2023 Report #: 11 Page: 1 of 1 Well Header Permit/Concession N° ADL-388583 Operator ENI PETROLEUM Subsidiary ENI Petroleum Co. Inc. Initial Lahee Code WATER INJECTION WELL Rotary Table Elevation (ft) 53.15 Ground Level (ft) 12.20 First Flange (ft) 16.19 RKB - Base Flange (ft) 36.96 RKB - Tubing Spool (ft) Rig Information Rig Name Contractor Rig Type Rig Num Daily Information Weather Partly Cloudy Temperature (°F) -2.0 Wind NW at 5 MPH Days LTI (days) 2,285.00 Days RI (days) POB 15.0 Daily Summary Operations 24h Forecast No further operations. 24h Summary Rig down wire line equipment and crane. Prepare to hand well over to Production group. Operation at 07.00 No further operations. Time Log Start Time End Time Dur (hr) Cum Dur (hr)Phase Opr. Act. Plan Oper. Descr. 00:00 06:00 6.00 6.00 PROD- MAN R 1 P No operations at this time. 06:00 07:00 1.00 7.00 PROD- MAN R 1 P Pre job safety meeting with crews. Obtain permit to work from operations and well pressures. 07:00 12:00 5.00 12.00 PROD- MAN R 5 P Rig down crane and Halliburton wire line equipment. Cleaned up work area. Perform walk down with Production and removed lock from EIP. Prepare to hand well over to Production group. Final report. No further operations. Daily Contacts Position Contact Name Company Title Email Office Mobile Company Representative Paul Dillon ASRC Energy Services Co. Man Paul.Dillon@external.eni.com 907-670-6606 Safety Representative Jack Potter ASRC Energy Services HSE Jack.Potter@External.eni.com 970-685-1434 Last Casing Seat Cas. Type OD (in) ID (in) Grade Top (ftKB) Bottom (ftKB) TVD Bot. (ftKB) Landing Date LINER 4 1/2 L80 8,775.8 18,660.0 3,423.3 6/8/2012 1. Type of Request: Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown Suspend Perforate Other Stimulate Pull Tubing Change Approved Program Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing Other: Rigless Diagnostic_____ 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?N/A Yes No OI24-08 9. Property Designation (Lease Number): 10. Field: Nikaitchuq Schrader Bluff Schrader Bluff 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: Junk (MD): 18,670 18660 3429 948 N/A N/A Casing Collapse Structural Conductor Surface 2480 Intermediate 4790 Production Liner ICD's 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: Alex Vaughan Contact Email: alex.vaughan@external.eni.com Contact Phone:907-865-3323 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 Length Size Well Operations Project Manager Subsequent Form Required: Suspension Expiration Date: Will perfs require a spacing exception due to property boundaries? Current Pools: MPSP (psi): Plugs (MD): 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name and Digital Signature with Date: Giorgio Iannucci November 21, 2023 3700 Centerpoint Dr. Ste 500, Anchorage, AK, 99503 50-029-23457-00-00 ENI US Operating Co. Inc. AOGCC USE ONLY ICD's Tubing Grade: 3429 TVD Burst STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL 355024, 373301, 391283 211-130 Tubing Size: 160 2135 Proposed Pools: PRESENT WELL CONDITION SUMMARY Tubing MD (ft): MD 6890 5210 3516 160 2413 20 13.375 160 9.6258993 2413 8993 8993-18660 4.5 3516-3429 Perforation Depth TVD (ft): 28-Nov-23 186608775 4.5 3429 HES PHL Perforation Depth MD (ft): L-80 8647/3498 8801 m n P s 2 6 5 6 t _ c N Form 10-403 Revised 06/2023 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov the procedure approved 323-634 By Grace Christianson at 8:22 am, Nov 22, 2023 10-404 X X A.Dewhurst 22NOV23 DSR-11/22/23 NIKAITCHUQ VTL 11/27/2023*&:JLC 11/28/2023 Brett W. Huber, Sr. Digitally signed by Brett W. Huber, Sr. Date: 2023.11.28 13:29:53 -09'00'11/28/23 RBDMS 113023 JSB 3700 Centerpoint Drive Suite 500 Anchorage, Alaska 99503 Giorgio Iannucci Phone (907) 865-3320 Email: Giorgio.iannucci@eni.com November 21st, 2023 Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Application for Sundry Approval for OI24-08 Rigless Intervention: Slickline/E-line Tubing Leak Diagnostics and Contingency Patch Installation Commissioners, ENI US Operating Co. Inc. hereby applies for a Sundry for well OI24-08. OI24-08 was drilled and completed on Spy Island June 2012 with an injection completion set at a depth of 8,801’ MD. Tubing to inner annulus hydraulic communication is suspected. The well is currently shut in awaiting intervention to diagnose communication. A slickline/E-Line intervention is planned to diagnose tubing to inner annulus communication and install tubing patch if required. This work scope has an estimated date for beginning work November 28th, 2023. Please find attached for review commission form 10-403 and supporting documentation. Questions or requests for supplemental information can be directed to: Alex Vaughan, 907-865-3323. Sincerely, Giorgio Iannucci Well Operations Project Manager cerely, orgio Iannucci OI24-08 Intervention – Proposal Summary and Wellbore Schematic OI24-08 Slickline/E-line Tubing Leak Diagnostics and Contingency Patch Installation PTD#:211-130 Status Well OI24-08 is currently shut in waiting for diagnostic work. Scope of Work Eni is planning to perform a rig less intervention on OI24-08 to investigate a potential tubing to annulus hydraulic communication in preparation to define the leak point in the tubing and patch accordingly. General Well Info Reservoir Pressure/TVD: Maximum initial shut-in pressure of approximately 948 psi based on a 1,300 psi BHP (3,516’ TVD) Wellhead type/pressure rating: Vault, MB-247/5000 psi Well type: Injector Estimated start date: November 28, 2023 Intervention Unit: Slickline / Eline Sr. Drilling Engineer: Alex Vaughan alex.vaughan@external.eni.com Work: 907-865-3323 Well Operations Project Manager: Giorgio Iannucci giorgio.iannucci@eni.com Work: 907-865-3320 Procedure Summary 1. Rig up slickline unit over OI24-08. 2. Confirm suspected hydraulic communication between inner annulus and tubing. 3. Establish inner annulus to tubing hydraulic leak rate. 4. Drift to the XN nipple at 8666’ MD. 5. Perform leak detection diagnostics to generally locate hydraulic communication via slickline conveyed tools between the packer and surface. 6. Set tubing plug in XN nipple at 8666’ MD and perform combo (inner annulus and tubing) pressure test 7. Rig down slickline unit. 8. Rig up eline unit. 9. Repeat leak detection diagnostics to precisely locate hydraulic communication via eline conveyed tools across the general interval range identified during previous slickline operations. a. This will include a multi-finger caliper and acoustic leak detection tool. 10. Contingency: Set the TBG patch at the definitive leak point. a. Off critical path and “cure” the patch as per product procedure by bringing on the well at standard injection rates and temperatures for 24 hours. 11. Rig down eline unit 12. Once patch is cured, perform MITIA to 1650 psi to confirm successful patch installation. Current Completion Schematic Vetco Gray, MB-247/5000 psi 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: OI24-08 (PTD# 211-130) TxIA Communication Date:Monday, November 20, 2023 9:17:41 AM Attachments:image002.png image001.png From: Lopez Keith <Keith.Lopez@eni.com> Sent: Friday, November 17, 2023 8:58 AM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov>; Regg, James B (OGC) <jim.regg@alaska.gov> Cc: Giraud Hector <Hector.Giraud@eni.com>; Lyden Dan <Dan.Lyden@eni.com>; Dexheimer Stephen <Stephen.Dexheimer@eni.com>; Morgan Michael <Mike.Morgan@eni.com>; Zuber Joshua <Joshua.Zuber@eni.com>; Burgess Larry <Larry.Burgess@eni.com>; Pitzalis Francesco <Francesco.Pitzalis@eni.com>; Brown Timothy <Timothy.Brown@eni.com>; Vaughan Alex <Alex.Vaughan@external.eni.com>; Gueco Chad <Chad.Gueco@external.eni.com>; Iannucci Giorgio <Giorgio.Iannucci@eni.com>; Zuber Joshua <Joshua.Zuber@eni.com>; Lopez Keith <Keith.Lopez@eni.com> Subject: OI24-08 (PTD# 211-130) TxIA Communication Mr. Wallace, Yesterday morning (11-16-23), ENI noticed a concern with tubing by inner annulus communication on OI24-08. The pressure began increasing at a very slow but steady ~10 psi/hr. The IA pressure was bled off and it continued this slow but steady build. The injector was shut in and will remain shut in until further diagnostics can be conducted with slickline/eline. OI24-08 passed its last state witnessed MIT on 03/23/21. Please let me know of any concerns or further data the AOGCC requires. 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 Keith.Lopez@eni.com ------------------------------------------------------------------------------------------------------------------------------------------------------------------------ Message for the recipient only, if received in error, please notify the sender and read http://www.eni.com/disclaimer/ MEMORANDUM To: Jim Regg ' `n 4""� Zc2i • . MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission To Jim Regg DATE: Wednesday,December 28,2016 P.I.Supervisor �e C I Z--1 Z kr" SUBJECT: Mechanical Integrity Tests ENI US OPERATING CO INC 0124-08 FROM: Jeff Jones NIKAITCHUQ 0I24-08 Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry 'ya--- NON-CONFIDENTIAL Comm Well Name NIKAITCHUQ 0124-08 API Well Number 50-029-23457-00-00 Inspector Name: Jeff Jones Permit Number: 211-130-0 Inspection Date: 12/9/2016 Insp Num: mitJJ161212131655 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min WellT 0124-08 , Type InjJ W 'TVD 3498 f Tubing 449 449 448 - 449 PTD 2111300 Type Test SPT'Test psi 1500 - IA 488 1673 - 1660 - 1655 Interval rYRTST P/F I P OA 200 220 - 220 . 220 . Notes: 1.5 barrels diesel pumped. 1 well inspected,no exceptions noted. SCANNED APR 0 5 201?. Wednesday,December 28,2016 Page 1 of 1 Image Project Well History File Cover Page XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable direct inspection of the file. b . 1 L - 13© Well History ile Identifier Organizing (done) Two-sided ❑ Rescan Needed RES N: OVERSIZED: NOTES: Color tems: ❑ Maps: rayscale Items: ogs: ❑ Poor Quality Originals: ❑ Other: ❑ Other: BY: derilbDate: VD%g— i i' /s/ title Project Proofing BY: Maria Date: Vaallif /s/ rill° 1 Scanning Preparation � x 30 = I UO + V = TOTAL PAGES I QQ BY: aft Date: glaoli 1./.. (Count does not include cover sheet) /s/ Production Scanning r Stage 1 Page Count from Scanned File: 1 S 7 (Count does include cover sheet) Page Count Matches Number in Scanning PrefILf ration: ES NO BY: Maria Date: gig, D— isi ill t Stage 1 If NO in stage 1, page(s) discrepancies were found: YES NO BY: Maria Date: /s/ Stage 2 Additional Well Reports: YES NO TOTAL PAGES: Digital version appended by: Meredith Michal Date: /s/ Final Page Count: Stage 1 + Stage 2: TOTAL PAGES: Scanning is complete at this point unless rescanning is required. ReScanned BY: Maria Date: /s/ Comments about this file: Quality Checked 7/8/2014 Well History File Cover Page_20140708.doc c c w C U o O O O o co U = h (0 J + co J J J + U o. 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LL 0 2 O z a. g U w W 0 cnw C.) z W z Z w t6 N - °' a to Cl. ° M c C r g C O y N a E U = U T Q I"" 9 N mr C O N C O CCI a 0 I M x• a) its Cn 1— Qz o H AQ C n z E 0 E U coz m 3 m N NI- el M M m r N d • d Q ii w o ICO a STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION 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 Developmeny N Exploratory ❑ GINJ ❑ WINJ 7. WAG ❑ WDSPL❑ No.of Completions: Service Stratigraphic Test ❑ 2.Operator Name: 5.Date Comp.,Susp.,or 12.Permit to Drill Number: ENI US Operating Co.Inc. Aband.: 6/11/2012• 211-130• 3.Address: 6.Date Spudded: 13.API Number: 3800 Centerpoint Drive,Ste.300,Anchorage,AK 99503 5/8/2012. 50-029-23457-00-00 • 4a.Location of Well(Governmental Section): 7.Date TD Reached: 14.Well Name and Number: Surface: 3126.4 FSL 1710.5 FEL S5 T13N R9E UM 6/1/2012 0124-08 Top of Productive Horizon: 8.KB(ft above MSL): 53.2 • 15.Field/Pool(s): 291 FSL 3064 FEL 31 T14N R9E UM GL(ft above MSL): 12.2 . Total Depth: 9.Plug Back Depth(MD+TVD): Nikaitchuq/Schrader Bluff Oil Pool- 1102 FSL 5263 FEL 25 T14N R8E UM N/A 4b.Location of Well(State Base Plane Coordinates,NAD 27): 10.Total Depth(MD+ND): 16.Property Designation: Surface: x- 516569.84 y- 6036479.38 ' Zone- 4 •18,670'MD/3,429'ND• ADL 355024,373301,391283 TPI: x- 509924.03 y- 6038911.78 Zone- 4 11.SSSV Depth(MD+ND): 17.Land Use Permit: Total Depth: x- 502575.53 y- 6044996.09 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) 1,921'MD/1,780'ND• 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 ND 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 2413 35 2135 16 10.7 ppg ASL: 417 bbls N/A 12.5 pm LiteCRETE:68 bbls 9.625 40 L-80 33 8993 33 3516 12.25 12.5 ppg LiteCRETE:212 bbls N/A 4.5 11.6 L-80 8775 18660 3510 3429 8.75 Blank Liner with ICD's N/A 24.Open to production or injection? Yes No 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) 4.5 8801 8,647'MD/3,498'ND .............�_...I,.,.,•. ACID r G(hS1PLETC i j 26. FRACTURE,CEMENT SQUEEZE,ETC. a1 �i P. DEPTH INTERVAL(MD) AMOUNT AND KIND OF MATERIAL USED 1.0'47-14.40i1 . , 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❑Q Sidewall Cores Acquired? Yes ❑ No 2 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 JUL 18 2012 9 G ,6fAv Form 10-407 Revised 12/2009 CONTINUED ON REVERSE ,Z � .c,..1 3 Submit original only A.�\ STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1a.Well Status: Oil❑ Gas ❑ SPLUG ❑ Other ❑ Abandoned ❑ Suspended 1b.Well Class: 20AAC 25.105 20AAC 25.110 Development Q Exploratory ❑ GINJ ❑ WINJ E WAG ❑ WDSPL❑ No.of Completions: a hi Service ❑ Stratigraphic Test❑ 2.Operator Name: 5.Date Comp.,Sus,or 12.Permit to Drill Number: ENI US Operating Co.Inc. Aband.: 6/�S4.2012 211-130 3.Address: 6.Date Spudded: 13.API Number: 3800 Centerpoint Drive,Ste.300,Anchorage,AK 99503 5/8/2012 50-029-23457-00-00 4a.Location of Well(Governmental Section): 7.Date TD Reached: 14.Well Name and Number: Surface: 3126.4 FSL 1710.5 FEL S5 T13N R9E UM 6/1/2012 0124-08 Top of Productive Horizon: 8.KB(ft above MSL): 53.2 15.Field/Pool(s): 286 FSL 3037 FEL S31 T14N R9E UM GL(ft above MSL): 12.2 Total Depth: 9.Plug Back Depth(MD+TVD): Nikaitchuq/Schrader Bluff Oil Pool 1121 FSL 5238 FEL 25 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- 516569.84 y- 6036479.38 Zone- 4 18,670'MD/3,429'TVD ADL 355024,373301,391283 TPI: x- 509924.03 y- 6038911.78 Zone- 4 11.SSSV Depth(MD+TVD): 17.Land Use Permit: Total Depth: x- 502575.53 y- 6044996.09 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) 1,921'MD/1,780'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 GRADE TOP BOTTOM TOP BOTTOM HOLE SIZE CEMENTING RECORD FT PULLED 20 178.89 X-65 37 160 37 160 Driven N/A N/A 13.375 68 L-80 35 2413 35 2135 16 10.7 ppg ASL: 417 bblsN/A 12.5 DmLiteCRETE:68 bbls 9.625 40 L-80 33 8993 33 3516 12.25 12.5 ppg LiteCRETE:212 bbls N/A 4.5 11.6 L-80 8775 18660 3510 3429 8.75 Blank Liner with ICD's N/A 24.Open to production or injection? Yes❑ No❑ 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) 4.5 8801 : 8,647'MD/3,498'TVD R 26. ACID,FRACTURE,CEMENT SQUEEZE,ETC. LOA' LL=["N i ■ RECEIVED I V E D DEPTH INTERVAL(MD) AMOUNT AND KIND OF MATERIAL USED i 6 i. F- ._ i JUL 162012 .. 09i7II 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 N9/ 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 Li No❑✓ =dewall Cores Acquired? Yes ❑ No❑., If Yes to either question,list formations and intervals cored(MD+TVD of top and bottom of each),and sum, arize lithology and presence of oil,gas or water (submit separate sheets with this form,if needed).Submit detailed descriptions,core chips,photographs=nd laboratory analytical results per 20 AAC 25.071. f, o a; o .• RBDMS JUL 17 2012 4/A___ Form 10-407 Revised 12/2009 CONTINUED ON REVERSE Submit original only 29. GEOLOGIC MARKERS (List all formations and markers encountered): 30. FORMATION TESTS NAME MD TVD Well tested? ❑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 1921 1780 OA sand top 8638 3497 Formation at total depth: OA sand 18670 3429 31. List of Attachments: Directional Survey,As Run Wellbore Schematic,Well Operations Summary 32. I hereby certify that the foregoing is true and corr-ct to the best of my knowledge. Contact: Michele Cesari Printed Name: Nelson Carballo ALS Title: Superintendent lo Signature: ® 1 Phone: (907)865-3338 Date: 7/12/2012 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-Altemating-Gas Injection,Salt Water Disposal,Water Supply for Injection,Observation,or Other.Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 4b: TPI(Top of Producing Interval). Item 8: The Kelly Bushing and Ground Level elevations in feet above mean sea level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 13: The API number reported to AOGCC must be 14 digits(ex:50-029-20123-00-00). Item 20: Report true vertical thickness of permafrost in Box 20. Provide MD and TVD for the top and base of permafrost in Box 28. Item 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 24: If this well is completed for separate production from more than one interval(multiple completion),so state in item 1,and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced,showing the data pertinent to such interval). Item 27: Method of Operation: Flowing,Gas Lift,Rod Pump,Hydraulic Pump,Submersible,Water Injection,Gas Injection,Shut-in,or Other (explain). Item 28: Provide a listing of intervals cored and the corresponding formations,and a brief description in this box. Submit detailed description and analytical laboratory information required by 20 AAC 25.071. Item 30: Provide a listing of intervals tested and the corresponding formation,and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. 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Daily Report WellCode:26154 Field Name: Nikatchuq • API/UW1:50-029-23457-00-00 2�,r, Date:5/2/2012 - Report#: 1 II II II page 1 of 1 Wellbore name: 0124-08 Well Header Permit/Concession N° Operator ENI Share)%) Well Configuration type 402100 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(ft) Ground Level(ft) Water Depth(ft) RKB-Base Flange(ft) RKB-Tubing Spool(ft) 53.15 1220 0.00 36.96 Rig Information Contractor Rig Name Rig Type NABORS ALASKA NABORS 245 E LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(ftKB) Target Depth(ND...Depth Dr.(MD)(ft) Drilling Hours(hr) Avg ROP(ft/hr) DFS(days) 0124-08 DRILLING 5/8/2012 18,666.0 18.510.00 176.23 105.0 -5.67 Daily Information End Depth(ftKB) End Depth(TVD)(f.. Depth Progress(ft) Drilling Hours(hr) Avg ROP(ft/hr) POB Temperature(°F) Weather Wind 0.0 84.0 -1.0 Snow WC-17' WNW @ 11 MPH Daily summary operation 24h Summary Rig accepted to Well 0124-08 05/02/2012 @ 12:00 hrs-Prepare to move ng over well 0124-08. Operation at 07.00 Prepare to move ng over wet 0124-08. 24h Forecast Move utility module and many up with drill module.Connect all lines and inner connects.Install stairways,build berms and finalize pre-spud checklist.NN Vetco starter head and test seals.Load shed with 5"DPs.Spot CCB.P/U 5"DP. Lithology Shows MAASP Pressure(psi) Mud Weight(lb/gal) Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 12:00 17.30 ' 5.50 5.50'MOB A 1 'P Rig accepted to Well 0124-08 05/02/2012 @ 12:00 hrs.B/D water and steam lines throughout rig.Secure wellbay.R/D kenning.Move cuttings box and continue preparing for rig move. ./ 17:30 20:00 2.50 8.00 MOB 'A 1 'P Set ng mats to move rig and utility module.Swap power.R/D interconnects beetween pit and sub modules.Start Lampson. R/D inner connect beelween motors/boiler room.Remove scaffolding in front of wellbay.Remove berming. 20:00 22:30 2.50 10.50 MOB A 2 P Safe out all door ways and landings.Jack up drill module and set on crib blocks,remove plywood and move east 90'.Jack up utility module and set on crib blocks,remove plywood and move east 90'. 22:30 00:00 s 1.50 12.00'MOB 'A 1 'P P/U mats,pit liner on well OP16-03. 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 Charles Cason Eni Petroleum Sr.Dig.Spvr. Eni representative Angelo Lamanna Eni Petroleum Drtg Spvr. angelo.lamanna@enipetroleum.com 907-685-1493 907-903-7269 Eni representative Bemie Leas Eni Petroleum Rig Clerk 907-670-8601 907-575-9427 Eni representative Mike Nelson Eni Petroleum HSE 907-685-1496 Eni representative Ken Bogner Eni Petroleum Matenal Coordinator Eni representative Alvin Criswell Eni Petroleum Expediter 907-980-7545 Tool Push Toby Bordelon Nabors Alaska Drilling Tour Pusher 907-670-1492 Tool Push Matt Vanhoose Nabors Alaska Drilling Tour Pusher 907-670-1492 Eni representative Marc Kuck Eni Petroleum Completion Eng. Last Casing seat Cas.Type OD(in) ID(in) Grade Top(ftKB) Bottom(ftKB( Run Date CONDUCTOR 20 18.250 X65 0.0 160.0 5/2/2012 Last Leakoff Test Depth(ftKB) ND(ItKB) Fluid Type Fluid Density(Ib/gal) P Surf Applied(psi) Eq.Mud Weight(Ib/gal) Leak Off Pressure(psi) If* Eni E&P Division I Well Name:0124-08 ENI Petroleum Co.Inc. Daily Report Well Code:26154 Field Name:Nikatchuq • API/LP/VI 50-029-23457-00-00 2^n Date:5/3/2012 - Report#: 2 II II I� page 1 of 1 Wellbore name: 0124-08 Well Header Permit/Concession N° Operator ENI Share(%) Well Configuration type 402100 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(ft) Ground Level(ft) Water Depth(ft) RKB-Base Flange(ft) RKB-Tubing Spool(ft) 53.15 12.20 0.00 36.96 Rig Information Contractor Rig Name Rig Type NABORS ALASKA NABORS 245 E LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(ftKB) Target Depth(ND...Depth Dr.(MD)(ft) Drilling Hours(hr) Avg ROP(ft/hr) DFS(days) 0124-08 DRILLING 5/8/2012 18,666.0 18,510.00 176.23 105.0 -4.67 Daily Information End Depth(ftKB) End Depth(TVD)(f.. Depth Progress(ft) Drilling Hours(hr) Avg ROP(ft/hr) POB Temperature(°F) Weather Wind 0.0 87.0 5.0 Light Snow WC-8° WSW @ 12 MPH Daily summary operation 24h Summary Move sub and utility modules over well 0124-08 and many up same-OP21-WVV01 need to be lifted with CTU-Move ng off 0124-08 to west 15'. Operation at 07.00 Rig maintenance while waiting for CTU. 24h Forecast Prepare for Coiled Tubing Unit 0g up-Rig in standby waiting for lifting job on OP21-WW01. Lithology Shows MAASP Pressure(psi) Mud Weight(lb/gal) 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 MOB A 1 P Lay herculite and mats for moving rig over well 0124-08. 04:00 12:00 8.00 12.00 MOB A 2 P Move utility module to west.Spot sub module on 0124-08.Shim with ply wood,pull crib blocks,set sub on mats and check level:Ok. 12:00 15:30 3.50 15.50 MOB -A 2 P Spot utility module to sub.Shim with ply wood,pull crib blocks,set on mats and lower curtains. 15:30 16:30 1.00 16.50 MOB A 1 U OP21-WW01 need to be lifted with coiled tubing to perform flow back.Decided to move rig off well 0124-08 to create space for CTU. 16:30 22:00 5.50 22.00 MOB A 2 U Move ng off 0124-08 to west 15'. 22:00 00:00 2.00 24.00 MOB A 1 U Set roof cover on well 0124-08.Hook up interconnects at motor room and steam lines. Daily Contacts Position Contact Name _ Company Title E-mail Office Mobile Eni representative Ben Perry Eni Petroleum -Sr.Ddg.Spvr. 907.685.1483 Eni representative Chades Cason Eni Petroleum Sr.Dig.Spvr. Eni representative Angelo Lamarina Eni Petroleum Drig Spur. angelo.lamanna@enipetroleum.corn 907-685-1493 907-903-7269 Eni representative Bernie Leas Eni Petroleum Rig Clerk 907-670-8601 907-575-9427 Eni representative Mike Nelson Eni Petroleum HSE 907-685-1496 Eni representative Ken Bogner Eni Petroleum Matenal Coordinator Eni representative Alvin Criswell Eni Petroleum Expediter 907-980-7545 Tool Push Toby Bordelon Nabors Alaska Dolling Tour Pusher 907-670-1492 Tool Push Matt Vanhoose Nabors Alaska Drilling Tour Pusher 907-670-1492 Eni representative Marc Kuck Eni Petroleum Completion Eng. Last Casing seat Cas.Type OD(in) ID(in) Grade Top(ftKB) Bottom(ftKB) Run Date CONDUCTOR 20 18.250 X65 0.0 160.0 5/2/2012 Last Leakoff Test Depth(ftKB) ND(ftKB) Fluid Type Fluid Density(1b/gal) P Surf Applied(psi) Eq.Mud Weight(Iblgal) Leak Off Pressure(psi) 777751 Eni E&P Division I Well Name:0124-08 ENI Petroleum Co.Inc. Daily Report Well Code:26154 Field Name:Nikatchuq • Date:5/4/2012 - Report#: 3 e i ii APIIUWI:50-029-23457-00-00 page 1 of 1 Wellbore name: 0124-08 Well Header Permit/Concession N° Operator ENI Share)%) Well Configuration type • 402100 ENI PETROLEUM 100.00 HORIZONTAL • Rotary Table Elevation(ft) Ground Level(ft) Water Depth(ft) RKB-Base Flange(ft) RKB-Tubing Spool(ft) • 53.15 12.20 0.00 36.96 • Rig Information Contractor Rig Name Rig Type NABORS ALASKA NABORS 245E LAND RIG • Job Information Wellbore Job Phase Spud Date Target Depth(ftKB) Target Depth(TVD...Depth Dr.(MD)(ft) Drilling Hours(hr) Avg ROP(ftlhr) DFS(days) 0124-08 DRILLING 5/8/2012 18,666.0 18,510.00 176.23 105.0 -3.67 Daily Information End Depth(ftKB) End Depth(TVD)(1..tDepth Progress(ft) Drilling Hours(hr) Avg ROP(ft/hr) POB Temperature(°F) Weather Wind 0.0 82.0 1.0 Overcast WC-12' NE @ 9 MPH Daily summary operation 24h Summary Perform ng maintenance while waiting on coil tubing unit to lift OP12-WWO1 in and start well to flowing.Change iron roughneck dies,change make up and break out lines. Operation at 07.00 Rig on standby waiting for lifting job on OP21-WW01. 24h Forecast Rig on standby waiting for lifting job on OP21-WW01-Move rig back over well 0124-08. Lithology Shows MAASP Pressure(psi) Mud Weight(lb/gal) 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 MOB A -24 U Perform ng maintenance while waiting on coil tubing unit to lift OP12-WW01 in and start well to flowing.Change iron roughneck dies,change make up and break out lines. - Daily Contacts Position Contact Name Company Title E-mail Office Mobile Eni representative Charles Cason 'Eni Petroleum Sr.Drig.Spvr. Eni representative Angelo Lamanna Eni Petroleum DrIg Spvr. angelo.lamanna@enipetroleum.corn 907-685-1493 907-903-7269 Eni representative Bernie Leas Eni Petroleum Rig Clerk 907-670-8601 907-575-9427 Eni representative Mike Nelson Eni Petroleum HSE 907-685-1496 Eni representative Ken Bogner Eni Petroleum Matenal Coordinator Eni representative Alvin Caswell Eni Petroleum Expediter 907-980-7545 Tool Push Toby Bordelon Nabors Alaska Drilling Tour 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(ftKB) Bottom(ftKB) Run Date CONDUCTOR 20 18.250 X65 0.0 160.0 5/2/2012 Last Leakoff Test Depth(ftKB) TVD(ftKB) Fluid Type Fluid Density(lb/gal) P Surf Applied(psi) Eq.Mud Weight(lb/gal) Leak Off Pressure(psi) 11* Eni E&P Division IWeII Name:0124-08 ENI Petroleum Co.Inc. Daily Report Well Code:26154 Field Name:Nikatchuq • API/UWI:50-029-23457-00-00 2 n o Date:5/5/2012 - Report#: 4 II II'I page 1 of 1 Wellbore name: 0124-08 Well Header Permit/Concession N° Operator ENI Share(%) Well Configuration type 402100 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(ft) Ground Level(ft) Water Depth(ft) RKB-Base Flange(ft) RKB-Tubing Spool(ft) 53.15 12.20 0.00 36.96 Rig Information Contractor Rig Name Rig Type NABORS ALASKA NABORS 245 E LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(ftKB) Target Depth(ND...Depth Dr.(MD)(ft) Drilling Hours(hr) Avg ROP(ft/hr) DES(days) 0124-08 DRILLING 5/8:2012 18,666.0 18,510.00 176.23 105.0 -2.67 Daily Information End Depth(ftKB) End Depth(TVD)(f.. Depth Progress(ft) Drilling Hours(hr) Avg ROP(ft/hr) POB Temperature(°F) Weather Wind 0.0 82.0 5.0 Snow WC-10 ENE @15 MPH Daily summary operation 24h Summary Perform rig maintenance while waiting on cod tubing unit to lift OP12-WW01 in and start well to flowing.Change iron roughneck dies,change make up and break out lines. Operation at 07.00 Rig on standby waiting for lifting job on OP21-WW01. 24h Forecast Rig on standby waiting for lifting job on OP21-WW01-Move ng back over well 0124-08. Lithology Shows MAASP Pressure(psi) Mud Weight(lb/gal) 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 MOB A '24 U Perform rig maintenance while waking on coil tubing unit to lift OP12-WW01 in and start well to flowing.Assist Schlumberger to spot CTU.C/O saver sub 8 gripper block/dies on Canng Top Drive.Install new service loops. Daily Contacts Position Contact Name Company Title E-mail Office Mobile Eni representative Charles Cason Eni Petroleum Sr.Dig.Spvr. Eni representative Angelo Lamarina Eni Petroleum Dig Spvr. angelo.lamanna@enipetroleum.com 907.685-1493 907-903-7269 Eni representative Bernie Leas Eni Petroleum Rig Clerk 907-670-8601 907-575-9427 Eni representative Mike Nelson Eni Petroleum HSE 907-685-1496 Em representative Ken Bogner Eni Petroleum Material Coordinator 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 Dolling Tour Pusher 907-670-1492 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(ftKB) Bottom(ftKB) Run Date CONDUCTOR 20 18.250 X65 0.0 160.0 5/2/2012 Last Leakoff Test Depth(ftKB) ND(ftKB) Fluid Type Fluid Density(Iblgal) P Surf Applied(psi) Eq.Mud Weight(Ib/gal) Leak Off Pressure(psi) Eni E&P Division IN/ell Name:0124-08 IN* ENI Petroleum Co.Inc. Daily Report Well Code:26154 Field Name:Nikatchuq • APIIUWI:50-029-23457-00-00 2�, Date:5/6/2012 - Report#: 5 II II II page 1 of 1 Wellbore name: 0124-08 Well Header PermitiConcession N' Operator ENI Share(o) Well Configuration type 402100 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(ft) Ground Level(ft) Water Depth(ft) RKB-Base Flange(ft) RKB-Tubing Spool(ft) 53.15 12.20 0.00 36.96 Rig Information Contractor Rig Name Rig Type NABORS ALASKA NABORS 245 E LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(ftKB) Target Depth(TVD...Depth Dr.(MD)(ft) Drilling Hours(hr) Avg ROP(ft/hr) DFS(days) 0124-08 DRILLING 5/8/2012 18,666.0 18,510.00 176.23 105.0 -1.67 Daily Information End Depth(ftKB) End Depth(TVD)(f.. Depth Progress(ft) Drilling Hours(hr) Avg ROP(ft/hr) POB Temperature(°F) Weather Wind 0.0 82.0 10.0 Snow WC-7' NE©19 MPH Daily summary operation 24h Summary Rig on standby waiting for lifting job on OP21-WW01-Move rig back over well 0124-08-Hook up interconnects-Install Vetco Gray starter head-N/U drilling riser,flow&fill-up lines-Install Katch-Kan. Operation at 07.00 Load pipe shed with 5"DP,strap and tally.P/U,M/U&R/B in derrick stands 5"DP.Spot CCB in progress. 24h Forecast Load pipe shed with 5"DPs-Spot CCB-P/U 285 joints of 5"DP and rack rack in derrick-Pre spud safety meeting.P/U BHA.Spud well 0124-08. Lithology Shows •MAASP Pressure(psi) Mud Weight(lb/gal) Time Log Start End Cum Time Time Dur(hr) Our(hr) Phase Opr. Act. Plan Oper.Descr. 00 00 10.00 10.00 10.00 MOB 'A 23 U Perform rig maintenance while waiting on coil tubing unit to lift OP12-WW01 in and start well to flowing.Hang Top Drive service loops&secure saety lines.Terminate wires per Nabors electrician. 1000 11:00 1.00 11.00 MOB A 1 P B/D steam lines on sub complex.Fold up walkways/interconnects throughout rig. 11:00 12:00 1.00 12.00 MOB A 2 P Spot/center sub module over well 0124-08.Shim with ply wood,pull crib blocks,set sub on mats and check level:Ok. 12:00 14:00 2.00 14.00 MOB 'A 2 P Spot utility module to sub&many up same.Shim with ply wood,pull crib blocks,set on mats and check level:Ok. 14:00 18:00 4.00 18.00 MOB -A 1 P Lower curtains,remove mats long side,secure stairs and landings,berm around rig.Hook up interconnect at motor room. pits,charge pump room and shaker room.Turn on steam. 18:00 00:00 6.00 24.00 DRILL C 5 P Vetco Gray installed starter head and pressure test to 500 psi x 10 min:Ok.N/U drilling riser,flow&fill-up lines.Install Katch-Kan.Measurements.36.96'to load shoulder and 40.95'to ground level. Daily Contacts Position Contact Name Company Title E-mail Office Mobile Eni representative Charles Cason Eni Petroleum Sr.Ddg.Spvr. Eni representative Angelo Lamarina Eni Petroleum Drlg Spvr. angelo.lamasna@enipetroleum.com 907-685-1493 907-903-7269 Eni representative Bernie Leas Eni Petroleum Rig Clerk 907-670-8601 907-575-9427 Eni representative Mike Nelson Eni Petroleum HSE 907-685-1496 Eni representative Ken Bogner Eni Petroleum Material Coordinator Eni representative Alvin Criswell Em 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(ftKB) Bottom(ftKB) Run Date CONDUCTOR 20 18.250 X65 0.0 160.0 5/2/2012 Last Leakoff Test Depth(ftKB) TVD(ftKB) Fluid Type Fluid Density(Iblgal) P Surf Applied(psi) Eq.Mud Weight(lb/gal) Leak Off Pressure(psi) --* Eni E&P Division I Well Name:0124-08 ENI Petroleum Co.Inc. Daily Repo)..}` Well Code:26154 Field Name:Nikatchuq • Date:5/7/2012 - Report#: 6 APIIUWI:50-029-23457-00-00 2 r' rr ii page 1 of 1 Wellbore name: 0124-08 Well Header Permit/Concession N° Operator ENI Share(%) Well Configuration type 402100 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(ft) Ground Level(ft) Water Depth(ft) RKB-Base Flange(ft) RKB-Tubing Spool(ft) 53.15 12.20 0.00 36.96 Rig Information Contractor Rig Name Rig Type NABORS ALASKA NABORS 245 E LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(ftKB) Target Depth(TVD...Depth Dr.(MD)(ft) Drilling Hours(hr) Avg ROP(ft/hr) DFS(days) 0124-08 DRILLING 5/8/2012 18,666.0 18,510.00 176.23 105.0 -0.67 Daily Information End Depth(ftKB) End Depth(TVD)(f.. Depth Progress(ft) Drilling Hours(hr) Avg ROP(ft/hr) POB Temperature(°F) Weather Wind 0.0 83.0 12.0 Cloudy WC-3° NE @ 17 MPH Daily summary operation 24h Summary Finish N/U Katch Kan and Riser-Terminate installation of service loops on Top Drive-Load pipe shed with 5"DPs-Spot CCB-P/U 50 stands of 5"DP and rack rack in derrick. Operation at 07.00 P/U,M/U and R/B stands of 5"DP. 24h Forecast P U 285 joints of 5"DP and rack rack in derrick-P/U HWDP and Jar-Pm spud safety meeting.P/U BHA#1-Wash 20"C.P.down to 160'-P/U BHA#2-Spud well 0124-08-Doll 0 16"surface section. Lithology Shows MAASP Pressure(psi) Mud Weight(1b/gall 8.34 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 C 5 P Finish N/U Riser and Katch Kan.Load pipe shed w/5"doll pipe&strap/tally. 03.00 16:30 13.50 16.50 DRILL -E 25 TRO4 Continue installing and wiring Top Drive service loops.Test hook up kelly hose,bail rams,safe out all slings.nuts/bolts. Inspect derrick and Top Drive f/loose tools.Clear rig floor.Spot CCB and cuttings tank. 16.30 00:00 7.50 24.00 DRILL E 5 'P Pull bushings and set mouse hole in rotary table.P/U,M/U&R/B stands of 5"DPs(50 stands @ midnight). Daily Contacts Position Contact Name Company Title E-mail Office Mobile Eni representative Charles Cason Eni Petroleum Sr.Dig.Spvr. Eni representative Angelo Lamarina Eni Petroleum Dig Spvr. angelo.lamanna@enipetroleum.com 907-685-1493 907-903-7269 Eni representative Bernie Leas Eni Petroleum Rig Clerk 907-670-8601 907-575-9427 Eni representative Mike Nelson Eni Petroleum HSE 907-685-1496 Eni representative Ken Bogner Eni Petroleum Material Coordinator Eni representative Alvin Criswell Eni Petroleum Expediter 907-980-7545 Tool Push Bruce Simonson Nabors Alaska Dnlling Tool Pusher 907-670-1492 Tool Push Matt Vanhoose Nabors Alaska Dnlling Tour Pusher 907-670-1492 Last Casing seat Can.Type OD(in) ID(in) Grade Top(ftKB) Bottom(ftKB) Run Date CONDUCTOR 20 18.250 X65 0.0 160.0 5/2/2012 Last Leakoff Test Depth(ftKB) TVD(ftKB) Fluid Type Fluid Density(Iblgal) P Surf Applied(psi) Eq.Mud Weight(lb/gal) Leak Off Pressure(psi) J"11* Eni E&P Division I Well Name:0124-08 ENI Petroleum Co.Inc. Daily Report Well Code:26154 Field Name: Nikatchuq • API/UW:50-029-23457-00-00 2�If II,r,II Date:5/8/2012 - Report#: 7 page 1 of 1 Wellbore name: 0124-08 Well Header Permit/Concession N° Operator ENI Share(%) Well Configuration type 402100 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(ft) Ground Level(1t) Water Depth(ft) RKB-Base Flange(ft) RKB-Tubing Spool(ft) 53.15 12.20 0.00 36.96 Rig Information Contractor Rig Name Rig Type NABORS ALASKA NABORS 245E LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(ftKB) Target Depth(TVD...Depth Dr.(MD)(ft) Drilling Hours(hr) Avg ROP(ft/hr) DFS(days) 0124-08 DRILLING 5/8/2012 18,666.0 18,510.00 176.23 105.0 0.33 Daily Information End Depth(ftKB) End Depth(TVD)(1.. Depth Progress(ft) Drilling Hours(hr) Avg ROP(ft/hr) POB Temperature('F) Weather Wind 298.0 286.1 138.00 1.43 96.5 83.0 14.0 Snow WC 3° EAST @ 10 MPH Daily summary operation 24h Summary P/U,M/U&R/B 45 stands 5"DP+4 stands 5"HWDP+stand with Jar-Held Pre-Spud Safety Meeting-P/U&M/U BHA#1-Fill hole oath mud and check for leaks:Ok- Start washing 20"C.P.down to 140'-Troubleshoot MWD sensor issues-Wash and ream 20"C.P.down to 160'-P/U BHA#2-Spud well @ 16:00 hrs-Slide Drilling 16"section to 298'-Circulate hole clean and POOH-Finish to P/U BHA#2 and RIH to 296'-Take Gyro/MWD surveys. Operation at 07.00 Drill 16"section as per well plan.Report time @ 489'. 24h Forecast Drill 16"section as per well plan to planned TD @ 2,427'. Lithology Shows MAASP Pressure(psi) Mud Weight(Iblgal) 8.80 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 5 P P/U,M/U&R/B 45 stands of 5"OPs(95 stands total in derrick x-9088'). 07:30 09:30 2.00 9.50 DRILL E 5 P P/U 4 stands of 5"HWDP and 1 stand with 2x 5"HWDP+7 3/4"Weatherford Hydraulic Jar(s/n 14171141).Rack back in derrick.P/U stabs,XO,saver sub,16"bit and stage on drill floor. 09:30 10:00 0.50 10.00 DRILL E 1 P 'Held Pre-Spud Safety Meeting with all parts involved:discussed of safe area,well program.spill prevention,spill response equipment,well control procedures.Fill out pre-spud check list Ok. 10:00 10:30 0.50 10.50 DRILL E 5 P P/U and M/U BHA#1:0 16"MT bit Hughes MX-1(s/n 5205094)with 3x20/32"&106/32"nozzles(TFA=1.116)+PDM with 1.83 bend(s/n 962-1056)+NM Stabilizer+XO.Total length=40.47'. 10:30 11:00 0.50 11.00 DRILL E 12 P 'Fill hole with spud mud.Check all lines and mud system for leaks:Ok.Circulate with all pumps and pressure test mud lines to 2,600 psi:Ok. 11:00 11:30 0.50 11.50'DRILL E 6 P RIH BHA#1.Break circulation @ 450 gpm/300 psi/40 rpm and start washing 20"C.P.down to 140'. 11:30 12:00 0.50 12.00 DRILL E 25 P Service Top Drive:add lube oil to Top Drive. 12:00 13.30 1.50 13.50 DRILL E 6 P Continue to wash and ream 20"C.P.from 140'to 160'@ 450 gpm/310 psi/40 rpm/1K TO.POOH BHA#1 racking back 2 stands 5"HWDP. 13:30 15:30 2.00 15.50 DRILL E 5 P Held PJSM.P/U BHA#2 with 0 16"MT bit Hughes MX-1(s/n 5205094)with 3x 20/32"+1x 16/32"nozzles(TFA=1.116)+ PDM 1.83 bend(s/n 962.1056)+NM stabilizer+2x NMXO+Gyro Pulse collar(s/n 15810)+8"PowerPulse MWD(s/n G0175)+ARC 825(s/n E5556)+NM Stabilizer+NMDC+XO.Orient motor and Gyro tools. 15:30 16:00 0.50 16.00 DRILL E 12 P RIH BHA#2 at 115'and perform shallow test 500 gpm/390 psi:Ok. 16:00 16.30 0.50 16.50 DRILL E 3 P Spud well 0124-08 @ 16'.00 hrs.Drilling Rotary with mud motor f/160'-1/180'-Pump 600 gpm/610 psi/WOB=5-8 K/40 rpm TTK TO/Mud wt=8.8 ppg. 16:30 17.30 1.00 17.50 DRILL E 25 TS03 -Had problem with MWD sensor in surface.Troubleshoot same:Ok. 17:30 18:30 1.00 18.50'DRILL E 11 P 'Check Gyro&MWD survey:Ok.Set Depth. 18:30 21:00 2.50 21,00 DRILL E 3 P Dolling Sliding/Rotary with mud motor f/180'-8298'-Pump 500 gpm/550 psi/WOB=10 K/Mud wt=8.8 ppg.Record Survey Gyro Data as needed.Monitor for leaks&conductor breaching:Ok. 21:00 '21:30 0.50 21.50'DRILL E 7 P Circulate hole clean @ 550 gpm/600 psi/40 rpm/1K TO. 21:30 '23:00 1.50 23.00 DRILL E 5 P 'P/U and R/B 2x stands 5"HWDP-P/U and M/U 2x NM Flex DCs+Saver sub+Jar(Weatherford s/n 14171141)+XO. Total length BHA#2=247.83'. 23:00 '00:00 1.00 24.00'DRILL E 4 P 'RIH BHA#2 down to 296'.Take surveys as per Gyro/MWD. Daily ADT=1.43 hrs(ART=0.38 hrs-AST=1.05 hrs).Jam=1.43 hrs. Daily Contacts Position Contact Name Company Title E-mail Office Mobile Eni representative Charles Cason Eni Petroleum Sr.Ddg.Spvr. Eni representative Angelo Lamaona Eni Petroleum Drlg 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 Mike Nelson Eni Petroleum HSE 907-685-1496 Eni representative Ken Bogner Eni Petroleum Material Coordinator Em 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(ftKB) Bottom(ftKB) Run Date CONDUCTOR 20 18.250 X65 0.0 160.0 5/2/2012 Last Leakoff Test Depth(ftKB) TVD(ftKB) Fluid Type Fluid Density(Ib/gal) P Surf Applied(psi) Eq.Mud Weight(1b/gall Leak Off Pressure(psi) ) �� Eni E&P Division .} I Well Name:0124-08 ENI Petroleum Co.Inc. Daily Report Well Code:26154 Field Name: Nikatchuq •II Date:5/9/2012 - Report#: 8 API/UWI:50-029-23457-00-00 2" " page 1 of 1 Wellbore name: 0124-08 Well Header Permit/Concession N° Operator ENI Share(%) Well Configuration type . 402100 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(ft) Ground Level(ft) Water Depth(ft) RKB-Base Flange(ft) RKB-Tubing Spool(ft) 53.15 12.20 0.00 36.96 Rig Information Contractor Rig Name Rig Type NABORS ALASKA NABORS 245 E LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(ftKB) Target Depth(ND...Depth Dr.(MD)(ft) Drilling Hours(hr) Avg ROP(ft/hr) DFS(days) 0124-08 DRILLING 5/8/2012 18.666.0 18.510.00 176.23 105.0 1.33 Daily Information End Depth(RKB) End Depth(TVD)(f.. Depth Progress(ft) Drilling Hours(hr) Avg ROP(ft/hr) FOB Temperature(°F) Weather Wind 1,560.0 1,466.5 1,262.00 13.70 92.1 83.0 19.0 Overcast WC 5° ESE @ 14 MPH Daily summary operation 24h Summary Drill ahead 0 16"section as per well plan f/298'V1,560'(2801'ND). Operation at 07.00 Drill 16"section as per well plan.Report time @ 1.819'. 24h Forecast Drill 16"section as per well plan to planned TD @ 2,427'-Circulate 3x B/U-BROOH. Lithology Shows MAASP Pressure(psi) Mud Weight(Ib/gal) 9.10 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/Sliding 0 16"section f/298'5/581'/500 gpm/650 psi/40 rpm/2.3k Ribs/WOB=15-25k lb/Up wt=78k lb -Dw wt=78k lb-Rot wt=78k lb/Mud wt=8.8 ppg-Take Gyro survey every 30'. 06.00 '12:00 6.00 12.00 DRILL E 3 P Drilling Rotary/Sliding 0 16"section f/581'V830'/500 gpm/800 psi/40 rpm/3.4k&lbs/WOB=10-25k Ib/Up wt=92k lb -Dw wt=85k lb-Rot wt=90k lb/Mud wt=8.9 ppg-Take Gyro survey every 30'. 12.00 18:00 6.00 18.00 DRILL E 3 P Drilling Rotary/Sliding 0 16"section f/830'V1,130'/500 gpm/820 psi/40 rpm/3.4k Ribs/WOB=10-25k lb/Up v4=92k lb-Dw wt=85k lb-Rot wt=92k lb/Mud wt=9.1 ppg-Take MWD survey as needed. 18.00 00.00 6.00 24.00 DRILL E 3 P Drilling Rotary/Sliding 0 16"section(/1,130'V1,560'(1,477'ND)/600 gpm/1100 psi/40 rpm/3'4k Ribs/WOB=20-25k lb/Up wt=92k lb-Dw wt=92k lb-Rot wt=100k lb/Mud wi=9.1 ppg-Take MWD survey every 100'. Daily ADT=13.7 hrs(ART=5.29 hrs-AST=8.41 hrs].Jars=15.13 hrs. Daily Contacts Position Contact Name Company _ Title E-mail Office Mobile _ Eni representative Charles Cason Eni Petroleum Sr.DrIg.Spvr. Eni representative Angelo Lamarina Eni Petroleum Drig Spvr. angelo.lamarina@enipetroleum.com 907-685-1493 907-903-7269 Eni representative Mitch Billington Eni Petroleum Rig Clerk 907-670-8601 Eni representative Steve Abbott Eni Petroleum •Material Coordinator 907-685-1491 907-715-0740 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 Turcotte Nabors Alaska Drilling Tour Pusher 907-670-1492 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(ftKB) Bottom(ftKB) Run Date CONDUCTOR 20 18.250 X65 0.0 160.0 5/2/2012 Last Leakoff Test Depth(RKB) ND(ftKB) Fluid Type Fluid Density(lb/gal) P Surf Applied(psi) Eq.Mud Weight(lb/gal) Leak Off Pressure(psi) fin* Eni E&P Division I Well Name:0124-OE ENI Petroleum Co.Inc. Daily Report Well Code: 26154 Field Name: Nikatchuq Date:5/10/2012 - Report#: 9 APIIUWI:50-029-23457-00-00 en 11 page 1 of 1 Wellbore name: 0124-08 Well Header Permit/Concession IT Operator ENI Share(%) Well Configuration type 402100 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(ft) Ground Level(ft) Water Depth(ft) RKB-Base Flange(ft) RKB-Tubing Spool(ft) 53.15 12.20 0.00 36.96 Rig Information Contractor Rig Name Rig Type NABORS ALASKA NABORS 245E LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(ftKB) Target Depth(TVD...Depth Dr.(MD)(ft) Drilling Hours(hr) Avg ROP(ft/hr) DFS(days) 0124-08 DRILLING 5/8/2012 18,666.0 18,510.00 176.23 105.0 2.33 Daily Information End Depth(ftKB) End Depth(TVD)(f..,Depth Progress(ft) Drilling Hours(hr) Avg ROP(ft/hr) POB Temperature(°F) Weather Wind 2,427.0 2,133.4 867.00 7.13 121.6 86.0 0.0 Partly Cloudy WC E @ 15 MPH 10° Daily summary operation 24h Summary Doll ahead 0 16"section as per well plan 61,560'1/2,427'(2,144'TVD)-Circulate 3x B/U-BROOH-UD BHA#2. Operation at 07.00 R/U Frank's fill up tool and GBR equipments to RIH 13 3/8"casing. 24h Forecast L/D BHA#2-Dummy run with csg hanger-Prepare and RIH 13 3/8"casing-Cement Job-L/D Riser and install Vetco Wellhead and BOPs. Lithology Shows MAASP Pressure(psi) Mud Weight(lb/gal) 9.30 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/Sliding 0 16"section f/1,560'1/2,030'/600 gpm/1200 psi/40 rpm/3.k5k fibs/WOB=10-20k lb/Up wt= 112k lb-Dw wt=95k lb-Rot wt=100k lb/Mud wt=9.1 ppg-Take MWD survey every 100'. 06:00 10.30 4.50 10.50 DRILL E 3 P Drilling Rotary/Sliding 0 16"section(/2,030'tl TD @ 2,427'(2,144'TVD)/600 gpm/1300 psi/40 rpm/5k(bibs/WOB= 10-30k lb/Up wt=115k lb-Dw wt=95k lb-Rot wI=108k lb/Mud wt=9.1 ppg-Take MWD survey every 100'. Daily ADT=7.13 hrs[ART=3.47 hrs-AST=3.66 hrs[.Jars=22.26 hrs. 10:30 14:00 3.50 14.00 DRILL E 7 P Circulate 3x B/U while backreaming one stand very slowly 8/2,427'1/2,120'@ 800 gpm/1600 psi/80 rpm/4k ft'lb.Rack back one stand each bottom up. 14:00 22:30 8.50 22.50 DRILL E 6 P BROOH 8/2,120'5/305'@ 800 gpm/1600 psi/80 rpm/3-4k ft'lb.Pulled 10 min/stand or as hole dictates. 2230 00:00 1.50 24.00 DRILL E 5 P POOH from 305'to surface.R/B jar stand 8,Drill Collars.B/D Top Drive.L/D BHA#2 in progress. F Daily Contacts Position Contact Name Company Title E-mail Office Mobile Eni representative Charles Cason Eni Petroleum 'Sr.Drlg.Spur. Eni representative Angelo Lamarina Eni Petroleum Drlg Spar. angelo.lamarina@enipetroleum.com 907-685-1493 907-903-7269 Eni representative Mitch Billington Eni Petroleum Rig Clerk 907-670-8601 Eni representative Steve Abbott Eni Petroleum Material Coordinator 907-685-1491 907-715-0740 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 Main Turcotte Nabors Alaska Drilling Tour Pusher 907-670-1492 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(11KB) Bottom(ftKB) Run Date CONDUCTOR 20 18.250 X65 0.0 160.0 5/2/2012 Last Leakoff Test Depth(ftKB) TVD(ftKB) Fluid Type Fluid Density(lb/gal) P Surf Applied(psi) Eq.Mud Weight(Ib/gal) Leak Off Pressure(psi) Eni E&P Division /Well Name: 0124-08 01511* ENI Petroleum Co.Inc. Daily Report Well Code:26154 Field Name: Nikatchuq • API/UWI:50-029-23457-00-00 2^r, Date:5/11/2012 - Report#: 10 'I 11 page 1 of 1 Wellbore name: 0124-08 Well Header PermiVConcession N° Operator ENI Share(%) Well Configuration type 402100 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(ft) Ground Level(ft) Water Depth(ft) RKB-Base Flange(ft) RKB-Tubing Spool(ft) 53.15 12.20 0.00 36.96 Rig Information Contractor Rig Name Rig Type NABORS ALASKA NABORS 245 E LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(ftKB) Target Depth(TVD...Depth Dr.(MD)(ft) Drilling Hours(hr) Avg ROP(ft/hr) DFS(days) 0124-08 DRILLING 5/8/2012 18,666.0 18,510.00 176.23 105.0 3.33 Daily Information End Depth(ftKB) End Depth(TVD)(f.. Depth Progress(ft) Drilling Hours(hr) Avg ROP(ft/hr) POB Temperature(°F) Weather Wind 2,427.0 2,133.4 0.00 86.0 27.0 Cloudy WC 18' NE @ 10 MPH Daily summary operation 24h Summary L/D BHA#2-Dummy run with csg hanger-Prepare and RIH 13 3/8"casing-Cement Job-L/D Riser and install Vetco Wellhead. Operation at 07.00 N/D Riser and starting head. 24h Forecast L/D Riser and install Vetco Wellhead and BOPs-Test BOPs as per AOGCC requirements-Install Wear Bushing-P/U,M/U and RIH BHA#3 for 12 1/4"section. Lithology Shows MAASP Pressure(psi) Mud Weight(lb/gal) 9.35 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 POOH and UD BHA#2.[Bit Dull 1-1-WT-A-E-0-WT-TD]. 03:00 03:30 0.50 3.50 DRILL G 11 P Make dummy run with 13 3/8"csg hanger and landing joint. 03:30 05:30 2.00 5.50 DRILL G 5 P 'R/U GBR casing tools and power tongs.R/U Frank's casing fill up tool. 05:30 11:00 5.50 11.00 DRILL G 4 P P/U,M/U Shoe track ed Baker Lock-Check float equipment:Ok-P/U,M/U 8 RIH Casing 13 3/8"688 L80 BTC(10k?bibs M/U torque)112,413'.M/U Hanger and Landing Jt-Remove casing slip and land hanger. [Shoe @ 2,413'-Float Collar @ 2,331'-Up wt 210k lbs,Dw wt 145k lbs]. 11:00 12:00 1.00 12.00 DRILL H 5 P 'R/D Frank's fill up tool and R/U Schlumberger cement head. 12:00 16:30 4.50 16.50 DRILL H 7 P Break circulation to condition mud for cement job(1.5 bpm @ 50 psi).Reciprocate pipe 2'-3'.Continue to circulate to condition mud for cement job(3-05 bpm @ 100-0180 psi)YP=15-No losses. 16:30 20:30 4.00 20.50 DRILL H 9 P -Cement 13 3/8"surface casing as per program.SLB pump 5 bbl Mud Push II and test lines to 4000 psi-SLB pump 95 bbl S La-I" Mud Push II @ 10.1 ppg(5 bpm @ 260 psi)-Drop Bottom Plug-SLB mix and pump 417 bbls Lead Slurry @ 10.7 ppg ,_-- [Class Artic Sea Lite 940 sacks,2.49 Yield,mix fluid 11.928 gaVak]-Followed by 68 bbls Tail Slurry @ 12.5 ppg G yt l - [DeepCRETE 243 sacks,1.57 Yield,mix fluid 5.494 gal/sk]-Drop Top Plug-SLB pump 10 bbls water-Switch to Rig Pump and Displace with 339 bbls of mud(5 bpm @ 150-0360 psi)-[Bump plug @ 20:30]-Pressure casing up to 860 psi (500 psi over FCP)-Release pressure and check float equipment:Ok-No losses during job-Recovered ?25 bbls of good lead slurry on surface. 20.30 00.00 3.50 24.00 DRILL H 5 P 1R/D and UD cement head-Back out and UD Landing JI-R/D Casing handling and cementing equipment.P/U Johnny Wacker and line up to pump.Rinse aid pig taking retums to shakers. Daily Contacts Position Contact Name Company Title E-mail Office Mobile Eni representative Charles Cason Eni Petroleum Sr.Ddg.Spvr. Eni representative Angelo Lamarina Eni Petroleum DrIg Spvr. angelo.lamarina@enipetroleum.com 907-685-1493 907-903-7269 Eni representative Mitch Billington Eni Petroleum Rig Clerk 907-670-8601 Eni representative Steve Abbott Eni Petroleum Material Coordinator 907-685-1491 907-715-0740 Eni representative Mike Nelson Eni Petroleum HSE 907-685-1496 Eni representative Alvin Cnswell Eni Petroleum Expediter 907-980-7545 Tool Push Bruce Simonson Nabors Alaska Dolling Tool Pusher 907-670-1492 Tool Push Mattt Turcotte i Nabors Alaska Dolling Tour Pusher 907-670-1492 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(ftKB) Bottom(ftKB) Run Date CASING 133/8 12.415 L80 0.0 2,413.0 5/11/2012 Last Leakoff Test Depth(ftKB) TVD(WB) Fluid Type Fluid Density(Ib/gal) P Surf Applied(psi) Eq.Mud Weight(lb/gal) Leak Off Pressure(psi) 11* Eni E&P Division I Well Name: 0124-08 ENI Petroleum Co.Inc. Daily Report Well Code:26154 Field Name: Nikatchuq • Date:5/12/2012 - Report#: 11 API/l1Wl:50-029-23457-00-00 2" "li page 1 of 1 Wellbore name: 0124-08 Well Header Permit/Concession N` Operator ENI Share)%) Well Configuration type 402100 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(ft) Ground Level(ft) Water Depth(ft) RKB-Base Flange(ft) RKB-Tubing Spool(ft) 53.15 12.20 0.00 36.96 Rig Information Contractor Rig Name Rig Type NABORS ALASKA NABORS 245 E LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(ftKB) Target Depth(ND...Depth Dr.(MD)(ft) Drilling Hours(hr) Avg ROP(ft/hr) DFS(days) 0124-08 DRILLING 5/6!2012 18,666.0 18,510.00 176.23 105.0 4.33 Daily Information End Depth(RKB) End Depth(TVD)(f.. Depth Progress(ft) Drilling Hours(hr) Avg ROP(fVhr) POB Temperature(`F) Weather Wind 2,427.0 2,133.4 0.00 84.0 23.0 Cloudy WC 23" NNE @ 5 MPH Daily summary operation 24h Summary N/D Katch Kan-N/D Riser and starting head-Install Vetco Wellhead and BOPs-Test BOPS as per AOGCC requirements. Operation at 07.00 Slip and cut 74'drilling line. 24h Forecast Finish test BOPS as per AOGCC requirements-Install Wear Bushing-Slip and cut 74'dolling line-P/U,M/U and rih BHA83-Perform Casing pressure integrity test-Drill out float equipments,cement and 20'new hole-Displace to new LSND mud system-Perform FIT/LOT-Drill 12 1/4"section as per well plan. Lithology Shows MAASP Pressure(psi) Mud Weight(Ib/gal) 9.35 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 H 1 P L/D Casing tongs,elevator,X-Over and flush tool.Clean Drill Floor. 01:30 05:00 3.50 5.00 DRILL C 5 P R/D Katch Kan,mouse hole.flow/bleeder lines-N/D Riser and Vetco starting head. 05:00 09:30 4.50 9.50 DRILL C 5 P N/U Wellhead and valves-Pressure test Wellhead/Csg Hanger 5k psi x 10 minutes:Ok. 09:30 12:00 2.50 12.00 DRILL C 5 P N/U 13 5/8"Riser and BOP Stack on wellhead&secure.N/U choke and kill lines. I. 12:00 17:30 5.50 17.50 DRILL C 5 P Waited on welder to cut pincher nipple down to match flow line.Finish N/U BOPs.Install Ketch Kan and skirts.Get test pump and chart recorder ready for BOP test. 17-.30 19:00 1.50 19.00 DRILL C 1 P P/U test plug,M/U 5"testing joint and install as per Vetco indications.Fluid pack BOPS&choke lines with water. . 19:00 00.00 5.00 24.00 DRILL C 12 P Test Bop as per AOGCC requirements.Test rams&all valves 250 psi low/3,500 psi high and annular 250 psi low/2,500 psi . high.All test held per 5 min and charted.AOGCC reps.Matt Herrera waived to witness the test @ 06.10 hrs 05/12/2012..- Daily Contacts Position Contact Name Company Title Entail Office Mobile Eni representative Charms Cason Eni Petroleum Sr.DrIg.Spur. Eni representative Angelo Lamarina Eni Petroleum DrIg Spur. angelo.lamarina@enipetroleum.com 907-685-1493 907-903-7269 Eni representative Mitch Billington Eni Petroleum Rig Clerk 907-670-8601 Eni representative Steve Abbott Eni Petroleum Material Coordinator 907-685-1491 907-715-0740 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 Mattt Turcotte Nabors Alaska Drilling Tour Pusher 907-670-1492 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(RKB) Bottom(RKB) Run Date CASING 13 3/8 12.415 L80 0.0 2,413.0 5/11/2012 Last Leakoff Test Depth(RKB) ND(ftKB) Fluid Type •Fluid Density(Ib/gal) P Surf Applied(psi) Eq.Mud Weight(Ib/gal) Leak Off Pressure(psi) I I fl* Eni E&P Division I Well Name:0124-08 ENI Petroleum Co.Inc. Daily Report Well Code:26154 Field Name:Nikatchuq • Date:5/13/2012 - Report#: 12 API/UWI:50-029-23457-00-00 2" " page 1 of 1 Wellbore name: 0124-08 Well Header Permit/Concession N° Operator ENI Share(%) Well Configuration type 402100 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(ft) Ground Level(ft) Water Depth(ft) RKB-Base Flange(ft) RKB-Tubing Spool(ft) 53.15 12.20 000 36.96 Rig Information Contractor Rig Name Rig Type NABORS ALASKA NABORS 245 E LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(ftKB) Target Depth(ND...Depth Dr.(MD)(ft) Drilling Hours(hr) Avg ROP(ft/hr) DFS(days) 0124-08 DRILLING 5/8/2012 18,666.0 18,510.00 176.23 105.0 5.33 Daily Information End Depth(ftKB) End Depth(TVD)(f.. Depth Progress(ft) Drilling Hours(hr) Avg ROP(ft/hr) POB Temperature(°F) Weather Wind 2,447.0 2,147.3 20.00 0.12 166.7 63.0 27.0 Snow WC 18' W @ 11 MPH Daily summary operation 24h Summary • Finish test BOPS as per AOGCC requirements-Install Wear Bushing-Shp and cut 74'drilling line-P/U,M/U and rih BHA#3-Perform Casing pressure integrity test-Drill out float equipments,cement and 20'new hole-Displace to new LSND mud system. • Operation at 07.00 • Downtime:Working on the Top Drive to fix electrical problem. 24h Forecast Perform FIT/LOT-Drill 12 1/4"section as per well plan. Lithology Shows MAASP Pressure(psi) Mud Weight(Iblgal) 9.25 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 0000 00.30 0.50 0.50 DRILL C 12 'P Finish to Test Bop as per AOGCC requirements.Test rams&all valves 250 psi low/3,500 psi high and annular 250 psi low/2,500 psi high.All test held per 5 min and charted.AOGCC reps.Matt Herrera waived to witness the test @ 06:10 hrs 05/12/2012.Koomey drawdown from 1900 psi to 2100=37 sec.2100 to 3000=129 sec. 00:30 02:00 1.50 2.00 DRILL C 5 P Pull test plug and install wear bushing.R/D testing equipment&L/D.B/D choke manifold and kill lines. 02:00 02:30 0.50 2.50 DRILL E 4 P M/U mule shoe and RIH with 4 stands of 5"HWDP. 02:30 04:30 2.00 4.50 DRILL E 25 P Slip and cut 74'of drilling line.Inspect and grease brake linkage.Set/calibrate crownsave&blocks. 04:30 05:00 0.50 5.00 DRILL E 5 P POOH and LID 12 joints of 5"HWDP. 05:00 06:00 1.00 6.00 DRILL E 1 P P/U BHA#3 stab,XO.bit,saver sub&stage on ng floor.R/U tongs,slips and dog collar. 06:00 06:30 0.50 6.50 DRILL E 25 P Grease and inspect Top Drive. 06.30 09:30 3.00 9.50 DRILL E 5 P Held PJSM.P/U BHA#3:P/U BHA#5:Smith PDC bit 0 12 1/4"MDSi616(s/n JF6477)with 6x 16/32"nozzles(TFA=1.116) +Xceed 900(s/n 082)+MWD(s/n E6381)+ILS NM stab+ARC 825(s/n E5556)+Frank's Hi Tool(s/n 004)+Smith Roller Reamer(s/n U43011)+NMDC+2x NM Flex DC+Float sub+Weatherford 7 3/4"Hydraulic Jar(s/n 14171141)+ X0+2x 5"HWDP.Total length=285.07'. 09 30 10.30 1.00 10.50 DRILL E 4 P RIH with 5"Dp to 1,050'and M/U 12 1/4"Ghost Reamer(s/n 269646). 1030 13.00 2.50 13.00 DRILL E 12 TRO2 Attempt to perform shallow test tools @ 650 gpm:mud aired up in pit#7.Add de-foamer,functioning the charge/mud pumps&bleeder to achieve pressure.Clean suction screens on mud pump.Continue to attempt to get pumps primed Ok. Perform shallow test BHA#3:Ok. 13:00 14.30 1.50 14.50 DRILL E 4 P RIH BHA#3 with 5"DP and tag cement©2,324'. 14-30 15.00 0.50 15.00 DRILL E 7 P R/U head pin,circulating hose and chart recorder.Circulate and condition mud for casing integrity test @ 500 gpm/1000 psi. 15:00 16:30 1.50 16.50 DRILL E 12 P Pressure test 13 3/8"Csg @ 2500 psi for 30 min(chart record):Ok.RID testing equipment. 16:30 19:30 3.00 19.50 DRILL E 3 P Drill out plugs+float collar+cement from 2,324'to 2,410'@ 500.630 gpm/600-800 psi/60 rpm/3-6k ft`Ibs TO 12-10 Klbs WOB/Up Wt=125 K/Rot Wt=100 k/Dw Wt=95 k/MW=9.3 ppg.Float collar @ 2,328'. 19:30 21:30 2.00 21.50 DRILL E 3 P Drill out shoe,rat hole and 20'of new 12 1/4"hole(/2,410'1/2,447'(8 620 gpm/850 psi/60 rpm/4-5k ft`Ibs TO/2-10 Klbs WOB/Up Wt=125K/Rot Wt=100 k/DwWt=95 k/MW=9.3 ppg.Shoe qt 2,410'. 21:30 23:00 1.50 23.00 DRILL E 9 P Held PJSM.Displace well to 9.2+ppg LSND mud system @ 9 bpm/750 psi while reciprocate/rotate at 55 rpm/3K ft`Ibs TO.When good mud retumed.shut pumps down and blow down lines. 23:00 00:00 1.00 24.00 DRILL E 1 P Clean possum belly,ditch,flow line,under shakers and pit#7. Daily Contacts Position Contact Name Company Title E-mail Office Mobile Eni representative -Charles Cason 'Eni Petroleum Sr.Ddg.Spvr. Eni representative Angelo Lamarina Eni Petroleum Drlg Spvr. angelo.lamarina@enipetroleum.com 907-685-1493 907-903-7269 Eni representative Mitch Billington Eni Petroleum Rig Clerk 907-670-8601 Eni representative Steve Abbott Eni Petroleum Material Coordinator 907-685-1491 907-715-0740 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(ftKB) Bottom(ftKB) Run Date CASING 133/8 12.415 L80 0.0 2.413.0 5/11/2012 Last Leakoff Test Depth(ftKB) TVD(ftKB) Fluid Type Fluid Density(lb/gal) P Surf Applied(psi) Eq.Mud Weight(Ib/gal) Leak Off Pressure(psi) 2,413.0 2,123.64 LSND mud©9.2 ppg 9.30 377.0 12.72 1.403.0 l, Eni E&P Division 'Well Name:0124-08 ENI Petroleum Co.Inc. Daily Report Well Code:26154 Field Name:Nikatchuq • APIIUWI:50-029-23457-00-00 2^ Date:5/14/2012 - Report#: 13 I' I) page 1 of 1 Wellbore name: 0124-08 Well Header Permit/Concession N° Operator ENI Share(7.) Well Configuration type 402100 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(ft) Ground Level(ft) Water Depth(ft) RKB-Base Flange(ft) RKB-Tubing Spool(ft) 53.15 12.20 0.00 36.96 Rig Information Contractor Rig Name Rig Type NABORS ALASKA NABORS 245 E LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(ftKB) Target Depth(TVD...Depth Dr.(MD)(ft) Drilling Hours(hr) Avg ROP(ft/hr) DFS(days) 0124-08 DRILLING 5/8/2012 18666.0 18,510.00 176.23 105.0 6.33 Daily Information End Depth(RKB) End Depth(TVD)(f.. Depth Progress(ft) Drilling Hours(hr) Avg ROP(ft/hr) POB Temperature(°F) Weather Wind 3,965.0 2,753.5 1,518.00 13.98 108.6 83.0 27.0 Snow WC 16" N @13 MPH Daily summary operation 24h Summary Circulate and condition LSND mud-Performed LOT-EMW=12.6 ppg-Repair TDS-Drill 12 1/4"section f/2,447'V3,965'(2,765'TVD). Operation at 07.00 Drill ahead 12'/."section as perwellplan @ 4500'MD. 24h Forecast Drill 12 1/4"section as per well plan. Lithology Shows MAASP Pressure(psi) Mud Weight(Ib/gal) 6.30 Time Log Start End Cum Time Time Dur(hr) Our(hr) Phase Opr. Act. Plan Oper.Descr. 00:00 00.30 0.50 0.50 DRILL E 1 P Finish cleaning up under shakers and in pit#7. 00:30 01:00 0.50 1.00 DRILL E 7 P Circulate B/U and condition LSND mud fror LOT/FIT @ 700 gpm/900 psi/80 rpm/2.5k ft'Ibs TO/Mud Weight In&Out= 9.3 ppg/10 min Gel=9 Ib/10061'. 01:00 02:00 1.00 2.00 DRILL E 11 P R/U head pin&lines and perform LOT with 9.3 ppg LSND mud-Leak off pressure=377 psi-EMW=12.6 ppg-R/D L O _( testing equipment. 02:00 04:00 2.00 4.00 DRILL E 25 TRO4 Troubleshoot Top Drive by electrician.Top drive occasionally shuts off.Found a wire problem&corrected same. 04:00 12:00 8.00 12.00 DRILL E 3 P Drill rotary 0 12 W new hole 612,447't/3,160'\850 gpm @ 1350 psi\120 rpm @ 4.6k Ribs\WOB=2*15k Ib\Up wt= 118k lb-Dw wt=95k lb-Rot wt=100k lb\Mud wt=9.3 ppg-Lowering pump rate(700 gpm)and 80 rpm on hardspots. Make survey as needed-Ream and wash 30'every connection.Used Canrig Soft Torque for all drilled interval. 12:00 18.00 6.00 18.00 DRILL E 3 P Drill rotary 0 12 Y. new hole(/3,160'V3,499'\850 gpm @ 1350 psi\120 rpm @ 4.6k R'Ibs\WOB=2*15k lb\Up wt= 118k lb-Dw wt=92k lb-Rot wt=102k lb\Mud wt=9.3 ppg-Encountered very hard spot @ 3.485i-3,502'-Lowering pump rate(700 gpm)and 80 rpm on hardspots.Make survey as needed-Ream and wash 30'every connection.Used Canrig Soft Torque for all drilled interval. 18:00 00'00 6.00 24.00 DRILL E 3 P Drill rotary 0 12'G"new hole(/3,499'V3,965'(2,765'TVD)\900 gpm @ 1620 psi\120 rpm @ 4.6k Ribs\WOB=2.10k lb \Up vA=112k lb-Dw wt=92k lb-Rot wt=102k lb\Mud wt=9.3 ppg-Lowering pump rate(700 ppm)and 80 rpm on hardspots.Make survey as needed-Ream and wash 30'every connection.Used Canrig Soft Torque for all drilled interval. Daily ADT=13.98 hrs-Cumulative ADT=14.1 hrs/JAR=36.36 Hrs. Daily Contacts Position Contact Name Company Title E-mail Office Mobile Eni representative Charles Cason Eni Petroleum Sr.Drlg.Spvr. Eni representative Angelo Lamarina Eni Petroleum Drlg Spvr. angelo.lamarina@enipetroleum.com 907-685-1493 907-903-7269 Eni representative Mitch Billington Eni Petroleum Rig Clerk 907-670-8601 Eni representative Steve Abbott Eni Petroleum Material Coordinator 907-685-1491 907-715-0740 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 Turcotte Nabors Alaska Dolling Tour Pusher 907-670-1492 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(RKB) Bottom(ftKB) Run Date CASING 13 3/8 12.415 L80 0.0 2,413.0 5/11/2012 Last Leakoff Test Depth(ftKB) TVD(ftKB) Fluid Type Fluid Density(1b/gall P Surf Applied(psi) Eq.Mud Weight(Iblgal) Leak Off Pressure(psi) 2,413.0 2,123 64 LSND mud @ 9.2 ppg 9.30 377.0 12.72 1,403.0 fig* Eni E&P Division 'Well Name:0124-08 ENI Petroleum Co.Inc. Daily Re p O rt Well Code: 26154 Field Name: Nikatchuq • API/UWI:50-029-23457-00-00 2 II n r, Date:5/15/2012 - Report#: 14 '( II page 1 of 1 wellbore name: 0124-08 Well Header Permit/Concession N° Operator ENI Share(%) Well Configuration type 402100 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(ft) Ground Level(ft) Water Depth(ft) RKB-Base Flange(ft) RKB-Tubing Spool(ft) 53.15 1220 0.00 36.96 Rig Information Contractor Rig Name Rig Type NABORS ALASKA NABORS 245 E LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(ftKB) Target Depth(ND...Depth Dr.(MD)(ft) Drilling Hours(hr) Avg ROP(ft/hr) DFS(days) 0124-08 DRILLING 5/8/2012 18,666.0 18,510.00 176.23 105.0 7.33 Daily Information End Depth(ftKB) End Depth(TVD)(f.. Depth Progress(ft) Drilling Hours(hr) Avg ROP(ft/hr) POB Temperature(°F) Weather •Wind 6,065.0 3,118.4 2,100.00 17.65 119.0 84.0 23.0 Snow WC 16' Variable @ 7 MPH Daily summary operation 24h Summary Drill 12 1/4"section 1/3,965'U6,065'(3,129'TVD).Very hard spot 1/5.775'1/5,786'&86,020'1/6,065'.Lower UGNU top @ 5,762'(3.080'ND). Operation at 07.00 BROOH @ 5,100'. 24h Forecast BROOH-POOH BHA#3 and L/D-M/U BHA#4 with 0 12 1/4"Smith insert bit-RIH to 6,065'-Drill 12 1/4"section as per well plan. Lithology Shows MAASP Pressure(psi) Mud Weight(1b/gal) 9.30 Time Log Start End Cum Time Time Dur(hr) Dun(hr) Phase Opr. Act. Plan Oper.Descr. 00.00 06.00 6.00 6.00 DRILL E 3 P Drill rotary 0 12 Z"new hole 1/3,965'8/4,780'1900 gpm @ 1800 psi 180-120 rpm @ 4-6k ft'lbs\WOO=4-15k lb\Up wt= 112k Ib-Dwwt=88k lb-Rot wt=100k lb\Mud wt=9.2+ppg-Lowenng pump rate(700 gpm)and 80 rpm on hardspots. Make survey as needed-Ream and wash 30'every connection,entire stand every other one.Used Canng Soft Torque for all drilled interval. 06 00 12 00 6.00 12.00 DRILL E 3 P Drill rotary 0 12 7."new hole 54,780'8/5,555'1900 gpm @ 1895 psi 180-120 rpm @ 5.7k ft'Ibs\WOB=2+15k lb\Up wt= 123k lb-Dw wt=80k lb-Rot wt=100k lb\Mud wt=9.2 ppg-Lowering pump rate(700 gpm)and 80 rpm on hardspots. Make survey as needed-Ream and wash 30'every connection.entire stand every other one.Used Canrig Soft Torque f/4,780'1/5,168'. 12 00 18 00 6.00 18.00 DRILL E 3 P Drill rotary 0 12 W new hole f/5,555'1/5,934'\900 gpm @ 1980 psi 180-120 rpm©6+8k ftdbs\WOB=2+15k Ib\Up wit= 125k lb-Dw wt=82k lb-Rot wt=110k lb\Mud wt=9.2+ppg-Very hard spot 1/5,775'U5,786'.Make survey as needed- Ream and wash 30'every connection.Used Canrig Soft Torque for all dolled interval except f/5,555'1/5,613'. 18.00 00 00 6.00 24.00 DRILL E 3 P Drill rotary 0 12 W new hole t/5,934'U6,065'(3,129'ND)\900 gpm @ 2050 psi\120-140 rpm @ 8+10k fl lbs\WOB= 10+32k lb\Up wt=125k lb-Dw wt=82k lb-Rot wt=110k lb\Mud wt=9.2+ppg-Very hard spot(/6,020'U6.065'.Used Canrig Soft Torque for all drilled interval. Note:ROP<2 ft/hr.Decided to POOH and check BHA&bit condition.Lower UGNU top @ 5,762'(3,080'ND). Daily ADT=17.65 hrs-Cumulative ADT=31.75 hrs/JAR=54.01 Hrs. Daily Contacts Position Contact Name Company Title E-mail Office Mobile - Eni representative Charles Cason Eni Petroleum Sr.Drlg.Spvr. Eni representative Angelo Lamarina Eni Petroleum Drlg Spvr. angelo.lamanna@enipetroleum.com 907-685-1493 907-903-7269 Eni representative Mitch Billington Eni Petroleum Rig Clerk 907-670-8601 Eni representative Steve Abbott Eni Petroleum Material Coordinator 907-685-1491 907-715-0740 Eni representative Steve Millea ENI Petroleum HSE 907-685-1496 Em representative Alvin Caswell Eni Petroleum Expediter 907-980-7545 Tool Push Bruce Simonson Nabors Alaska Dulling 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(ftKB) Bottom(ftKB) Run Date CASING 133/6 12.415 L80 0.0 2,413.0 5/11/2012 Last Leakoff Test Depth(RKB) ND(ftKB) Fluid Type Fluid Density(Ib/gal) P Surf Applied(psi) Eq.Mud Weight(1b/gall Leak Off Pressure(psi) 2,413.0 2,123.64 LSND mud @ 9.2 ppg 9.30 377.0 12.72 1,403.0 1 ii...poi il Eni E&P Division I Well Name:0124-08 I ENI Petroleum Co.Inc. Daily Report Well Code:26154 Field Name:Nikatchuq • APIIUWI:50-029-23457-00-00 2^,t II Date:511612012 - Report#: 15 (I II page 1 of 1 Wellbore name: 0124-08 Well Header Permit/Concession N° Operator ENI Share(%) Well Configuration type 402100 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(ft) Ground Level(ft) Water Depth(ft) RKB-Base Flange(ft) RKB-Tubing Spool(ft) 53.15 12.20 0.00 36.96 Rig Information Contractor Rig Name Rig Type NABORS ALASKA NABORS 245 E LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(ftKB) Target Depth(TVD...Depth Dr.(MD)(ft) Drilling Hours(hr) Avg ROP(ft/hr) DFS(days) 0124-08 DRILLING 5/8/2012 18,666.0 18,510.00 176.23 105.0 8.33 Daily Information End Depth(ftKB) End Depth(TVD)(f.. Depth Progress(ft) Drilling Hours(hr) Avg ROP(ft/hr) POB Temperature(°F) Weather Wind • • 6,155.0 3,136.6 90.00 1.05 85.7 84.0 32.0 Cloudy WC 25' SSE @ 11 MPH Daily summary operation 24h Summary BROOH-POOH BHA#3 and UD-M/U BHA#4 with 0 12 1/4"Smith insert bit-RIH to 6,065'-Drill 12 114"section as per well plan down to 6.155'MD(3.148'TVD). Operation at 07.00 Drill ahead 12''/."section as per wellplan @ 6.342'MD. 24h Forecast Drill 12 1/4"section as per well plan. Lithology Shows MAASP Pressure(psi) Mud Weight(lb/gal) 9.30 Time Log Start End Cum Time Time Dur(hr) Dur(Br) Phase Opr. Act. Plan Oper.Descr. 00:00 10:00 10.00 10.00 DRILL E 6 P BROOH f/6.065'V2,394'at 10 min/stand or as hole dictates.900 gpm/1850 psi/120 rpm/7k fibs.No drag/tightspot. CBU x 2 inside 13 3/8"csg shoe. 10:00 12:00 2.00 12.00 DRILL E 4 -P Slug pipe.B/D top drive and POOH on elevator to 290'.B/0 ghost reamer.R/B 5"HWDP,jar and DC. 12:00 15:00 3.00 15.00 DRILL E 5 P UD BHA#3.Bit dull 1-3-BT-S-X-I-CT-PR. -)Ghost Reamer was%under but no grooves,nice even wear. -)Roller Reamer was'/.under but at on the body.The roller looked good.Some slight grooving on the leading edge. -)HI Tool was 1/16 under and even wear. -)ILS Stab-groove worn in bottom about 2 inches tall,just thru the tiles. Was about 1/8th under gauge overall. -)Upper Xceed Stab was full gague but starting to lose some tiles. -)Lower Xceed Stab was full gauge and showing very faint wear on the tile in the same place as the upper.Same pattern just not thru the tiles yet. 15.00 16:30 1.50 16.50 DRILL E 5 P Held PJSM.P/U BHA#4:Smith Insert bit 0 12 1/4"GF15B(s/n PX3948)with 3x 18/32"+lx 16/32"nozzles(TFA=0.942)+ Xceed 900(s/n 146)+MWD(s/n E6381)+ILS NM stab+ARC 825(s/n E5556)+Frank's Hi Tool(s/n 005)+Smith Roller Reamer(s/n 163388)+NMDC+2x NM Flex DC•Float sub+Weatherford 7 3/4"Hydraulic Jar(s/n 14171141)+X0+2x 5"HWDP.Total length=284.83'. 16.30 17.00 0.50 17.00 DRILL E 4 P RIH with 5"DP to 1,050'and M/U 12 1/4"Ghost Reamer(s/n 289781).Perform shallow test BHA#4:Ok. 17.00 17:30 0.50 17.50 DRILL E 25 P 'Service rig:service drawworks and iron roughneck. ' 17.30 21:30 4.00 21.50 DRILL E 4 P Continue RIH BHA#4 with 5"DP down to 6,065'.Wash down last 200'.Take survey 15'from bottom.Send downlink to Xceed.Up wt=128k lb-Dw wt=60k lb. 21 30 005:10 2.50 24.00 DRILL E 3 P Drill rotary 0 12 7."new hole 06,065'V6,155'(3,148'TVD)\900 gpm @ 2150 psi\100 rpm @ 7012k Ribs\WOB=2.30k lb I Up w1=140k lb-Dw wt=60k lb-Rot wt=105k lb\Mud WI=9.3 ppg-Very hard spot f/6,065'5/6,071'.Used Canrig Soft Torque for all drilled interval. Daily ADT=1.05 hrs-Cumulative ADT=32.8 hrs/JAR=55.06 Hrs. Daily Contacts Position _ Contact Name Company Title E-mail Office _ Mobile Eni representative Charles Cason Eni Petroleum Sr.Dug.Spvr. Eni representative Angelo Lamarina Eni Petroleum Drig Spvr. angelo.lamanna@enipetroleum.com 907-685-1493 907-903-7269 Eni representative Mitch Billington Eni Petroleum Rig Clerk 907-670-8601 Eni representative Steve Abbott Eni Petroleum Material Coordinator 907-685-1491 907-715-0740 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 I Mattt Turcotte ,Nabors Alaska Dulling Tour Pusher 907-670-1492 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(ftKB) Bottom(ftKB) Run Date CASING 13 3/8 12.415 L80 0.0 2,413.0 5/11/2012 Last Leakoff Test Depth(RKB) TVD(ftKB) Fluid Type Fluid Density(1b/gal) P Surf Applied(psi) Eq.Mud Weight(lb/gal) Leak Off Pressure(psi) 2,413.0 2,123.64 LSND mud @ 9.2 ppg 9.30 377.0 12.72 1,403.0 ?Ili* Eni E&P Division I Well Name:0124-08 ENI Petroleum Co.Inc. Daily Report Well Code:26154 Field Name:Nikatchuq • APIIUWI:50-029-23457-00-00 2^ Date:5/17/2012 - Report#: 16 If II page 1 of 1 Wellbore name: 0124-08 Well Header Permit/Concession N° Operator ENI Share(%) Well Configuration type 402100 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(ft) Ground Level(ft) Water Depth(ft) RKB-Base Flange(ft) RKB-Tubing Spool(ft) 53.15 12.20 0.00 36.96 Rig Information Contractor Rig Name Rig Type NABORS ALASKA NABORS 245 E LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(ftKB) Target Depth(TVD...Depth Dr.(MD)(ft) Drilling Hours(hr) Avg ROP(ft/hr) DFS(days) 0124-06 DRILLING 5/8/2012 18,666.0 18,510.00 176.23 105.0 9.33 Daily Information End Depth(f1KB) End Depth(TVD)(f...Depth Progress(ft) Drilling Hours(hr) Avg ROP(ft/hr) POB Temperature(°F) Weather Wind 7,691.0 3,375.3 1.536.00 19.59, 78.4 63.0 34.0 Cloudy WC 28' SSE @ 7 MPH Daily summary operation 24h Summary Drill 12 1/4"section V6,155'1/7,691'(3,387'TVD). Operation at 07.00 Drill ahead 12%"section as per wellplan @ 7,949'MD. 24h Forecast Drill 12 1/C section as per well plan-CBU. Lithology Shows MAASP Pressure(psi) Mud Weight(lb/gal) 9.30 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 V."new hole 8/6,1551/6,445\900 gpm @ 2150 psi\120 rpm @ 9,10k ft-lbs\WOB=20+25k lb\Up wt= 140k lb-Dw wt=82k lb-Rot wt=105k lb I Mud wt=9.3 ppg.Take survey as needed-Ream and wash 30'every connection.Used Canrig Soft Torque for all drilled interval. 06:00 12:00 6.00 12.00 DRILL E 3 P Drill rotary 0 12%."new hole 8/6,445'V6,650'1900 gpm @ 2200 psi 1120-140 rpm @ 9+10k ft4bs 1 WOB=10+20k lb\Up wt=140k lb-Dw wt=80k lb-Rot wt=105k lb\Mud wt=9.2+ppg.Take survey as needed-Ream and wash 30'every connection.Used Canrig Soft Torque for all drilled interval. 12'.00 18'00 6.00 18.00 DRILL E 3 P Drill rotary 0 12 7."new hole V6.650'1/7,230'1888 gpm @ 2280 psi 1140 rpm @ 9+11k Ribs\WOB=20+35k lb\Up wt= 150k lb-Dw wt=80k lb-Rot wt=105k lb\Mud wt=9.3+ppg.Take survey as needed-Ream and wash 30'every connection.Used Canrig Soft Torque for all drilled interval. 18.00 00 00 6.00 24.00 DRILL E 3 P Drill rotary 0 12 7."new hole 8/7.230'1/7,69V(3,387 TVD)1900 gpm @ 2150 psi\120 rpm @ 9+10k ft'lbs\WOB=20+25k lb\Up w4=140k lb-Dw wt=82k lb-Rot WI=105k lb\Mud wt=9.3 ppg.Take survey as needed-Ream and wash 30' every connection.Used Canrig Soft Torque for all drilled interval. Daily ADT=19.59 hrs-Cumulative ADT=52.4 hrs/JAR=74.65 Hrs. Daily Contacts Position Contact Name 1 Company Title E-mail Office Mobile - Eni representative Charles Cason Eni Petroleum Sr.Drlg.Spvr. Eni representative Angelo Lamarina Eni Petroleum Drlg Spur. angelo.lamarina@enipetroleum.com 907-685-1493 907-903-7269 Eni representative Mitch Billington Eni Petroleum Rig Clerk 907-670-8601 Eni representative Steve Abbott Eni Petroleum Material Coordinator 907-685-1491 907-715-0740 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 Matt Turcotte Nabors Alaska Drilling Tour Pusher 907-670-1492 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(ftKB) Bottom(ftKB) Run Date CASING 133/8 12.415 L80 0.0 2,413.0 5/11/2012 Last Leakoff Test Depth(ftKB) TVD(ftKB) Fluid Type Fluid Density(Ib/gal) P Surf Applied(psi) Eq.Mud Weight(Ib/gal) Leak Off Pressure(psi) 2,413.0 2,123.64 LSND mud @ 9.2 ppg 9.30 377.0 12.72 1,403.0 fill* Eni E&P Division I Well Name: 0124-08 EN!Petroleum Co.Inc. Daily Report Well Code:26154 Field Name:Nikatchuq • API/UWI:50-029-23457-00-00 2^n Date:5/18/2012 - Report#: 17 Ifl I� page 1 of 1 Wellbore name: 0124-08 Well Header Permit/Concession N° Operator ENI Share(%) Well Configuration type 402100 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(ft) Ground Level(ft) Water Depth(ft) RKB-Base Flange(ft) RKB-Tubing Spool(ft) 53.15 1220 0.00 36.96 Rig Information Contractor Rig Name Rig Type NABORS ALASKA NABORS 245 E LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(ftKB) Target Depth(TVD...Depth Dr.(MD)(ft) Drilling Hours(hr) Avg ROP(ft/hr) DFS(days) 0124-08 DRILLING 5/6/2012 18,666.0 18,510.00 176.23 105.0 10.33 Daily Information End Depth(ftKB) End Depth(TVD)(f.. Depth Progress(ft) Drilling Hours(hr) Avg ROP(ft/hr) POB Temperature(°F) Weather Wind 9,010.0 3,504.7 1,319.00 15.10 87.4 87.0 25.0 Cloudy WC 19" N @ 6 MPH Daily summary operation 24h Summary Drill 12 1/4"section ff7,691't/TD @ 9,010'(3,516'TVD)-CBU. Operation at 07.00 BROOH @ 7,844' 24h Forecast CBU x6-BROOH to 1,300'-Circulate till shakers clean-POOH and LID BHA#4. Lithology Shows MAASP Pressure(psi) Mud Weight(lb/gal) 9.30 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. new hole 1/7,691'V8,060'1800 gpm @ 2150 psi\80-120 rpm @ 9.11k ft-lbs\WOB=20.25k lb\Up wt=150k lb-Dwwt=78k lb-Rot wt=105k lb\Mud wt=9.4 ppg.Take survey as needed-Ream and wash 30'every connection.Used Canrig Soft Torque for all drilled interval. 06.00 12:00 • 6.00 12.00 DRILL E '3 P Drill rotary 0 12 7."new hole 1/8,060'118,370'1900 gpm @ 2700 psi 180-120 rpm @ 11.12k ftlbs\WOB=25.35k lb\Up wt=150k lb-Dwwt=75k lb-Rot wl=107k lb\Mud wt=9.4 ppg.Take survey as needed-Ream and wash 30'every connection.Used Canrig Soft Torque for all drilled interval. 12:00 18:00 ' 6.00 18.00 DRILL E 3 P Drill rotary 0 12 Y."new hole V8,370'1/8800'\900 gpm @ 2615 psi\130 rpm @ 12.16k ft'lbs\WOB=30.35k Ib\Up wt= 165k lb-Dw wt=70k lb-Rot wt=105k lb\Mud wt=9.4 ppg.Take survey as needed-Ream and wash 30'every connection.Used Canrig Soft Torque for all drilled interval. 18:00 21:00 • 3.00 21.00 DRILL E -3 P -Drill rotary 0 12'/."new hole f/8,800'tfTD @ 9,010'TD(3.516'TVD)\900 gpm @ 2720 psi\120 rpm @ 12.15k Ribs\ WOB=15.30k lb\Up wt=140k lb-Dwwt=82k lb-Rot wt=105k lb\Mud wt=9.3 ppg.Take survey as needed-Ream and wash 30'every connection.Used Canrig Soft Torque for all drilled interval.Circulate out 1500 units of gas @ 9,001'. Daily ADT=15.1 hrs-Cumulative ADT=67.5 hrs I JAR=89.75 Hrs. 21 00 00:00 3.00 24.00 DRILL E 7 P -CBU while backreaming one stand per bottoms up to 8,715'\900 gpm @ 2750 psi\140 rpm @ 12.13k ft-lbs. Daily Contacts Position Contact Name Company Title E-mail Office Mobile Eni representative -Ben Perry Em 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 Mitch Billington Eni Petroleum Rig Clerk 907-670-8601 Eni representative Steve Abbott Em Petroleum Material Coordinator 907-685-1491 907-715-0740 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 Matti Turcone Nabors Alaska Dolling Tour Pusher 907-670-1492 Last Casing seat Can.Type OD(in) ID(in) Grade Top(ftKB) Bottom(ftKB) Run Date CASING 13 3/8 12.415 L80 0.0 2,413.0 5/11/2012 Last Leakoff Test Depth(RKB) TVD(ftKB) Fluid Type Fluid Density(1b/gall P Surf Applied(psi) Eq.Mud Weight(Ib/gal) Leak OR Pressure(psi) 2,413.0 2,123.64 LSND mud @ 9.2 ppg 9.30 377.0 12.72 1.403.0, Eni E&P Division Well Name:0124-08 ENI Petroleum Co.Inc. Daily Report Well Code:26154 Field Name:Nikatchuq 011* � APIIUWI:50-029-23457-00-00 2 II^ Date:5/19/2012 - Report#: 18 II "n page 1 of 1 Wellbore name: 0124-08 Well Header Permit/Concession N° Operator ENI Share)%) Well Configuration type 402100 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(ft) Ground Level(ft) Water Depth(ft) RKB-Base Flange(ft) RKB-Tubing Spool(ft) 53.15 12.20 0.00 36.96 Rig Information Contractor Rig Name Rig Type . NABORS ALASKA NABORS 245 E LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(ftKB) Target Depth(TVD...Depth Dr.(MD)(ft) Drilling Hours(hr) Avg ROP(ft/hr) DFS(days) 0124-08 DRILLING 5/8/2012 18 666.0 18,510.00 176.23 105.0 11.33 Daily Information End Depth(ftKB) End Depth(TVD)(f.. Depth Progress(ft) Drilling Hours(hr) Avg ROP(ft/hr) POB Temperature(°F) Weather Wind 9,010.0 3,504.7 0.00 84.0 25.0 Cloudy WC 18' WSW @ 7MPH Daily summary operation 24h Summary CBU x6-BROOH to 1.300'-Circulate till shakers clean-POOH and L/D BHA#4-C/O top rams to 9 5/8". Operation at 07.00 R/U Tesco tool in progress. 24h Forecast C/O lop rams to 9/5"and test as per AOGCC requirements-R/U Tesco casing tool-9 5/8"Casing Job. Lithology Shows MAASP Pressure(psi) Mud Weight(Ib/gal) 9.30 Time Log Start End Cum I Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00:00 02:00 2.00 2.00 DRILL E 7 P CBU while backreaming one stand per bottoms up t/8,715'08,420'\900 gpm @ 2650 psi\140 rpm @ 12.13k ft-lbs. 02:00 12:00 10.00 12.00 DRILL E 6 P 'BROOH(/8,420'115,085'@ 15-20 min/stand 1900 gpm @ 1910 psi 1 140 rpm @ 9.12k ft-lbs. 12:00 19:30 7.50 19.50 DRILL E 6 P BROOH(/5.085'111.300'@ 10 min/stand 1900 gpm @ 2000->1500 psi 1 140 rpm @ 6.11k ft'Ibs. 19:30 20:00 0.50 20.00'DRILL E 7 P At 1,300'circulate 4x bottoms up 1900 gpm @ 1500 psi 8140 rpm @ 6k 8-lbs. 20:00 21:00 1.00 21.00 DRILL E 4 P -Monitor well:static.Pump slug and POOH 11BHA. 21:00 23:00 2.00 23.00 DRILL E 5 P LID BHA#4.Bit Dull:1-1-WT-A-E-1-NO-TD. -)Ghost Reamer was 1/8 under gauge but wom evenly. -)The NM Flex Drill collars showed significant wear on the wear bands and some grooving at the base of some of the wear bands. -)The Roller Reamer was 1/8 under and had step wear on the gauge protection. -)The HI tool was in gauge and showed slight wear to the pads. -)The ARC and MWD tool showed no damage or wear other than slight wear on the wear bands of the ARC. -)The ILS Non Mug Stab had a 1 inch groove in the lower portion of the blade and the upper end of the blade had notches worn in all the blades. -)The Xceed stabs looked very good.The upper blade was 1/16 under and the lower blade was in gauge. 23.00 00:00 1.00 24.00 DRILL C 5 P C/O Top rams to 9 5/8"csg rams.In progress. 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 Angelo Lamarina Eni Petroleum Ddg Spvr. angelo.lamarina@enipetroleum.com 907-685-1493 907-903-7269 Eni representative Mitch Billington Eni Petroleum Rig Clerk 907-670-8601 Eni representative Steve Abbott Eni Petroleum Material Coordinator 907-685-1491 907-715-0740 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 Dulling Tour Pusher 907-670-1492 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(RKB) Bottom(ftKB( Run Date CASING 13 3/8 12.415 L80 0.0 2,413.0 5/11/2012 Last Leakoff Test Depth(ftKB) TVD(ftKB) Fluid Type Fluid Density(lb/gal) P Surf Applied(psi) Eq.Mud Weight(Ib/gal) Leak Off Pressure(psi) 2,413.0 2,123.64 LSND mud @ 9.2 ppg 9.30 377.0 12.72 1,403.0 ft* Eni E&P Division I Well Name:0124-08 ENI Petroleum Co.Inc. Daily Report Well Code:26154 Field Name:Nikatchuq eDate:5/20/2012 - Report#: 19 APIIUWI:50-029-23457-00-00 t i l ii page 1 of 1 Wellbore name: 0124-08 Well Header Permit/Concession N. Operator ENI Share)%) Well Configuration type 402100 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(ft) Ground Level(ft) Water Depth(ft) RKB-Base Flange(ft) RKB-Tubing Spool(ft) 53.15 12.20 0.00 36.96 Rig Information Contractor Rig Name Rig Type NABORS ALASKA NABORS 245 E LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(ftKB) Target Depth(TVD...Depth Dr.(MD)(ft) Drilling Hours(hr) Avg ROP(ft/hr) DFS(days) 0124-08 DRILLING 5/8/2012 18,666.0 18,510.00 176.23 105.0 12.33 Daily Information End Depth(ftKB) End Depth(TVD)(f..,Depth Progress(ft) Drilling Hours(hr) Avg ROP(ft/hr) POB Temperature(°F) Weather Wind 9,010.0 3,504.7 0.00 83.0 25.0 Partly Cloudy WC Variable 5 MPH 25" Daily summary operation 24h Summary C/O top rams to 9 5/8"and test as per AOGCC requirements-R/U Tesco casing tool-Downtime:pipe skate broke down-RIH 9 5/8"Casing 1/6.930'. Operation at 07.00 R/D Tesco Toors 24h Forecast Complete to run 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 Pressure(psi) Mud Weight(Ib/gal) 9.30 Time Log Start End Cum Time Time Dur(Br) Dur(hr) Phase Opr. Act. Plan _ Oper.Descr. 00:00 02:30 2.50 2.50 DRILL C 12 P Finish to C/O top rams f/4%"x 7"variable U 9 5/8"-Fill BOP-Test 9 5/e"top rams 250/3500 psi 10 min on chart-Ok.Pull test plug-Install short wear bushing-L/D running and testing tool. ----. - 02:30 07:00 4.50 7.00 DRILL G 5 P Held PJSM.R/U Tesco casing running tools-Function test equipment Ok. 07:00 12:30 5.50 12.50 DRILL G 4 P 'Held PJSM-P/U 9 5/8"csg(40#/L-80/Hydril 563/Special drift 8.75")Floating-Fill shoe track and check float equipment Ok-RIH 1/2.489'(1/1.5 min/Jt-Av.MUT 13k ft-lbs). 12:30 18:30 6.00 18.50 DRILL G 25 TR99 Pipe skate broke down:powered catwalk buggy on skate sheared of(from attachment to chain.Troubleshoot and repair same. 18:30 00:00 5.50 24.00 DRILL G 4 P 'P/U 9 5/8"csg(408/L-80/Hydril 563/Special drift 8.75")Floating-RIH rotating(/2,489'1/6,930'. Parameters:60 rpm @ 2k->4.2k Albs-HKLD 50k->40k lbs-1/1.5 min/J1-Av.MUT 13k ft'lbs. 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 Angelo Lamaina Eni Petroleum Drlg Spvr. angelo.lamanna@enipetroleum.com 907-685-1493 907-903-7269 Eni representative Mitch Billington Eni Petroleum Rig Clerk 907-670-8601 Eni representative Steve Abbott Eni Petroleum Material Coordinator 907-685-149t 907-715-0740 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 Math Turcotte Nabors Alaska Drilling Tour Pusher 907-670-1492 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(ftKB) Bottom(ftKB) Run Date CASING 9 5/8 8.835 L80 0.0 8,993.0 5/20/2012 Last Leakoff Test Depth(ftKB) TVD(ftKB) Fluid Type Fluid Density(Ib/gal) P Surf Applied(psi) Eq.Mud Weight(Ib/gal) Leak Off Pressure(psi) 2,413.0 2,123.64 LSND mud @ 9.2 ppg 9.30 377.0 12.72 1,403.0 Iff* Eni E&P Division , IWeII Name:0124-08 ENI Petroleum Co.Inc. Daily Report L Well Code:26154 Field Name:Nikatchuq � API/UWI:50-029-23457-00-00 enrl U Date:512112012 - Report#: 20 II II page 1 of 1 Wellbore name: 0124-08 Well Header Permit/Concession N° Operator ENI Share(%) Well Configuration type 402100 ENI PETROLEUM 100.00 HORIZONTAL • Rotary Table Elevation(ft) Ground Level(ft) Water Depth(ft) RKB-Base Flange(ft) RKB-Tubing Spool(ft) 53.15 12.20 0.00 36.96 Rig Information Contractor Rig Name Rig Type NABORS ALASKA NABORS 245 E LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(ftKB) Target Depth(TVD...Depth Dr.(MD)(ft) Drilling Hours(hr) Avg ROP(ft/hr) DFS(days) • 0124-08 DRILLING 5/8/2012 18,666.0 18,510.00 176.23 105.0 13.33 Daily Information End Depth(ftKB) End Depth(TVD)(f.. Depth Progress(ft) Drilling Hours(hr) Avg ROP(ft/hr) POB Temperature("F) Weather Wind 9.010.0 3,504.7 0.00 84.0 23.0 Partly Cloudy WC E @ 8 MPH 14' Daily summary operation 24h Summary -- Complete to run 9 5/8"Csg-R/D Tesco tools-R/U cement head-Fill up Csg with LSND mud-R/U cementing equipments-Perform 9 5/8"Cement job-Cement in place @ 20:20 hrs-Injectivity test- R/D cement head-R/D Katch Kan-Prepare to Lift BOP stack. Operation at 07.00 Remove and lay down cap casing,and install Vetco Grey pack off Assy. 24h Forecast WOC-Lift BOP Stack-Set 9 5/8"Csg slip and cut 9/8'Csg-N/U BOP Stack-C/O rams-Cull out bad 5"DPs-P/U 4 1/2"DP. Lithology Shows MAASP Pressure(psi) Mud Weight(Iblgal) 9.30 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00:00 0400 4.00 400 DRILL G 4 P P/U 9 5/8"csg(409/L-80/Hydril 563/Special drift 8.75")Floating-RIH rotating 1/6,930'8/8,993'. Parameters:60-75 rpm @ 4.2k->5.5k ft•lbs-HKLD 50k->40k lbs-1/1.5 min/Jt-Av.MUT 13k ft'lbs. 04:00 06.00 2.00 6.00 DRILL G 5 P R/D Tesco tool and running equipment-M/U cement head and lines to 8119 5/8"csg with LSND mud. 06:00 11 00 5.00 11.00 DRILL G 9 P Fill 9 5/8"csg with 9.4 ppg LSND mud bleeding air through choke.Stop and bleed off air at 1/2 way full,3/4 full and 50 bbls shy of full.Filled at 660 bbls. 11:00 17.30 6.50 17.50 DRILL H 7 P Break circulation @ 1/2 bpm and stage rate up(1 bbl/min every 10 minutes)to 8 bpm @ 485 psi w/no losses.Condition mud for cement job(8 bpm @ 500 psi)Final YP=17 MW=9.4 ppg. 17-30 20.30 3.00 20.50 DRILL H 9 P Held PJSM-SLB pump 5 bbls Mud Push and test lines to 1000/3500 psi+SLB pump 95 bbls Mud Push @ 10.5 ppg(5 bpm @ 340 psi)-Drop Bottom Plug-SLB mix and pump 212 bbls Slurry @ 12.5 ppg[LiteCrete 758 sacks,1.57 Yield,mix fluid 5.494 gallsk](5 bpm @ 700 psi)-Drop Top Plug-SLB pump 10 bbls water-Switch to Rig Pump and Displace with 665 bbls mud @ 9.4 ppg(8 bpm @ 450->890 psi)-Bump plug @ 20:30-Pressure up casing to 1060 psi(500 psi over FCP)-Release pressure and check float equipment Ok-No losses during cement job. [Shoe @ 8,993'MD(3,516'TVD)-Collar @ 8,906'MD] 20-30 21:00 0.50 21,00 DRILL H 9 P Perform 20 bbls injectivity test down 13 3/8"x 9 5/8"ann.(1.5 bpm(g')max pressure 450 psi)-Bleed back 1.6 bbls. 21:00 22:00 1.00 22.00 DRILL H 5 P W.O.C.-R/D cement head.UD casing slips and elevator. 22:00 00.00 2.00 24.00 DRILL C 1 P W.O.C.-Drain stack-RIH x1 Std 5"DP and displace 9 5/8"casing-Blow down lines-R/D Katch Kan-Prepare cellar to lift BOP Stack Daily Contacts Position Contact Name Company Tide E-mail Office Mobile Eni representative i Ben Perry Eni Petroleum Sr.Ddg.Spvr. 907-685-1493 Eni representative Angelo Lamarina Eni Petroleum DrIg Spvr. angelo.lamarina@enipetroleum.com 907-685-1493 907-903-7269 Eni representative Mitch Billington Eni Petroleum Rig Clerk 907.670-8601 Eni representative Steve Abbott Eni Petroleum Material Coordinator 907-685-1491 907-715-0740 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(ftKB) Bottom(ftKB) Run Date CASING 9 5/8 8.835 L80 0.0 8,993.0 5/20/2012 Last Leakoff Test Depth(ftKB) TVD(f1KB) Fluid Type Fluid Density(Iblgal) P Surf Applied(psi) Eq.Mud Weight(lb/gal) Leak Off Pressure(psi) 2413.0 2 123.64 LSND mud @ 9.2 ppg 9.30 377.0 12.72 1.403.0 Ili* Eni E&P Division I Well Name:0124-08 ENI Petroleum Co.Inc. Daily Report Well Code:26154 Field Name: Nikatchuq � API/UWI:50-029-23457-00-00 2^n Date:5/22/2012 - Report#: 21 II II�I page 1 of 1 Wellbore name: 0124-08 Well Header Permit/Concession N° Operator ENI Share(%) Well Configuration type 402100 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(ft) Ground Level(ft) Water Depth(ft) RKB-Base Flange(ft) RKB-Tubing Spool(ft) 53.15 12.20 0.00 36.96 Rig Information Contractor Rig Name Rig Type NABORS ALASKA NABORS 245 E LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(ftKB) Target Depth(ND...Depth Dr.(MD)(ft) Drilling Hours(hr) Avg ROP(ft/hr) DFS(days) 0124-08 DRILLING 5/8/2012 18,666.0 18.510.00 176.23 105.0 14.33 Daily Information End Depth(ftKB) End Depth(TVD)(1.. Depth Progress(ft) Drilling Hours(hr) Avg ROP(ft/hr) POB Temperature(°F) Weather Wind 9,010.0 3,504.7 0.00 81.0 82.4 Freezing Fog WC 18° ENE @ 13 MPH Daily summary operation 24h Summary WOC-Lift BOP Stack-Set 9 5/8"Csg slip(100k lbs on slips)and cut 9/8"Csg-Install packoff assy and test:Ok-N/U BOP Stack-C/O rams-Pressure test casing to 3000 psi as per AOGCC requirements-Cull out bad 5"DPs-P/U stands of good 5"DP. Operation at 07.00 P/U,M/U and R/B stands of good 5"DP and stands of 4 1/2"DP. 24h Forecast P/U,M/U and R/B stands of good 5"DP and stands of 4 1/2"DP-Perform BOP test as per AOGCC requirements with 5"and 4 1/2"test joint. Lithology Shows MAASP Pressure(psi) Mud Weight(lb/gal) 9.30 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 C 1 P W.O.C.-Finish to R/D Katch Kan-L/D mouse hole-Hookup lifting cylinders and secondary slings-Prepare to lift BOP Stack. 02:00 06.00 4.00 6.00 DRILL C 5 P Raise BOP stack and Multi Bowl-Pull 9 5/8"csg to 150k 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 15 min:Ok. 06:00 10.30 4.50 10.50 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.Change out top rams from 9 5/8"to 4 1/2"x7"VBR. 10:30 11 30 1.00 11.50 DRILL E 12 P R/U lines and test 9 5/8"casing against blind rams to 3,000 psi and chart for 30 minutes as per AOGCC requirements:Ok. 11:30 12:30 1.00 12.50 DRILL E 5 P Install wear ring ID=9 1/8"-L/D running tool-Install mouse hole.C/O elevators. 12:30 14.30 2.00 14.50 DRILL E 9 P TIH w/5"DP,cull bad hardband joints and replace with good 5"DP.Freeze protect 13 3/8"x 9 5/8"annulus w/145 bbls diesel(2 bpm©600-c825 psi). Note:At 13:00 performed safety inspection.Removed ice build up in derrick. 14:30 15:30 1.00 15.50 DRILL E 4 P Continue RIH with stands 5"DP to 4,660'. 15:30 21:30 6.00 21.50'DRILL E 5 P POOH and L/D 5"DP with worn hard bands.112 ds culled. 21:30 00:00 2.50 24.00 DRILL E 5 P P/U,M/U&R/B x12 stands of good 5"DP. Daily Contacts Position Contact Name Company Title E-mail Office Mobile Eni representative Ben Perry Eni Petroleum Sr.Ddg.Spur. 907-685-1493 Eni representative Angelo Lamarina Eni Petroleum Dr1g Spvr. angelo.lamarina@enipetroleum.com 907-685-1493 907-903-7269 Eni representative Mitch Billington Eni Petroleum Rig Clerk 907-670-8601 Eni representative Steve Abbott Eni Petroleum Material Coordinator 907-685-1491 907-715-0740 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 Mum Turcone Nabors Alaska Drilling Tour Pusher 907-670-1492 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(ftKB) Bottom(ftKB) Run Date CASING 9 5/8 8.835 L80 0.0 8,993.0 5/20/2012 Last Leakoff Test Depth(ftKB) ND(ftKB) Fluid Type Fluid Density(Ib/gal) P Surf Applied(psi) Eq.Mud Weight(lb/gal) Leak Off Pressure(psi) 2,413.0 2,123.64 LSND mud @ 9.2 ppg 9.30 377.0 12.72 1,403.0 1191* Eni E&P DivisionWell Name:0124-08 ENI Petroleum Co.Inc. Daily Report Well Code:26154 Field Name:Nikatchuq • API/UWI:50-029-23457-00-00 2�,r, Date:5/23/2012 - Report#: 22 If II�I page 1 of 1 Wellbore name: 0124-08 Well Header Permit/Concession N° Operator ENI Share(%) Well Configuration type 402100 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(ft) Ground Level(ft) Water Depth(ft) RKB-Base Flange(ft) RKB-Tubing Spool(ft) 53.15 12.20 0.00 36.96 Rig Information Contractor Rig Name Rig Type NABORS ALASKA NABORS 245 E LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(ftKB) Target Depth(TVD...Depth Dr.(MD)(it) Drilling Hours(hr) Avg ROP(ft/hr) DFS(days) 0124-08 DRILLING 5/8/2012 18.666.0 18,510.00 176.23 105.0 15.33 Daily Information End Depth(ftKB) End Depth(TVD)(f.. Depth Progress(ft) Drilling Hours(hr) Avg ROP(ft/hr) POB Temperature(°F) Weather Wind 9,010.0 3,504.7 0.00 80.0 27.0 Overcast WC 18° EAST @ 8 MPH • Daily summary operation 24h Summary P/U 5"DPs Jt and M/U Std-BOP test-P/U 4 14"DPs Jt and M/U Std Operation at 07.00 TIH picking up 4 V:"DPs Jt at 5832' 24h Forecast Complete to P/U and M/U in Std 4.4"DPs-P/U BHA#5-RIH BHA#5 picking up 4'A"DPs until 13 3/8"Shoe-RIH BHA#5 w/4 14"DPs Std,logging CBL until landing collar-9 5/8"Casing pressure test -Displace to new Oil based reservoir drilling fluid-Drill out float equipment and cement-Drill 20'8%"hole-FIT-Drill 8'/."section as per well plan Lithology Shows MAASP Pressure(psi) Mud Weight(Ib/gal) 9.30 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 E 25 P TDS and change oil-Load DPs Jt in the shed 02 30 10:00 7.50 10.00'DRILL E 5 P P/U and RIH 5"DPs Jt 5/3541'-POOH and SLM 5"DPs Std 10.00 12:30 2.50 12.50 DRILL E 5 -P C/O handling equipment-P/U and RIH 4%"DPs Jt 5/500'-POOH and SLM 4%"DPs Std 12.30 14:00 1,50 14.00 DRILL C 5 P Pull wear ring-Set test plug-WU test Jt and fill BOP stack and choke with water 14:00 14:30 0.50 14.50-DRILL E 25 P Safety inspection:remove ice build up in derrick 14.30 19:00 4.50 19.00'DRILL C 12 P Test BOP as per AOGCC requirements w4 5"and 4%"test Jt-Annular @ 250?2500 psi-Rams,choke manifold,floor and top drive valves @ 250?3500 psi-Chart record-BOP test witnessed by AOGCC rep.John Crisp NOTE: Two week interval time will not start until the start of drilling out cement from the 9 5/8"casing as per AOGCC 19:00 20.00 1.00 20.00'DRILL C 5 P Pull test plug-Set wear nng-R/D testing equipment 20:00 00.00 4.00 24.00'DRILL E 5 P M/U mule shoe and TIH picking up 4'/:"DPs JI 5/2680' Daily Contacts Position Contact Name Company Title Email _ Office Mobile Eni representative 'Ben Perry Eni Petroleum 'Sr.Drlg.Spur. 907-685-1493 Eni representative Mirko Musumeci Eni Petroleum Drtg Spur. 907-685-1493 907-903-7269 Eni representative Mitch Billington Eni Petroleum Rig Clerk 907-670-8601 Eni representative Ken Bogner Eni Petroleum Material Coordinator Eni representative Steve Millea 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 Toby Bordelon Nabors Alaska Drilling Tour Pusher 907-670-1492 Last Casing seat Can.Type OD(in) ID(in) Grade Top(ftKB) Bottom(ftKB) Run Date CASING 9 5/8 8.835 L80 0.0 8,993.0 5/20/2012 Last Leakoff Test Depth(ftKB) TVD(ftKB) Fluid Type Fluid Density(Ib/gal) P Surf Applied(psi) Eq.Mud Weight(Ib/gal) Leak Off Pressure(psi) 2,413.0 2,123.64 LSND mud @ 9.2 ppg 9.30 377.0 12.72 1,403.0 Eni E&P Division (Well Name:004-08 1/191* ENI Petroleum Co.Inc. Daily Report Well Code:26154 Field Name:Nikatchuq • API/UWI:50-029-23457-00-00 2 II^ Date:5/24/2012 - Report#: 23 II II„ page 1 of 1 Wellbore name: 0124-08 Well Header Permit/Concession N° Operator ENI Share(%) Well Configuration type 402100 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(ft) Ground Level(ft) Water Depth(ft) RKB-Base Flange(ft) RKB-Tubing Spool(ft) 53.15 12.20 0.00 36.96 Rig Information Contractor Rig Name Rig Type NABORS ALASKA NABORS 245 E LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(ftKB) Target Depth(TVD...Depth Dr.(MD)(ft) Drilling Hours(hr) Avg ROP(ft/hr) DFS(days) 0124-08 DRILLING 5/8/2012 18.666.0 18,510.00 176.23 105.0 16.33 Daily Information End Depth(ftKB) End Depth(TVD)(f.. Depth Progress(ft) Drilling Hours(hr) Avg ROP(ft/hr) POB Temperature(°F) Weather Wind _ 9,010.0 3,504.7 0.00 80.0 28.0 Overcast WC 28° WIND @ 0 MPH Daily summary operation 24h Summary Complete to P/U and M/U in Std 4 W DPs-P/U BHA#5-RIH BHA#5 logging CBL Operation 1107.00 RIH BHA#5 logging CBL @ 4,710' 24h Forecast RIH BHA#5 logging CBL until landing collar-Displace to new Oil based reservoir drilling fluid-Drill out float equipment and cement-Drill 20'of 8'/°"hole-FIT-Drill 8'/°"section as per well plan Lithology Shows MAASP Pressure(psi) Mud Weight(Ib/gal) 9.30 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 4%"DPs Jt f/2680'V6656' 05:00 06:00 1.00 6.00 DRILL E 4 P Flush pipes pumping string volume-Blow down TDS-POOH and rack back 4''A"DP(/6656'1/5896' 06:00 07:00 1.00 7.00 DRILL E 25 TR99 Troubleshoot:Repair broken skate scissor arm 07:00 10.00 3.00 10.00 DRILL E 4 P POOH and rack back 4'A"DP 1/5896'1/1235' 10:00 13:30 3.50 13.50 DRILL E 5 P TIH picking up 4 W DPs Jt(/1235'1/3420' 13:30 16:00 2.50 16.00 DRILL E 4 P POOH and rack back 4''A"DP-L/D mule shoe 16:00 21:00 5.00 21.00 DRILL E 5 P P/U and M/U BHA#5[Bit 8%"Huges 0D506X TFA:0.882(s/n 7133191)+Xceed+Periscope+Telescope+NM stab+ Sonic+ADN+Hi Tool+NM stab+x3 NM Flex DC+Float Sub+6'/:"Jar WTF(s/n 1416-1505)+x2 HWDP 5"+XO]- Shallow test-RIH wl 4'A"DPs V1500' 21:00 00:00 3.00 24.00 DRILL J 11 P RIH w/4''4"DPs f/1500'112894'logging cement bong(speed controlled @ 900 fph)-Fill pipe every 2000' Daily Contacts • Position Contact Name Company Title E-mail Office Mobile Eni representative -Ben Perry Eni Petroleum Sr.Ddg.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 Ken Bogner Eni Petroleum Material Coordinator • Eni representative Steve Millea 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 Toby Bordelon Nabors Alaska Drilling Tour Pusher 907-670-1492 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(ftKB) Bottom(ftKB) Run Date CASING 9 5/8 8.835 L80 0.0 8,993.0 5/20/2012 Last Leakoff Test • Depth(ftKB) TVD(ftKB) Fluid Type Fluid Density(Ib/gal) P Surf Applied(psi) Eq.Mud Weight(Iblgal) Leak Off Pressure(psi) 2,413.0 2,123.64 LSND mud @ 9.2 ppg 9.30 377.0 12.72 1,403.0 Eni E&P Division 'Wen Name:0124-08 ft* EN!Petroleum Co.Inc. Daily Report Well Code:26154 Field Name:Nikatchuq • Date:5/25/2012 - Report#: 24 APIIUWI:50-029-23457-00-00 2" " page 1 of 1 Wellbore name: 0124-08 Well Header Permit/Concession N° Operator ENI Share(%) Well Configuration type 402100 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(ft) Ground Level(ft) Water Depth(ft) RKB-Base Flange(ft) RKB-Tubing Spool(ft) 53.15 12.20 0.00 36.96 Rig Information Contractor Rig Name Rig Type NABORS ALASKA NABORS 245 E LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(ftKB) Target Depth(TVD...Depth Dr.(MD)(ft) Drilling Hours(hr) Avg ROP(ft/hr) DFS(days) 0124-08 DRILLING 5/8/2012 18,666.0 18,510.00 176.23 105.0 17.33 Daily Information End Depth(ftKB) End Depth(TVD)(f.. Depth Progress(ft) Drilling Hours(hr) Avg ROP(ft/hr) POB Temperature(°F) Weather Wind 9,010.0 3,504.7 0.00 80.0 30.0 Overcast WC 23° NNE @ 8 MPH Daily summary operation 24h Summary RIH BHA#5 logging CBL until landing collar-Displace to new Oil based reservoir drilling fluid-Drill out float equipment and cement Operation at 07.00 Drill 8'"section as per well plan to 9035' 24h Forecast Drill 20'of 8%"hole-Circuulate B/U-FIT-Drill 8'"section as per well plan Lithology Shows MAASP Pressure(psi) Mud Weight(lb/gal) 9.20 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00:00 12:00 12.00 12.00 DRILL J -11 P RIH w/4 1/"DPs f/2694'1/8896'(Tag cement)logging cement bong(speed controlled @ 900 fph)-Fill pipe every 2000'(Up wt 130k lbs/Dw wt 75k lbs) 12:00 '15:00 3.00 15.00 DRILL E 9 P Displace well to new FazePro 9.2 ppg OBM pumping 50 bbl HiVisc spacer followed by 9.2 ppg OBM,reciprocating and rotating string(280 gpm @ 1200 psi,35 rpm) 15:00 -19:00 ' 4.00 19.00 DRILL E '20 P Clean shakers and trough pits-Cut and slip 95'DL-Inspect and adjust breaks 19:00 00:00 5.00 24.00 DRILL E 6 P Drill out float collar and cement 1/8896'1/9000'(450 gpm @ 2200 psi,50 rpm @ 9-13k bibs) NOTE: BOP test time start @ 19:30 as per AOGCC 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 Spar. 907-685-1493 907-903-7269 Eni representative Mitch Billington Eni Petroleum Rig Clerk 907-670-8601 Eni representative Ken Bogner Eni Petroleum Material Coordinator Eni representative Steve Millea 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 Toby Bordelon Nabors Alaska Drilling Tour Pusher 907-670-1492 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(ftKB) Bottom(ftKB) Run Date CASING 9 5/8 8.835 L80 0.0 8,993.0 5/20/2012 Last Leakoff Test Depth(ftKB) TVD(ftKB) Fluid Type Fluid Density(lb/gal) P Surf Applied(psi) Eq.Mud Weight(Ib/gal) Leak Off Pressure(psi) 2,413.0 2,123.64 LSND mud @ 9.2 ppg 9.30 377.0 12.72 1,403.0 ` _� Eni E&P DivisionENI Petroleum Co.visionI Well Name:0124-08 1 14 aily Report Well Code:26154 Tl�� Field Name: Nikatchuq •'^� Date:5/26/2012 - Report#: 25 API/UWI:50-029-23457-00-00 r' i o page 1 of 1 Wellbore name: 0124-08 Well Header Permit/Concession N° Operator ENI Share(o) Well Configuration type 402100 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(ft) Ground Level(ft) Water Depth(ft) RKB-Base Flange(ft) RKB-Tubing Spool(ft) 53.15 12.20 0.00 36.96 Rig Information Contractor Rig Name Rig Type NABORS ALASKA NABORS 245 E LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(ftKB) Target Depth(TVD..,Depth Dr.(MD)(ft) Drilling Hours(hr) Avg ROP(ft/hr) DFS(days) 0124-00 DRILLING 5/8/2012 18.666,0 18,510.00 176.23 105.0 18.33 Daily Information End Depth(ftKB) End Depth(TVD)(f...Depth Progress(ft) Drilling Hours(hr) Avg ROP(ft/hr) POB Temperature(°F) Weather Wind 10,128.0 3,472.6 1,118.00 13.97 80.0 80.0 28.0 Snow Frzg Fog WC NE @ 13 MPH 18' Daily summary operation 24h Summary Drill 20'of 8'h"hole-Circuulate B/U-FIT-Drill 8%"section as per well plan to 10031' Operation at 07,00 Drill 8'/."section as per well plan @ 10,205' 24h Forecast Drill 8°%"section as per well plan(planned TD @ 18670') Lithology Shows MAASP Pressure(psi) Mud Weight(Ib/gal) 9.20 • 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 P Service rig:Adjust breaks on draw works 01 00 0300 2.00 3.00'DRILL E 6 P Drill out shoe and cement f/9000'59010'(500 gpm @ 2650 psi,50 rpm @ 6+7k ft-lbs,WOB=2-8k lbs,MW=9.2 ppg)-Drill rotary 0 8%"new hole V9010'1/90301(500 gpm @ 2650 psi,50 rpm @ 6,7k ft lbs,WOB=2*8k lbs,MW=9.2 ppg)- Circulate B/U(500 gpm(§2650 psi)-POOH into shoe 03:00 03.30 0.50 3.50 DRILL E 11 P B/D TD-Rig up lines and perform LOT with 9.2 ppg FazePro OBM-Surface pressure of 654 psi-EMW=12.8 ppg-R/D test equipment 03:30 12'.00 8.50 12.00 DRILL E 3 P Drilling steerable 0 8%"section 1/9030'f/9239'1 5007550 gpm @ 2650?3000 psi\80.120 rpm @ 10.11k Ribs\WOB= 5*17k lb\Up v4 118k lb-Dn wt 62k lb-Rot w4 90k lb\Mud wt 9.2 ppg 12:00 17.00 5.00 17.00 DRILL E 3 P Drilling steerable 0 8%"section V9239'1/9660'1 550 gpm @ 300073050 psi\80+120 rpm @ 10=13k Ribs\WOB=10-20k lb\Up wt 145k lb-Dn wt 70k lb-Rot wt 92k lb\Mud wt 9.2 ppg 17.00 20.00 3.00 20.00 DRILL E 6 P BROOH and rack back x9 Std 5"DPs f/9660'1/87821(550 gpm @ 3000 psi.120 rpm @ 8.9k Rubs)-RIH x9 Std 4 14"DPs (/8782'59660'-WU XO NC50xNC46 20:00 0000 4.00 24.00 DRILL E 3 P Drilling steerable 0 8%"section f/9660'510031'1550 gpm @ 305073200 psi\120 rpm @ 9*13k ft'lbs\WOB=5.18k Ib\ Up wt 145k lb-Dn ail 70k lb-Rot w1 90k lb\Mud wt 9.2 ppg (ADT=5.46 Hrs-JARS=12.8 Hrs] I Daily Contacts PositionContact Name Company Title E-mail Office Mobile Eni representative Ben Perry Eni Petroleum Sr.DrIg.Spar. 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 Ken Bogner Eni Petroleum Material Coordinator f Eni representative Steve Millea 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 Toby Bordelon Nabors Alaska Drilling Tour Pusher 907-670-1492 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(ftKB) Bottom(ftKB) Run Date CASING 9 5/8 8.835 L80 0.0 8.993.0 5/20/2012 Last Leakoff Test Depth(ftKB) TVD(ftKB) Fluid Type Fluid Density(Ib/gal) P Surf Applied(psi) Eq.Mud Weight(lb/gal) Leak Off Pressure(psi) 2.413.0 2,123.64 LSND mud @ 9.2 ppg 9.30 377,0 12.72 1.403.0 • Eni E&P Division I Well Name:0124-08 01* ENI Petroleum Co.Inc. Daily Report Well Code:26154 Field Name:Nikatchuq • Date:5/27/2012 - Report#: 26 API/MI: 50-029-23457-00-00 2" " page 1 of 1 Wellbore name: 0124-08 Well Header Permit/Concession N. Operator ENI Share(%) Well Configuration type 402100 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(ft) Ground Level(ft) Water Depth(ft) RKB-Base Flange(ft) RKB-Tubing Spool(ft) 53.15 12.20 0.00 36.96 Rig Information Contractor Rig Name Rig Type NABORS ALASKA NABORS 245E LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(ftKB) Target Depth(TVD...Depth Dr.(MD)(ft) Drilling Hours(hr) Avg ROP(ft/hr) DFS(days) 0124-08 DRILLING 5/8/2012 18,666.0 18,510.00 176.23 105.0 19.33 Daily Information End Depth(ftKB) End Depth(TVD)(f.. Depth Progress(ft) Drilling Hours(hr) Avg ROP(ft/hr) POB Temperature(°F) Weather Wind 11,946.0 3.536.2 1,818.00 14.49 125.5 80.0 25.0 Overcast WC 19° NW @ 5 MPH Daily summary operation 24h Summary 8 V."section as per well plan from 10031'to 11945' Operation at 07.00 Drill 8 Y."section as per well plan @ 12,320' 24h Forecast Drill 8%"section as per well plan(planned TD @ 18670') Lithology Shows MAASP Pressure(psi) Mud Weight(lb/gal) 9.20 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 steerable 0 8'/"section(/10031'V10314'1550 gpm @ 3200 psi\80+140 rpm @ 10+15k ft'lbs\WOB 5+20k lb\ Up wt 145k lb-Dn wt 60k lb-Rot wt 92k lb\Mud wt 9.2 ppg\Hard spot 10200'+10209' • 06:00 '12E0 ' 6.00 12.00'DRILL E 3 P Drilling steerable 0 8%"section f/10314'1/10800'1550 gpm @ 3200 psi\140 rpm @ 13+15k ft'lbs\WOB 10+20k lb\Up wt 145k lb-Dn wt 60k lb-Rot wt 92k lb\Mud wt 9.2 ppg 12-.00 18:00 6.00 18.00 DRILL E 3 P 'Drilling steerable 0 8%"section f/10800'1111370'1550 gpm @ 3200 psi\100+140 rpm @ 13+17k fobs\WOB 5-05k lb\ Up wt 145k lb-Dn wt 60k lb-Rot wt 92k lb\Mud wt 9.2+ppg\Hard spot 11060'+11067' 18 00 00:00 6.00 24.00 DRILL E 3 P Drilling steerable 0 8%"section f/11370'811945'1550 gpm @ 3200?3250 psi\100+140 rpm @ 11+16k ftdbs I WOB 5+20k lb\Up w1145k lb-Dn wt 60k lb-Rot wt 92k lb 1 Mud wt 9.2+ppg [ADT=15.33 Hrs-JARs=28.13 Hrs] Daily Contacts Position Contact Name Company _ Title E-mail Office 1 Mobile Eni representative Ben Perry Eni Petroleum Sr.Drag.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 Ken Bogner Eni Petroleum Material Coordinator Eni representative Steve Millea 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 Toby Bordelon Nabors Alaska Dnlling Tour Pusher 907-670-1492 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(RKB) Bottom(ftKB) Run Date CASING 9 5/8 8.835 L80 0.0 8,993.0 5/20/2012 Last Leakoff Test Depth(RKB) TVD(ftKB) Fluid Type Fluid Density(Iblgal) P Surf Applied(psi) Eq.Mud Weight(Ib/gal) Leak Off Pressure(psi) 2,413.0 2,123.64 LSND mud @ 9.2 ppg 9.30 377.0 12.72 1,4030 ii Eni E&P Division I Well Name:0124-08 ENI Petroleum Co.Inc. Daily Report Well Code:26154 Field Name: Nikatchuq • API/U1A/1 50-029-23457-00-00 2^r,II Date:5128/2012 - Report#: 27 'f II page 1 of 1 wellbore name: 0124-08 Well Header Permit/Concession N° Operator ENI Share(%) Well Configuration type 402100 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(ft) Ground Level(ft) Water Depth(ft) RKB-Base Flange(ft) RKB-Tubing Spool(ft) 53.15 12.20 0.00 36.96 Rig Information Contractor Rig Name Rig Type NABORS ALASKA NABORS 245 E LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(ftKB) Target Depth(TVD...Depth Dr.(MD)(ft) Drilling Hours(hr) Avg ROP(ft/hr) DFS(days) 0124-08 DRILLING 5/8/2012 18,666.0 18,510.00 176.23 105.0 20.33 Daily Information End Depth(ftKB) End Depth(TVD)(f..,Depth Progress(ft) Drilling Hours(hr) Avg ROP(ft/hr) POB Temperature(°F) Weather Wind 13,861.0 3,509.5 1.915.00 18.34 104.4 80.0 27.0 Light Snow Mist WC ENE @ 10 MPH 17` Daily summary operation 24h Summary 8'/"section as per well plan from 11945'to 13760' Operation at 07.00 Drill 8'/."section as per well plan @ 14,052' 24h Forecast Drill 8'/."section as per well plan(planned TD @ 18670') Lithology Shows MAASP Pressure(psi) Mud Weight(Iblgal) 9.20 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 Dolling steerable 0 8%"section 8/11945'5/12520'\550 gpm @ 3250 psi\140 rpm @ 10+17k('lbs\WOB 10+20k lb\Up wl 160k lb-No S/0-Rot wt 100k lb\Mud wt 9.2 ppg 06:00 12:00 6.00° 12.00 DRILL E 3 P Dolling steerable 0 8%"section f/12520'5/12660'\550 gpm @ 3250 psi\60+140 rpm @ 9+14k fflbs I WOB 10+20k Ib\ Up wt 160k lb-No S/O-Rot wt 100k Ib\Mud w4 9.2 ppg\Hard spot 12571'.12593',12683'+12660' 12:00 18:00 6.00 18.00 DRILL E 3 P Drilling steerable 0 8•%"section t/12660'813186'1550 gpm @ 3250?3400 psi\80+140 rpm @ 11+17k fldbs\WOB 10+20k lb\Up wt 165k lb-NoS/0-Rot wt 95k lb I Mud w19.2 ppg 18:00 00:00 6.00• 24.00 DRILL •E 3 P Drilling steerable 0 8%"section(/13186'5/13760'\550 gpm @ 340073500 psi\80+140 rpm @ 10+19k 9-lbs\WOB 10+20k lb\Up wit 165k lb-NoS/0-Rot wt 95k lb I Mud wt 9.2 ppg .(ADT=17.65 Hrs-JARs=45.8 Hrs) 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 Mitch Billington Em Petroleum Rig Clerk 907-670-8601 Eni representative Ken Bogner Em Petroleum Material Coordinator Em representative Steve Millea ENI Petroleum HSE 907-685-1496 Eni representative Greg Parker Em Petroleum Expediter 907-980-7545 Tool Push Mike Williams Nabors Alaska Drilling Tool Pusher 907-670-1492 Tool Push Toby Bordelon Nabors Alaska Drilling Tour Pusher 907-670-1492 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(ftKB) Bottom(ftKB) Run Date CASING 9 5/8 8.835 L80 0.0 8,993.0 5/20/2012 Last Leakoff Test Depth(ftKB) TVD(ftKB) Fluid Type Fluid Density(Ib/gal) P Surf Applied(psi) Eq.Mud Weight(Ib/gal) Leak Off Pressure(psi) 2,413.0 2,123.64 LSND mud©9.2 ppg 9.30 377.0 12.72 1,403.0 Eni E&P Division [Well Name:0124-08 Y� ENI Petroleum Co.Inc. Daily Report Well Code:26154 Field Name: Nikatchuq e APIIUWI:50-029-23457-00-00 2nII n Date:5/29/2012 - Report#: 28 II II page 1 of 1 Wellbore name: 0124-08 Well Header Permit/Concession N° Operator ENI Share(%( Well Configuration type 402100 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(ft) Ground Level(ft) Water Depth(ft) RKB-Base Flange(ft) RKB-Tubing Spool(ft) 53.15 12.20 0.00 36.96 Rig Information Contractor Rig Name Rig Type NABORS ALASKA NABORS 245 E LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(ftKB) Target Depth(TVD...Depth Dr.(MD)(ft) Drilling Hours(hr) Avg ROP(ft/hr) DFS(days) 0124-08 DRILLING 5/8/2012 18,666.0 18,510.00 176.23 105.0 21.33 Daily Information End Depth(ftKB) End Depth(TVD)(f.. Depth Progress(ft) Drilling Hours(hr) Avg ROP(ft/hr) POB Temperature(°F) Weather Wind 15 325.0 3,494.9 1.464.00 10.25 142.8 80.0 30.0 Freezing Raining NE @ 14 MPH Mist WC 20' Daily summary operation 24h Summary 8'/"section as per well plan from 13760'to 15330'-Repeat section log 13765',14052'-Start mud losses @ 13900'-Pump LCM pill as needed Operation at 07.00 Drill 8°/"section as per well plan @ 15,584 24h Forecast Drill 8%"section as per well plan(planned TD @ 18670') Lithology Shows MAASP Pressure(psi) Mud Weight(Ib/gal) 9.20 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00:00 04:00 I 4.00 4.00 DRILL E 3 'P Drilling steerable 0 6' 'section f/13760'V14050'\5507470 gpm @ 3500?2680 psi\120,140 rpm @ 10,13k ft lbs\WOB 5,20k lb\Up wt 145k lb-No S/0-Rot wt 100k lb I Mud WI 9.2 ppg NOTE: Unplanned fault @ 13840'-Start losing mud 2707100 bbVHrs @ flow rate 550?470 gpm-Build up LCM(10/7%250/40 SatcCarb) 04:00 07:00 3.00 7.00 DRILL E 11 'P BROOH(/14050'1/13765'(480 gpm @ 2820 psi,140 rpm @ 12k ftlbs)-RIH at 400 fph logging f/13765'1/14052'(470 gpm @ 2680 psi,80,120 rpm @ 10k 12k ft'lbs)-Pump 40 bbl LSM pill 07:00 12:00 5.00 12.00 DRILL E 3 -P Drilling steerable 0 8%"section f/14050't/14405'\470 gpm @ 268072700 psi\70,140 rpm @ 11,17k albs\WOB 5,20k lb\Up w4 155k lb-No S/0-Rot wt 100k lb\Mud wt 9.2 ppg-Hard spot 14385',14405'-Pumped LCM sweep as needed 12:00 18:00 6.00 18.00 DRILL E 3 'P Drilling steerable 0 8%"section(/14405'1/14866'\470 gpm @ 270072750 psi\120,140 rpm @ 14,19k Ribs\WOB 5,20k lb\Up v4 155k lb-No S/O-Rot wt 100k lb\Mud wt 9.2 ppg-Pumped LCM sweep as needed 18:00 00:00 6.00 24.00 DRILL E 3 •P Drilling steerable 0 8%"section(/14866'1/15330'\470 gpm @ 275072800 psi\120 rpm @ 15,19k ftdbs\WOB 5,20k lb\ Up wt 155k Ib-No S/O-Rot wt 100k lb\Mud wt 9.2 ppg-Hard spot 15085',15096'-Pumped LCM sweep as needed IADT=11.26 Hrs-JAR5=57.1 Hrs) NOTE: Daily losses 436 bbl Daily Contacts Position Contact Name Company Title E-mail Office Mobile Eni representative Ben Perry En:Petroleum 'Sr.Ddg.Spvr. 907-685-1493 Eni representative Mirka Musumeci Eni Petroleum Drtg Spvr. 907.685.1493 907-903-7269 Eni representative Ken Bogner Eni Petroleum Material Coordinator Eni representative Steve Millea 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 Toby Bordelon Nabors Alaska Dolling Tour Pusher 907-670-1492 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(ftKB) Bottom(ftKB) Run Date CASING 9 5/8 8.835 L80 0.0 8,993.0 5/20/2012 Last Leakoff Test Depth(RKB) TVD(ftKB) Fluid Type Fluid Density(11s/gal) P Surf Applied(psi) Eq.Mud Weight(Ib/gal) Leak Off Pressure(psi) 2,413.0 2,123.64 LSND mud @ 9.2 ppg 9.30 377.0 12.72 1.403.0 Eni E&P Division I Well a • r* ENI Petroleum Co.Inc. Daily Report Well CNomede::261540124-08 Field Name:Nikatchuq • APIIUWI:50-029-23457-00-00 2^n Date:5/30/2012 - Report#: 29 II l)ii page 1 of 1 Wellbore name: 0124-08 Well Header Permit/Concession N° Operator ENI Share(%) Well Configuration type 402100 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(ft) Ground Level(ft) Water Depth(ft) RKB-Base Flange(ft) RKB-Tubing Spool(ft) 53.15 12.20 0.00 36.96 Rig Information Contractor Rig Name Rig Type NABORS ALASKA NABORS 245 E LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(ftKB) Target Depth(TVD...Depth Dr.(MD)(ft) Drilling Hours(hr) Avg ROP(ft/hr) DFS(days) 0124-08 DRILLING 5/8/2012 18,666.0 18,510.00 176.23 105.0 22.33 Daily Information End Depth(RKB) End Depth(TVD)(f.. Depth Progress(ft) Drilling Hours(hr) Avg ROP(ft/hr) POB Temperature(°F) Weather Wind 16,924.0 3,429.7 1.599.00 14.88 107.5 80.0 28.0 Overcast WC 19' ENE @ 10 MPH Daily summary operation 14h Summary 8%"section as per well plan from 15330'to 16920' Operation at 07.00 Drill 8%"section as per well plan @ 17,150' 24h Forecast Drill 8%"section as per well plan(planned TD @ 18670') Lithology Shows MAASP Pressure(psi) Mud Weight(Ib/gal) 9.20 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 steerable 0 8%"section(/15330'515774'1470 gpm @ 2680?2850 psi 180.120 rpm @ 15*18k ftlbs I WOB 8*18k lb\Up wt 170k lb-No S/0-Rot wt 100k lb\Mud wt 9.2 ppg-Hard spot 15584'+15600' NOTE: Unplanned fauhed zone(/15280'515350' 06:00 13:00 7.00' 13.00 DRILL E 3 P Drilling steerable 0 8%"section 1/15774'1116032'1470 gpm @ 2850 psi 180+120 rpm©14*19k ftlbs\WOB 5*20k 15 1 Up wt 170615-No S/0-Rot wt 100k lb\Mud wt 9.2 ppg-Hard spot 16018'*16032'-Flow check 15 min/75 bbl back 13:00 18:00 5.00 18.00 DRILL E 3 P Drilling steerable 0 8%"section f/16032'1/16358'14707450 gpm @ 2850?2700 psi 180.120 rpm @ 15+20k ftlbs\WOB 5+20k lb\Up wt 175k lb-No S/0-Rot wt 95k lb\Mud wA 9.2 ppg ppg-Hard spot 16261'*16276' • 18:00 00:00 6.00' 24.00'DRILL E 3 P Drilling steerable 0 8%"section f/16358'1/16920'\450?470 gpm @ 2700?3050 psi 1120 rpm @ 17*20k ftlbs\WOB 5*20k lb\Up w1 175k lb-No 5/0-Rot wt 95k lb\Mud vA 9.2 ppg-Flow check 15 min/70 bbl back [ADT=14.88 Hrs-JAR s=71.9 Hrs-Daily losses 327 bbl) 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 Mirko Musumeci Eni Petroleum Ddg Spvr. 907-685-1493 907-903-7269 Eni representative Ken Bogner Eni Petroleum Material Coordinator Eni representative Steve Millea ENI Petroleum HSE 907-685-1496 Eni representative Greg Parker Eni Petroleum Expediter 907-980-7545 Tool Push Bruce Simonson Nabors Alaska Dolling Tool Pusher 907-670-1492 Tool Push Toby Bordelon Nabors Alaska Dulling Tour Pusher 907-670-1492 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(ftKB) Bottom(ftKB) Run Date CASING 9 5/8 8.835 L80 0.0 8,993.0 5/20/2012 Last Leakoff Test Depth(ftKB) TVD(ftKB) Fluid Type Fluid Density(Iblgal) P Surf Applied(psi) Eq.Mud Weight(Ib/gal) Leak Off Pressure(psi) 2,413.0 2,123.64 LSND mud @ 9.2 ppg 9.30 377.0 12.72 1.403.0 Eni E&P Divisionwell Name:0124-08 Iff* ENI Petroleum Co.Inc. Daily Report Well Code:26154 Field Name:Nikatchuq • APIIUWI:50-029-23457-00-00 2 n o Date:5/3112012 - Report#: 30 - If II page 1 of 1 Wellbore name: 0124-08 Well Header Permit/Concession N° Operator ENI Share(e) Well Configuration type 402100 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(ft) Ground Level(ft) Water Depth(ft) RKB-Base Flange(ft) RKB-Tubing Spool(ft) 53.15 12.20 0.00 36.96 Rig Information Contractor Rig Name Rig Type NABORS ALASKA NABORS 245 E LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(ftKB) Target Depth(TVD...Depth Dr.(MD)(ft) Drilling Hours(hr) Avg ROP(ft/hr) DFS(days) 0124-08 DRILLING 5/8/2012 18.666.0 18.510.00 176.23 105.0 23.33 Daily Information End Depth(ftKB) End Depth(TVD)(f.. Depth Progress(ft) Drilling Hours(hr) Avg ROP(ft/hr) POB Temperature(°F) Weather Wind 18,455.0 3,427.0 1.531.00 12.36 123.9 80.0 28.0 Overcast WC 22° NW @ 6 MPH Daily summary operation 24h Summary 8•V.."section as per well plan from 16920'10 18379' Operation at 07.00 Drill 8 G"section as per well plan to TD 18,646' 24h Forecast Drill 8'/."section as per well plan(planned TD @ 18670')-BROOH 1Std/BU for x 6 Std-BROOH 2Std/BU for x 6 Std-BROOH as per tripping schedule Lithology Shows MAASP Pressure(psi) Mud Weight(Ib/gal) 9.20 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00.00 0600 6.00 6.00 DRILL E 3 P Drilling steerable 0 8%"section(/16920'517257/4707460 gpm @ 3050?2950 psi/80.120 rpm @ 15.18k fHbs 1 WOB 15.20k lb\Up wt 182k lb-No 5/0-Rot wt 100k lb\Mud wt 9.2 ppg-Hard spot 17153'•17159' NOTE: Unplanned fault @ 17092' 06:00 12.00 6.00 12.00 DRILL E 3 P Drilling steerable 0 8'/."section f/17207'1/17593'1 460 gpm @ 2950 psi 180.120 rpm @ 16.21k Ribs\WOB 10.20k lb\ Up wt 182k lb-No S/0-Rot wt 100k lb\Mud wt 9.2 ppg-Hard spot 17582'•17587'-Flow check 15 min/90 bbl back 12:00 1800 6.00 18.00 DRILL I E 3 P Dolling steerable 0 8'"section(/17593'V17993'14607450 gpm @ 2950?2800 psi 1 120 rpm @ 18.20k ft'lbs\WOB 8.18k lb\Up wt 185k lb-Nos/0-Rot wt 97k lb\Mud vd 9.3 ppg NOTE. Unplanned fault @ 17732' 1800 00.00 6.00 24.00 DRILL E 3 P Dulling steerable 0 8%"section 8/17993'V18379'1 450 gpm @ 2800 psi\80.120 rpm @ 18-23k ft'Ibs 1 WOB 5.20k lb\ Up wt 185k lb-No S/0-Rot wt 97k lb\Mud vA 9.2 ppg-Flow check 15 min/85 bbl back-Pump LCM pill as needed (ADT=12.36 Hrs-JAR=84.29 Hrs-Daily losses 683 bbl] Daily Contacts Position Contact Name Company Title E-mail Office Mobile Eni representative Ben Perry Eni Petroleum Sr.Dug.Spur. 907-685-1493 Eni representative Mirko Musumeci Eni Petroleum Dug Spvr. 907-685-1493 907-903-7269 Eni representative Ken Bogner Eni Petroleum Material Coordinator Eni representative Steve Millea ENI Petroleum HSE 907-685-1496 Eni representative Greg Parker Eni Petroleum Expediter 907-980-7545 Tool Push Bruce Simonson Nabors Alaska Dulling Tool Pusher 907-670-1492 Tool Push Toby Bordelon Nabors Alaska Drilling Tour Pusher 907-670-1492 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(ftKB) Bottom(ftKB) Run Date CASING 95/8 8.835 L80 0.0 8,993.0 5/20/2012 Last Leakoff Test Depth(ftKB) ND(ftKB) Fluid Type Fluid Density(11,/gal) P Surf Applied(psi) Eq.Mud Weight(Ib/gal) Leak Off Pressure(psi) 2,413.0 2,123.64 LSND mud @ 9.2 ppg 9.30 377.0 12.72 1,403.0 1111* Eni E&P Division ..} !Well Name:0124-08 ENI Petroleum Co.Inc. Daily Repo Well Code:26154 Field Name: Nikatchuq • API/UWI:50-029-23457-00-00 2^n Date:6/1/2012 - Report#: 31 II II II page 1 of 1 Wellbore name: 0124-08 Well Header Permit/Concession N° Operator ENI Share(%) Well Configuration type 402100 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(ft) Ground Level(ft) Water Depth(ft) RKB-Base Flange(ft) RKB-Tubing Spool(ft) 53.15 12.20 0.00 36.96 Rig Information Contractor Rig Name Rig Type NABORS ALASKA NABORS 245E LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(f1KB) Target Depth(TVD...Depth Dr.(MD)(ft) Drilling Hours(hr) Avg ROP(fllhr) DFS(days) 0124-08 DRILLING 5/8/2012 18,666.0 18,510.00 176.23 105.0 24.33 Daily Information End Depth(RKB) End Depth(TVD)(f..,Depth Progress(ft) Drilling Hours(hr) Avg ROP(ft/hr) POB Temperature(°F) Weather Wind 18,670.0 3,423.0 215.00 2.19 98.2 79.0 31.0 Mosty Cloudy WC NE @ 9 MPH 23' Daily summary operation 24h Summary 8 Vr"section as per well plan from 18379'to TD(18670'MD-3429.7'TVD)-Clean up cycle-BROOH to 16560' Operation at 07.00 BROOH @ 15,280' 24h Forecast BROOH to 9 5/8"Shoe-Circulate hole clean-POOH on elevators Lithology Shows MAASP Pressure(psi) Mud Weight(lb/gal) 9.20 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 3 P Drilling steerable 0 8%"section(/18379'to TD(18670'MD-3429.7'TVD)\450 gpm @ 2800 psi\80.120 rpm @ 18.22k 8'lbs\WOB 5.15k lb\Up wt 182k Ib-No SIO-Rot wt 100k lb\Mud wt 9.3 ppg-Flow check 15 min/83 bbl back (ADT=2.19 Hrs-JAR=85.9 Firs] 04:30 '15:00 10.50 15.00 DRILL E 7 P Clean up cycle:Circulate x6 BU(400?430 gpm @ 235072600 psi-120 rpm @ 18?21k ft-lbs)Rack back 01 Std each BU (/18670'517970" 15.00 22:30 7.50' 22.50 DRILL E 7 P Clean up cycle:Circulate x6 BU(430?450 gpm @ 2600?2700 psi-120 rpm @ 16719k ft-lbs)Rack back x2 Std each BU f/17970'016917' 22:30 00:00 1.50 24.00-DRILL -E 6 P BROOH(116917'516560'(450 gpm @ 2700?2550 psi-120 rpm @ 16715k ft'lbs-10 min/Std) [Daily losses 642 bbl] Daily Contacts Position Contact Name Company Title E-mail Office Mobile Eni representative Ben Perry Eni Petroleum -Sr.Drip.Spvr. 907-685-1493 Eni representative Mirko Musumeci Eni Petroleum Drlg Spvr. 907-685-1493 907-903-7269 Eni representative Ken Bogner Eni Petroleum Material Coordinator Eni representative Steve Millea ENI Petroleum HSE 907-685-1496 Eni representative Greg Parker Eni Petroleum Expediter 907-980-7545 Tool Push Bruce Simonson Nabors Alaska Drilling Tool Pusher 907-670-1492 Tool Push Toby Bordelon Nabors Alaska Drilling Tour Pusher 907-670-1492 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(RKB) Bottom(ftKB) Run Date CASING 9 5/8 8.835 L80 0.0 8,993.0 5/20/2012 Last Leakoff Test Depth(RKB) TVD(f1KB) Fluid Type Fluid Density(Ib/gal) P Surf Applied(psi) Eq.Mud Weight(Iblgal) Leak Off Pressure(psi) 2,413.0 2,123.64 LSND mud @ 9.2 ppg 9.30 377.0 12.72 1,403.0 Eni E&P Division a . cf* ENI Petroleum Co.Inc. Daily Report Well Code:26154 Field Name: Nikatchuq • API/UWI:50-029-23457-00-00 2 Date:6/2/2012 - Report#: 32 if l� page 1 of 1 Wellbore name 0124-08 Well Header Permit/Concession N° Operator ENI Share)%) Well Configuration type 402100 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(ft) Ground Level(ft) Water Depth(ft) RKB-Base Flange(ft) RKB-Tubing Spool(ft) 53.15 12.20 0.00 36.96 Rig Information • Contractor Rig Name Rig Type NABORS ALASKA NABORS 245 E LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(ftKB) Target Depth(ND...Depth Dr.(MD)(ft) Drilling Hours(hr) Avg ROP(ft/hr) DFS(days) 0124-08 DRILLING 5/8/2012 18,666.0 18,510.00 176.23 105.0 25.33 Daily Information End Depth(ftKB) End Depth(TVD)(f.. Depth Progress(ft) Drilling Hours(hr) Avg ROP(ft/hr) POB Temperature(°F) Weather Wind 18,670.0 3,423.0 0.00 79.0 31.0 Overcast WC 21' East @ 13 MPH Daily summary operation 24h Summary BROOH t/16560'08220' Operation at 07.00 BROOH @ 6.074' 14h Forecast BROOH to 4500'-POOH on elevators-UD BHA#5-P/U BHA#6 and RIH Lithology Shows MAASP Pressure(psi) Mud Weight(lb/gal) 9.20 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00,00 19,30 19.50 19.50 DRILL E 6 P BROOH(/16560'6/9646'(450?500 gpm @ 2550?2500 psi-120 rpm @ 1579k ft'Ibs-1078 min/Std) 19.30 20:30 1.00 20.50 DRILL E 5 P C/O 41.4 IF Saver sub to 41/:"NC46-C/O 5"elevators to 4 X" 20:30 00:00 3.50 24.00 DRILL E 6 P BROOH 6/9646'6/8220'(500 gpm @ 2500?2300 psi-120 rpm @ 9766 ft-lbs-876 min/Std) [Daily losses 67 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 Drig Spvr. 907-685-1493 907-903-7269 Eni representative Ken Bogner Eni Petroleum Material Coordinator Eni representative Steve Milieu ENI Petroleum HSE 907-685-1496 Eni representative Greg Parker Eni Petroleum Expediter 907-980-7545 Tool Push Bruce Simonson Nabors Alaska Dulling Tool Pusher 907-670-1492 Tool Push Toby Bordelon Nabors Alaska Dnlling Tour Pusher 907-670-1492 Last Casing seat Can.Type OD(in) ID(in) Grade Top(RKB) Bottom(ftKB) Run Date CASING 95/8 8.835 L80 0.0 8.993.0 5/20/2012 Last Leakoff Test Depth(ftKB) ND(ftKB) Fluid Type Fluid Density(lb/gal) P Surf Applied(psi) Eq.Mud Weight(lb/gal) Leak Off Pressure(psi) 2,413.0 2,123.64 LSND mud @ 9.2 ppg 9.30 377.0 12.72 1,403.0 Eni E&P Division .. I Well Name: 0124-08 04 1 ENI Petroleum Co.Inc. Daily Report Well Code:26154 Field Name: Nikatchuq • APIIUWI:50-029-23457-00-00 2^ Date:6/3/2012 - Report#: 33 If II page 1 of 1 Wellbore name: 0124-08 Well Header Permit/Concession N° Operator •ENI Share(%) Well Configuration type 402100 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(ft) Ground Level(ft) Water Depth(ft) RKB-Base Flange(ft) RKB-Tubing Spool(ft) 53.15 12.20 0.00 36.96 Rig Information Contractor Rig Name Rig Type NABORS ALASKA NABORS 245 E LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(ftKB) Target Depth(TVD...Depth Dr.(MD)(ft) Drilling Hours(hr) Avg ROP(ft/hr) DFS(days) 0124-08 DRILLING 5/8/2012 18,666.0 18,510.00 176.23 105.0 26.33 Daily Information End Depth(ftKB) End Depth(TVD)(f.. Depth Progress(ft) Drilling Hours(hr) Avg ROP(ftlhr) POB Temperature(°F) Weather Wind 18,670.0 3,423.0 0.00 78.0 30.0 Overcast WC 21" East @ 10 MPH Daily summary operation 24h Summary BROOH to 3500'-POOH on elevators-UD BHA#5-P/U BHA#6-Repair Iron roughneck-RIH BHA#6 5/9712'on elevators Operation at 07.00 RIH BHA#6 @ 12.000' 24h Forecast RIH BHA#6 to TD-Displace 9.5 ppg Brine+9.5 ppg Breaker fluid-POOH on elevator to 8700'(200'into 9 5/8"shoe)-Displace 9.1 ppg KCI completion fluid-POOH and UD 4%"DPs • Lithology Shows MAASP Pressure(psi) Mud Weight(1b/gal) 9.20 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 6 P BROOH t/8220'1/4500'(500?540 gpm @ 230071800 psi-120 rpm @ 623.5k fl'lbs-674 06:30 07:30 1.00 7.50 DRILL E 6 'P Flow check 15 min OK-Attempt to POOH on elevator failed due to swabbing 07:30 09:00 1.50 9.00 DRILL E 6 P BROOH 1/4500'113500'(540 gpm @ 180071600 psi-120 rpm @ 3.572.7k fl'lbs-4 min/Std) 09:00 11:30 2.50 11.50 DRILL E 4 P "POOH on elevator f/3500'11330'as per TAD trip speed schedule(Proper displacement) 11:30 15:30 4.00 15.50 DRILL E 5 P POOH and L/D BHA#5(Bit Dull:1-1-BT-C-X-1-RO-TD)-Download MWD tools 15:30 16:30 1.00 16.50 DRILL E 5 'P M/U BHA#6[8%"Hole Opener+Bit Sub w/float+x9 Jt 5"DPs+Jar+x2 HWDP 5"+XO] 16:30 '18:00 1.50 16.00 DRILL E '25 'P "Service Rig:Replace broken ram on iron roughneck 18.00 00:00 6.00 24.00 DRILL E 4 P Complete M/U BHA#6 and RIH on elevators 0/9712'filling pipe every 20 Std(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 Mirko Musumeci Eni Petroleum Ddg Spvr. 907-685-1493 907-903-7269 Eni representative Ken Bogner Eni Petroleum Material Coordinator Eni representative Steve Millea ENI Petroleum HSE 907685-1496 Eni representative Greg Parker Eni Petroleum Expediter 907-980-7545 Tool Push Bruce Simonson Nabors Alaska Drilling Tool Pusher 907-670-1492 Tool Push Toby Bordelon Nabors Alaska Drilling Tour Pusher 907-670-1492 • Last Casing seat Cas.Type OD(in) ID(in) Grade Top(RKB) Bottom(ftKB) Run Date CASING 9 5/8 8.835 L80 0.0 8,993.0 5/20/2012 Last Leakoff Test Depth(ftKB) TVD(ftKB) Fluid Type Fluid Density(lb/gal) P Surf Applied(psi) Eq.Mud Weight(Iblgal) Leak Off Pressure(psi) 2,413.0 2,123.64 LSND mud @ 9.2 ppg 9.30 377.0 12.72 1,403.0 - ft* Eni E&P Division `Well Name:0124-08 EN!Petroleum Co,Inc. Daily Report Well Code:26154 Field Name:Nikatchuq • API/UWI:50-029-23457-00-00 2^i Date:614/2012 - Report#: 34 II II page 1 of 1 Wellbore name: 0124-08 Well Header Permit/Concession N° Operator ENI Share(%) Well Configuration type 402100 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(ft) Ground Level(ft) Water Depth(ft) RKB-Base Flange(ft) RKB-Tubing Spool(ft) 53.15 12.20 0.00 36,96 Rig Information Contractor Rig Name Rig Type NABORS ALASKA NABORS 245 E LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(ftKB) Target Depth(TVD...Depth Dr.(MD)(ft) Drilling Hours(hr) Avg ROP(ft/hr) DFS(days) 0124-08 DRILLING 5/8/2012 18.666.0 18.510.00 176.23 105.0 27.33 Daily Information End Depth(ftKB) End Depth(TVD)(f.. Depth Progress(ft) Drilling Hours(hr) Avg ROP(ft/hr) POB Temperature(°F) Weather Wind 18.670.0 3,423.0 0.00 83.0 30.0 Overcast WC 19° East @ 15 MPH Daily summary operation 24h Summary RIH BHA#6 to TD-circulate EU-Wait for breaker fluid Operation at 07.00 Displace Breaker Fluid 24h Forecast Wait for breaker fluid-Displace 9.5 ppg mud*9.5 ppg Breaker fluid-POOH on elevator to 8700'(200'into 9 5/8"shoe)-Displace 9.1 ppg KCI completion fluid-POOH and UD 4%"DPs Lithology Shows MAASP Pressure(psi) Mud Weight(Iblgal) 9.20 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 P C/O 4 14"NC46 Saver sub to 4%"IF-C/O 4 W elevators to 5" 01:30 03:00 1.50 3.00 DRILL E 4 P RIH on elevators f/9712'511443'filling pipe every 20 Std(Proper displacement) 03:00 09.30 6.50 9.50 DRILL 'E 4 P 'Ream and wash down f/11443'518670'tag bottom(200 gpm @ 600?700 psi-60 rpm @ 6711k ft'lbs)-No tight spots encountered NOTE.6 Hrs notice to MI mud plant @ 06:00 am 09.30 12:00 2.50 12.00 DRILL E 7 P Circulate BU reciprocating and rotating(160 gpm©700 psi-50 rpm @ 13k ft'lbs) 12.00 00.00 12.00 24.00 DRILL E 24 TW02 Circulate reciprocating and rotating(160 ppm @ 700 psi-50 rpm @ 13k fflbs)-Waiting for Breaker fluid,delayed due to issues at MI mud plant Daily Contacts Position Contact Name Company Title E-mail _ Office Mobile Eni representative Ben Perry 'Eni Petroleum Sr.Dig.Spur. 907-685-1493 Eni representative Mirko Musumeci Eni Petroleum Drlg Spur. 907-685-1493 907-903-7269 Eni representative Ken Bogner Eni Petroleum Material Coordinator Eni representative Steve Millea ENI Petroleum HSE 907-685-1496 Eni representative Greg Parker Eni Petroleum Expediter 907-980-7545 Tool Push Bruce Simonson Nabors Alaska Dolling Tool Pusher 907-670-1492 Tool Push Toby Bordelon Nabors Alaska Dulling Tour Pusher 907-670-1492 Last Casing seat Cas.Type OD(in) ID(in) Grade Top OMB) Bottom(ftKB) Run Date CASING 95/8 8.835 L80 0.0 8,993.0 5/20/2012 Last Leakoff Test Depth(ftKB) TVD(ftKB) Fluid Type Fluid Density(Iblgal) P Surf Applied(psi) Eq.Mud Weight(Ib/gal) Leak Off Pressure(psi) 2,413.0 2,123.64 LSND mud @ 9.2 ppg 9.30 377.0 12.72 1,403.0 rill° Eni E&P Division [Well Name:0124-08 ENI Petroleum Co.Inc. Daily Report Well Code:26154 Field Name: Nikatchuq eDate:6/5/2012 - Report#: 35 APIIUWI:50-029-23457-00-00 " " page 1 of 1 Wellbore name. 0(24-08 Well Header Permit/Concession N° Operator ENI Share(%) Well Configuration type 402100 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(ft) Ground Level(ft) Water Depth(ft) RKB-Base Flange(ft) RKB-Tubing Spool(ft) 53.15 12.20 0.00 36.96 Rig Information Contractor Rig Name Rig Type NABORS ALASKA NABORS 245 E LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(ftKB) Target Depth(TVD...Depth Dr.(MD)(ft) Drilling Hours(hr) Avg ROP(ft/hr) DFS(days) 0124-08 DRILLING 5/82012 18,666.0 18,510.00 176.23 105.0 28.33 Daily Information End Depth(ftKB) End Depth(TVD)(f.. Depth Progress(ft) Drilling Hours(hr) Avg ROP(ft/hr) POB Temperature('F) Weather Wind 18,670.0 3,423.0 0.00 81.0 32.0 Overcast WC 22' ENE @ 20 MPH Daily summary operation 24h Summary Displace 9.5 ppg mud+9.5 ppg Breaker fluid-POOH on elevator to 12427' Operation at 07.00 POOH and L/D 4 W DPs @ 9555' 24h Forecast POOH on elevator to 8700'(300'into 9 5/8"shoe)-C/O Saver sub-Displace 9.1 ppg KCI completion fluid-POOH and L/D 4'h"DPs-R/U 4 14"Liner running equipment Lithology Shows MAASP Pressure(psi) Mud Weight(Ib/gal) 9.50 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 24 TWO2 Circulate reciprocating and rotating(160 gpm @ 700 psi-50 rpm @ 13k ftdbs)-Waiting for Breaker fluid,delayed due to issues at MI mud plant 01 30 02'.30 1.00 2.50 DRILL E 20 P Connected Vac Trucks with mud pump-PJSM 02.30 09.30 7.00 9.50 DRILL E 9 P Displace hole to 9.5 ppg FazePro 460 bbl(Cased Hole)+9.6 ppg FazeAway breaker fluid 750 bbl(Hopen Hole)(100*200 gpm @ 700 psi-50 rpm @ 14k ft'lbs)-Chase breaker with 118 bbls 9.5 ppg FazePro+30 bbl 11.4 ppg dry job 09:30 0000 14.50 24.00 DRILL E 4 P POOH on elevators f/16670'5112427'(Up wt=175?150k lbs)-No tight spot encountered Trip speed: 18670'*18420'@ 30 min/Std 18420'17600'@ 20 min/Std 17600'*16600'@ 15 min/Std 16600'*16000'@ 10 min/Std 16000'*15300'@ 7 min/Std 15300'+12427'@ 5 min/Std 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 Mirko Musumeci Eni Petroleum DrIg Spvr. 907-685-1493 907-903-7269 Eni representative Ken Bogner Eni Petroleum Material Coordinator Eni representative Mike Nelson Eni Petroleum HSE 907-685-1496 Eni representative Greg Parker Eni Petroleum Expediter 907-980-7545 Tool Push Bruce Simonson Nabors Alaska Drilling Tool Pusher 907-670-1492 Tool Push Toby Bordelon Nabors Alaska Dolling Tour Pusher 907-670-1492 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(RKB) Bottom(f1KB) Run Date CASING 9 5/8 8.835 L80 0.0 8,993.0 5/20/2012 Last Leakoff Test Depth(RKB) TVD(ftKB) Fluid Type Fluid Density(lb/gal) P Surf Applied(psi) Eq.Mud Weight(lb/gal) Leak Off Pressure(psi) 2.413.0 2,123.64 LSND mud @ 9.2 ppg 9.30 377.0 12.72 1,403.0 I I Eni E&P Division I Well Name:0124-08 J III* ENI Petroleum Co.Inc. Daily Report Well Code:26154 Field Name: Nikatchuq 2^n Date:6/6/2012 - Report#: 36 II APuuwe 50-029-23457-00-00 - II II page 1 of 1 Wellbore name: 0124-08 Well Header Permit/Concession N° Operator ENI Share)%) Well Configuration type 402100 ENI PETROLEUM 10000 HORIZONTAL Rotary Table Elevation(ft) Ground Level(ft) Water Depth(ft) RKB-Base Flange(ft) •RKB-Tubing Spool(ft) 53.15 12.20 0.00 36.96 Rig Information Contractor Rig Name Rig Type NABORS ALASKA NABORS 245 E LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(ftKB) Target Depth(TVD...Depth Dr.(MD)(ft) Drilling Hours(hr) Avg ROP(ft/hr) DFS(days) 0124-08 DRILLING 5/8/2012 18,666.0 18,510.00 176.23 105.0 29.33 Daily Information End Depth(ftKB) End Depth(TVD)(f...Depth Progress(ft) Drilling Hours(hr) Avg ROP(ft/hr) POB Temperature(°F) Weather Wind 18670.0 3,423.0 0.00 81.0 33.0 Overcast WC 23° ENE @ 15 MPH Daily summary operation 24h Summary POOH on elevator to 8700'(300'into 9 5/8"shoe)-Displace 9.1 ppg KCI completion fluid-POOH and UD 4'A"DPs-POOH and L/D BHA#6 Operation at 07.00 Run 4 1/2"Liner @ 120' 24h Forecast Complete L/D BHA#6-R/U Liner running equipment-4%"Liner Job Lithology •Shows MAASP Pressure(psi) Mud Weight(Ib/gal) 9.10 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00:00 03:30 3.50 3.50 DRILL E 4 P POOH on elevators 1/12427'119714'(Up wt=150?135k lbs-Trip speed 573 min/Std)-No tight spot encountered 03:30 05:30 2.00 5.50 DRILL E 4 P C/O 5"elevators to 4% -POOH on elevators(/1714'98750'(Up wt=135k lbs-Trip speed 372 min/Std)-B/O and L/D 4 'A"single Jt-No tight spot encountered 05:30 06:30 1.00 6.50 DRILL E 8 P Connected Vac Trucks-Transfer 3%KCI Brine 9.1 ppg to rig pits-PJSM 06:30 09:00 2.50 9.00 DRILL E 9 P Displace hole(from 8750'to surface)to 9.1 ppg KCI Brine(3%)580 bbl(280 gym @ 300 psi-50 rpm @ 4k ftlbs) 09:00 11:30 2.50 11.50 DRILL E 20 P Flow check 6 bbt/Hr-Clean pits,shakers,possum belly and lines 11:30 22:30 11.00 22.50 DRILL E 4 P POOH and UD 4''A"DPs 1/8750'9393'(Trip speed 271.5 min/Std) 22:30 00:00 1.50 24.00 DRILL E 4 P POOH and UD BHA#6-In progress 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 Drtg Spvr. 907-685-1493 907-903-7269 Eni representative Ken Bogner Eni Petroleum Material Coordinator Eni representative Mike Nelson Eni Petroleum HSE 907-685-1496 Eni representative .Greg Parker Eni Petroleum Expediter 907-980-7545 Tool Push Bruce Simonson Nabors Alaska Drilling Tool Pusher 907-670-1492 Tool Push Brian Tiedemann Nabors Alaska Drilling Tour Pusher 907-685-1491 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(ftKB) Bottom(ftKB) Run Date CASING 9 5/8 8.835 L80 0.0 8,993.0 5/20/2012 Last Leakoff Test Depth(ftKB) ND(ftKB) Fluid Type Fluid Density(lb/gal) P Surf Applied(psi) Eq.Mud Weight(Iblgal) Leak Off Pressure(psi) 2,413.0 2,123.64 LSND mud @'9.2 ppg 9.30 377.0 12.72 1,403.0 • Eni E&P Division I Well Name:0124-08 VII* ENI Petroleum Co.Inc. Daily Report Well Code:26154 Field Name:Nikatchuq • API/11tH:50-029-23457-00-00 2�,r, Date:6/7/2012 - Report#: 37 II II II page 1 of 1 Wellbore name: 0124-08 Well Header Permit/Concession N° Operator ENI Share)%) Well Configuration type 402100 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(ft) Ground Level(ft) Water Depth(ft) RKB-Base Flange(ft) RKB-Tubing Spool(ft) 53.15 12.20 0.00 36.96 Rig Information Contractor Rig Name Rig Type NABORS ALASKA NABORS 245 E LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(ftKB) Target Depth(TVD...Depth Dr.(MD)(ft) Drilling Hours(hr) Avg ROP(ft/hr) DFS(days) 0124-08 DRILLING 5/8/2012 18,666.0 18,510.00 176.23 105.0 30.33 Daily Information End Depth(ftKB) End Depth(TVD)(f.."Depth Progress(ft) Drilling Hours(hr) Avg ROP(ft/hr) POB Temperature(°F) Weather Wind 18,670.0 3,423.0 0.00 81.0 33.0 Overcast WC 23` ENE 14 MPH Daily summary operation 24h Summary Complete to L/D BHA 116-R/U Liner running equipment-RIH 4 14"Liner Operation at 07.00 RIH 4.4"liner wd 5"DPs @ 12000'/Fixing failure on iron roughneck 24h Forecast Continue to RIH 4 4"liner-Install SLZXP liner hanger-RIH w/5"DPs-Set liner hanger-POOH and L/D 5"DPs Lithology Shows MAASP Pressure(psi) Mud Weight(Ib/gal) 9.10 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. I 00:00 01.00 1.00- 1.00 DRILL 'E 5 'P Complete to POOH and L/D BHA#6 01:00 01:30 0.50 1.50 DRILL E 25 P ..TDS,drawworks,crown and iron roughneck service 01:30 03:00 1.50 3.00 DRILL E 2 P R/U GBR 4'A"liner running equipment 03:00 22:00 19.00 22.00 DRILL E 5 P 'PJSM-P/U,M/U and RIH Liner 4 1/2"11.66 L80 HYD521(M/U torque 6.3k Mlbs)08500'installing ICD valve and water swell packer as per tally-Top fill every 10 Jt 22:00 22:30 0.50 22.50 DRILL E 7 'P Circulate tubing volume(420 gpm©300 psi) 22:30 0000 1.50 24.00'DRILL 'E 5 -P 'P/U,M/U and RIH Liner4 1/2"11.66 L80 HYD521(M/U torque 6.3k ft-lbs)f/8500'118982'installing ICD valve and water swell packer as per tally-Top fill every 10 Jt 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 Mirko Musumeci Eni Petroleum Drtg Spvr. 907.685-1493 907-903-7269 Eni representative Ken Bogner Eni Petroleum Matenal Coordinator Eni representative Mike Nelson Eni Petroleum HSE 907-685-1496 I Eni representative Greg Parker Eni Petroleum Expediter 907-980-7545 Tool Push Bruce Simonson Nabors Alaska Drilling Tool Pusher 907-670-1492 Tool Push Brian Tiedemann Nabors Alaska Drilling Tour Pusher 907-685-1491 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(ftKB) Bottom(ftKB) Run Date LINER 41/2 L80 8,775.8 18,660.0 6/8/2012 Last Leakoff Test Depth(ftKB) TVD(ftKB) Fluid Type Fluid Density(Iblgal) P Surf Applied(psi) Eq.Mud Weight(Ib/gal) Leak Off Pressure(psi) 2,413.0 2,123.64 LSND mud @ 9.2 ppg 9.30 377.0 12.72 1,403.0 , $r* Eni E&P Division f Well Name:0124-08 ENI Petroleum Co.Inc. Daily Report Well Code:26154 Field Name: Nikatchuq • APIIUWI:50-029-23457-00-00 2�, Date:6/8/2012 - Report#: 38 In i page 1 of 1 Wellbore name: 0124-08 Well Header Permit/Concession N° Operator ENI Share(%) Well Configuration type 402100 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(ft) Ground Level(ft) Water Depth(ft) RKB-Base Flange(ft) RKB-Tubing Spool(ft) 53.15 12.20 0.00 36.96 Rig Information Contractor Rig Name Rig Type NABORS ALASKA NABORS 245 E LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(ftKB) Target Depth(TVD...Depth Dr.(MD)(ft) Drilling Hours(hr) Avg ROP(ft/hr) DFS(days) 0124-08 DRILLING 5/8/2012 18,666.0 18,510.00 176.23 105.0 31.33 Daily Information End Depth(RKB) End Depth(TVD)(f.. Depth Progress(ft) Drilling Hours(hr) Avg ROP(ft/hr) POB Temperature(°F) Weather Wind 18,670.0 3,423.0 0.00 81.0 36.0 Overcast WC 26` ENE @ 17 MPH Daily summary operation 24h Summary Continue to RIH 4'A"liner-Install SLZXP liner hanger-RIH w/5"DPs-Set liner hanger-POOH and UD 5"DPs-BOP test-Stip and cut DL-M/U test tool for finer hanger pressure test Operation at 07.00 Pressure test liner hanger seal 24h Forecast RIH test tool-Set test tool on liner hanger PBR-Pressure test liner hanger seal-POOH and L/D 5"DPs-Completion job Lithology Shows MAASP Pressure(psi) Mud Weight(1b/gall 9.10 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 G 5 P P/U,M/U and RIH Liner 4 1/2"11.6#L80 HYD521(M/U torque 6.3k ftlbs)(/8922'59853'installing ICD valve and water swell packer as per tally-Top fill every 10 Jt 01:30 02:30 1.00 2.50 DRILL G 5 P C/O Elevator-P/U&M/U SLZXP liner hanger-Fill Tieback sleeve with"pal mix"(wait 30'to set up)-R/D GBR equipment 02:30 10:30 8.00 10.50 DRILL G 4 P RIH 5 1/::"Liner on 92 Std 5"DPs 1/18670'(Up wt 160k lbs-Rot wt 110k lbs)-Ream tight spot(/16000'1/16300'(30 rpm @ 5k ft'lbs)-Start ream down from 17600'(40 rpm @ 6t8k ft'Ibs) NOTES: From 03:30 to 06:00 operation slowed down due to iron roughneck broken 1030 11:00 0.50 11.00 DRILL G 19 P Pull liner in tension 1/18670't18660'(160k lbs)-Drop setting ball-Start pump(3 bpm @ 300 psi)-Pressure up to 2280 psi -Pressure up to 3200 psi to shear bypass-Pressure up to 4000 psi and held 10'-Set 80k lbs on hanger-Running tool released(Up wt=123k lbs) 4'A Shoe @ 18660' TOL @ 8775' Water swell packer @ 9684.47/10.729.55/12266.93/14773.45/16977.74 Hall ICD valves(All in open position and flow set 111)@ 9411.34/9922.58/10258.41/11166.56/11579.57/11996.89/ 12822.16/13359.27/13891.41/14424.92/15170.51/15706.18/16244.71/16743.36/17533.08/17910.12/18405.13 11.00 16.00 5.00 16.00 DRILL G 4 P POOH and R/B 5"DPs-Inspect and UD liner hanger running tool 16.00 17:00 1.00 17.00 DRILL C 5 P Pull wear ring-Set test plug-Fill Stack and fines wr'water-Purge air out of system 17.00 21 00 4.00 21.00 DRILL C 12 P Test BOP as per AOGCC requirements-Annular @ 250?2500 psi-Rams,choke manifold,floor and top drive valves @ 250?3500 psi-Chart record-BOP test waived by AOGCC rep.Lou Grimaldi at 11:45,6-7-12 21 00 22.00 1.00 22.00 DRILL C 5 P Pull test plug-Set wear ring-L/D testing tools 22.00 23.30 1.50 23.50 DRILL M 25 P Slip and cut 116'DL-TDS service 23.30 0000 0.50 24.00 DRILL M 5 P P/U and M/U 7 5/8"seal assembly(test tool)for liner pressure test-In progress 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 Mirka Musumeci Em Petroleum DrIg Spvr. 907-685-1493 907-903-7269 Eni representative Ken Bogner Eni Petroleum Material Coordinator Eni representative Mike Nelson Eni Petroleum HSE 907-685-1496 Eni representative Greg Parker Eni Petroleum Expediter 907-980-7545 Tool Push Bruce Simonson Nabors Alaska Dulling Tool Pusher 907-670-1492 Tool Push Brian Tiedemann Nabors Alaska Drilling Tour Pusher 907-685-1491 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(RKB) Bottom(ftKB) Run Date LINER 41/2 L80 8,775.8 18,660.0 6/8/2012 Last Leakoff Test Depth(ftKB) ND(f1KB) Fluid Type Fluid Density(lb/gal) P Surf Applied(psi) Eq.Mud Weight(lb/gal) Leak Off Pressure(psi) 2.413.0 2,123.64 LSND mud @ 9.2 ppg 9.30 377.0 12.72 1,403.0 Iff* Eni E&P Division `Well Name: 0124-08 ENI Petroleum Co.Inc. Daily Report Well Code:26154 Field Name: Nikatchuq • • Date:6/912012 - Report#: 39 API/UWI:50-029-23457-00-00 2" " page 1 of 1 Wellbore name: 0124-08 Well Header Permit/Concession N° Operator ENI Share(%) Well Configuration type 402100 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(ft) Ground Level(ft) Water Depth(ft) RKB-Base Flange(ft) RKB-Tubing Spool(ft) 53.15 12.20 0.00 36.96 Rig Information Contractor Rig Name Rig Type NABORS ALASKA NABORS 245 E LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(ftKB) Target Depth(TVD...Depth Dr.(MD)(ft) Drilling Hours(hr) Avg ROP(ft/hr) DFS(days) 0124-08 DRILLING 5/8/2012 18,666.0 18,510.00 176.23 105.0 32.33 Daily Information End Depth(ftKB) End Depth(TVD)(f.. Depth Progress(ft) Drilling Hours(hr) Avg ROP(ft/hr) POB Temperature(°F) Weather Wind 18,670.0 3.423.0 0.00 80.0 36.0 Clear WC 26" ENE @ 16 MPH Daily summary operation 24h Summary RIH test tool-Set test tool on liner hanger PBR-Pressure test liner packer-POOH and L/D 5"DPs-RIH 4%"Completion to 5145' Operation at 07.00 Fixing broken pipe skate. FINAL DRILL REPORT 24h Forecast Complete to RIH 4 G"Completion-Space out-Set and test tubing hanger-Set PHL packer-Tubing integrity test-Shear mirage plug-Shear GLM valve-Set BPV-N/D BOP Stack N/U Production Tree Lithology Shows MAASP Pressure(psi) Mud Weight(lb/gal) 9.10 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 DRILL G 4 P P/U and M/U 7 5/8"seal assembly(test tool)for liner pressure test and RIH 7/8785'-Set seal into tieback sleeve with 5k lbs down 04:00 04:30 0.50 4.50 DRILL G 11 P Test liner hanger seal assembly 1500 psi 10 min on chart 04:30 16:00 11.50 16.00 DRILL G 4 P POOH and UD 5"DPs 1/8785'to surface-Inspect and L/D testing tool 16:00 17:30 1.50 17.50 COMP K 2 P R/U completion running tools 1730 00.00 6.50 24.00 COMP K 5 P PJSM-P/U and M/U Tieback entry guide+Mirage plug assembly+Halliburton PHL Packer assemblies and RIH completion string a/4 W 12.6#L80 HYD563 tbg 1/5145'(Up wt 95k lbs-Dwwt 70k lbs-M/U Tq 4.4k fflbs)as per tally Daily Contacts Position Contact Name Company Title E-mail Office Mobile Eni representative Ben Perry Eni Petroleum Sr.Ddg.Spur, 907-685-1493 Eni representative Mirk°Musumeci Eni Petroleum Ortg Spvr. 907-685-1493 907-903-7269 Eni representative Ken Bogner Eni Petroleum Matenal Coordinator Eni representative Mike Nelson Eni Petroleum HSE 907-685-1496 Eni representative Greg Parker Eni Petroleum Expediter 907-980-7545 Tool Push Bruce Simonson Nabors Alaska Drilling Tool Pusher 907-670-1492 Tool Push Brian Tiedemann Nabors Alaska Drilling Tour Pusher 907-685-1491 Last Casing seat • Cas.Type OD(in) ID(in) Grade Top(RKB) Bottom(ftKB) Run Date LINER 41/2 L80 8,775.8 18,660.0 6/8/2012 Last Leakoff Test Depth(RKB) TVD(ftKB) Fluid Type Fluid Density(lb/gal) P Surf Applied(psi) Eq.Mud Weight(lb/gal) Leak Off Pressure(psi) 2.413.0 2.123.64 LSND mud @ 9.2 ppg 9.30 377.0 12.72 1,403.0 II* Eni E&P Division 'Well Name:0124-08 EN!Petroleum Co.Inc. Daily Report Well Code:26154 Field Name:Nikatchuq • APIIUWI:50-029-23457-00-00 2�,,t Date:6/9/2012 - Report#: 1 II II II page 1 of 1 Wellbore name: 0124-08 Well Header PermiVConcession N° Operator ENI Share(%) Well Configuration type 402100 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(ft) Ground Level(ft) Water Depth(ft) RKB-Base Flange(ft) RKB-Tubing Spool(ft) 53.15 12,20 0.00 36.96 Rig Information Contractor Rig Name Rig Type NABORS ALASKA NABORS 245E LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(fiKB) Target Depth(TVD...Depth Dr.(MD)(ft) Drilling Hours(hr) Avg ROP(ft/hr) DFS(days) 0124-08 COMPLETION 6/9/2012 18,666.0 3,428.6 0.29 Daily Information End Depth(RKB) End Depth(TVD)(f.. Depth Progress(ft) Drilling Hours(hr) Avg ROP(ft/hr) POB Temperature(°F) Weather Wind 18670.0 0.0 80.0 36.0 Clear WC 26° ENE C.16 MPH Daily summary operation 24h Summary RIH test tool-Set test tool on liner hanger PBR-Pressure test liner packer-POOH and UD 5"DPs-RIH 4 Y"Completion to 5145' Operation at 07.00 Fixing broken pipe skate. 24h Forecast Complete to RIH 4'/_"Completion-Space out-Set and test tubing hanger-Set PHL packer-Tubing integrity test-Shear mirage plug-Shear GLM valve-Set BPV-N/D BOP Stack N/U Production Tree Lithology Shows MAASP Pressure(psi) Mud Weight(Ib/gal) 9.10 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 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 Ken Bogner Eni Petroleum Material Coordinator Eni representative Mike Nelson Eni Petroleum HSE 907-685-1496 Eni representative Greg Parker Eni Petroleum Expediter 907-980-7545 Tool Push Bruce Simonson Nabors Alaska Drilling Tool Pusher 907-670-1492 Tool Push Brian Tiedemann Nabors Alaska Drilling Tour Pusher 907-685-1491 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(fiKB) Bottom(fiKB) Run Date LINER 41/2 L80 8,775.8 18.660.0 6/8/2012 Last Leakoff Test Depth(fiKB) TVD(fiKB) Fluid Type Fluid Density(lb/gal) P Surf Applied(psi) Eq.Mud Weight(lb/gal) Leak Off Pressure(psi) 2.413.0 2,123.64 LSND mud @ 9.2 ppg 9.30 377.0 12.72 1,403.0 119* Eni E&P Divisionwell Name: 0124-08 ENI Petroleum Co.Inc. Daily Report Well Code:26154 Field Name:Nikatchuq • API/UWI: 50-029-23457-00-00 en II�,II,t Date:6/1012012 - Report#: 2 page 1 of 1 Wellbore name: 0124-08 Well Header Permit/Concession N° Operator ENI Share(%) Well Configuration type 402100 _ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(ft) Ground Level(ft) Water Depth(ft) RKB-Base Flange(ft) RKB-Tubing Spool(ft) 53.15 12.20 0.00 36.96 Rig Information Contractor Rig Name Rig Type NABORS ALASKA NABORS 245 E LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(ftKB) Target Depth(TVD...Depth Dr.(MD)(it) Drilling Hours(hr) Avg ROP(ftlhr) DES(days) 0124-08 COMPLETION 6/9/2012 18,666.0 3.428.6 1.29 Daily Information End Depth(ftKB) End Depth(TVD)(f.. Depth Progress(ft) Drilling Hours(hr) Avg ROP(ft/hr) POB Temperature(°F) Weather Wind 18670.0 0.0 76.0 35.0 Overcast WC 24' ENE©18 MPH Daily summary operation 24h Summary Complete to RIH 4''A"Completion-Space out-Set and test tubing hanger-Set PHL packer-Tubing integrity test-Packer pressure test-Shear mirage plug-Shear GLM valve-Set BPV-N/D BOP Stack N/U Production Tree Operation at 07.00 Rig up for Freeze Protect well. 24h Forecast Test production Tree-Freeze protect annulus-C/O GLM valve-Rig move Lithology Shows MAASP Pressure(psi) Mud Weight(Iblgal) 9.10 Time Log Start End Cum Time Time Dur(Or) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00.00 02.00 2.00 2.00 COMP K 5 P -P/U,M/U and RIH completion stnng w/4%"12.60 L80 HYD563 tbg(/5145'5/6270'(M/U Tq 4.4k N'lbs) 02:00 0930 7.50 9.50 COMP K 25 TR99 Downtime:Repair pipe skate(raising ram broke,weld new pad eyes to mount bracket) 0930 1530 6.00 15.50 COMP K 5 P P/U,M/U and RIH completion string w/4 W 12.60 L80 HYD563 tbg(/6270'0/8805'(M/U Tq 4.4k(fibs)-Tag no go-Space out-M/U VIT5 and tubing hanger '15.30 '17.00 1.50 17.00 COMP K 5 P 'Land tbg hanger-Run in all lock down screws-Test upper and lower seals 5000 psi 10'each [Shoe @ 8801'-NO GO @ 8775'-LN'XN'3.813'©8666'-MFA Packer @ 8647'-LN'X'3.813"@ 8594'-GLM 2000 psi ATT(fp 2358'-LN'X'3.813"@ 2265') 17:00 19.00 2.00 19.00 COMP K 11 P 'M/U surface lines to set Packer-Pressure test lines @ 5000 psi-Pressure down Tbg to 3500 psi,hold 30 min on chart (A [Packer start setting @ 900 psi-Autofill valve closed @ 1400 psi].Bleed off Tbg pressure to 2000 psi-Test MFA Packer pumping down IA to 2500 psi,hold 30 min on chart-Bleed off IA pressure to zero-Increase Tbg pressure until shear oiMirage plug @ 4400 psi-Bleed off Tbg pressure to zero-Pressure down IA until shear GLM @ 2500 psi -" .e?- ( 19:00 20:00 1.00 20.00 COMP C 5 P -R/D equipment-Blow down all lines and TDS-Drain BOP Stack-Install BPV 20:00 22.30 2.50 22.50 COMP C 5 P Remove choke&kill lines-R/D Katch Kan-L/D mouse hole-L/D flow line-N/D BOP stack and set back-N/D and L/D nser 22:30 00.00 1.50 24.00 COMP C 5 P N/U Tree adapter and valves Daily Contacts Position Contact Name Company Title E-mail Office Mobile l Eni representative Ben Perry Eni Petroleum Sr.Ddg.Spvr. 907-685-1493 Eni representative Mirko Musumeci Eni Petroleum Drlg Spvr. 907-685-1493 907-903-7269 Eni representative Ken Bogner Eni Petroleum Material Coordinator Eni representative Mike Nelson Eni Petroleum HSE 907-685-1496 Eni representative Greg Parker Eni Petroleum Expediter 907-980-7545 Tool Push Bruce Simonson Nabors Alaska Drilling Tool Pusher 907-670-1492 Tool Push ,Brian Tiedemann Nabors Alaska Dnlling Tour Pusher 907-685-1491 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(ftKB) Bottom(ftKB) Run Date LINER 41/2 L80 8.775.8 18.660.0 6/8/2012 Last Leakoff Test Depth(ftKB) TVD(ftKB) Fluid Type Fluid Density(Iblgal) P Surf Applied(psi) Eq.Mud Weight(Ibigal) Leak Off Pressure(psi) 2,413.0 2,123.64 LSND mud @ 9.2 ppg 9.30 377.0 12.72 1,403.0 frAiiil Eni E&P Division I Well Name:0124-08 ENI Petroleum Co.Inc. Daily Report Well Code:26154 Field Name: Nikatchu9 • API/UWI:50-029-23457-00-00 2^ Date:6/11/2012 - Report#: 3 'I 1I page 1 of 1 wellbore name: 0124-08 Well Header Permit/Concession N° Operator ENI Share(%) Well Configuration type 402100 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(ft) Ground Level(ft) Water Depth(ft) RKB-Base Flange(ft) RKB-Tubing Spool(ft) 53.15 12.20 0.00 36.96 Rig Information Contractor Rig Name Rig Type NABORS ALASKA NABORS 245 E LAND RIG Job Information Wellbore Job Phase •Spud Date Target Depth(ftKB) Target Depth(TVD...Depth Dr.(MD)(ft) Drilling Hours(hr) Avg ROP(ft hr) DFS(days) 0124-08 COMPLETION 6/9/2012 18,666.0 3,428.6 2.29 Daily Information End Depth(ftKB) End Depth(TVD)(f.. Depth Progress(ft) Drilling Hours(hr) Avg ROP(ft/hr) POB Temperature(°F) Weather Wind 18,670.0 0.0 78.0 33.0 Clear WC 21' NE @ 22 MPH Daily summary operation 24h Summary Test production Tree-Freeze protect annulus-C/O GLM valve-Rig move Operation at 07.00 Rig moving to 0120-07 24h Forecast Rig move to 0120-07 Lithology Shows MAASP Pressure(psi) Mud Weight(Ib/gat) 9.10 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 COMP C 12 P Pressure lest upper void area 5000 psi 10 min-Pull BPV-Install TWC-Pressure test Tree 500/5000 psi 5/15 min-R/D testing equipment-Pull TWC 01:00 04:30 3.50 4.50 COMP K 2 P R/U Little Red and returns lines on Tree to freeze protect annulus-Roll up Lampson curtains-Clean active pits-P/U Slick line equipment on rig floor 04:30 06:30 2.00 6.50 COMP K 9 P Freeze protect annulus pumping diesel down IA with returns from Tbg(2 bpm @ 1200 psi-168 bbl pumped)-Blow down and R/D lines and valves 06.30 00:00 17.50 24.00 COMP K 5 P Prepare for ng move:Pump pill through surface equipment-Continue to Clean pits-Secure BOP stack-Blow down lines- Change pump liner f/5'/:'66'-Jack up utility module and move to east onto crib blocs-RELEASE RIG TO 0120-07 Slick line operations:Complete R/U equipment-Pressure test lubncator 1000 psi-#1 Run:Install tubing stop-#2 Run: Pull sheared GLM valve FAILED-#3 Run:Pull shear GLM valve-#4,#5,#6 Runs:Attempts to set new GLM valve 2000 psi A?T FAILED-#7 Run:Clean Gas lift mandrel with braided line brush-#8 Run'.Check pocket accessibility with Tattle tail(Pin not sheared)-#9 Run:Check again pocket accessibility with Tattle tail refurbished(Pin sheared)-#10 Run: Attempt to set new GLM valve 2000 psi A?T FAILED(No go showing valve is all the way in the pocket)-Cut 1"off bottom nose cone on shear valve,redressed JK running tool with aluminum pin-#11 Run.Set GLM valve 2000 psi A?T OK-#12 Run:Pull tubing stop-R/D Slick line equipment Daily Contacts Position Contact Name Company Title E-mail Office Mobile Eni representative Ben Perry Eni Petroleum Sr.Drlg.Spur. 907-685-1493 Eni representative Mirko Musumeci Eni Petroleum Dng Spur. 907-685-1493 907-903-7269 Eni representative Ken Bogner Eni Petroleum Material Coordinator Eni representative Mike Nelson Eni Petroleum HSE 907-685-1496 Eni representative Greg Parker Eni Petroleum Expediter 907-980-7545 Tool Push Bruce Simonson Nabors Alaska Dnlling Tool Pusher 907-670-1492 Tool Push Bnan Tiedemann Nabors Alaska Dnlling Tour Pusher 907-685-1491 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(ftKB) Bottom(ftKB) Run Date LINER 41/2 L80 8,775.8 18,660.0 6/8/2012 Last Leakoff Test Depth(ftKB) TVD(ftKB) Fluid Type Fluid Density(lb/gal) P Surf Applied(psi) Eq.Mud Weight(lb/gal) Leak Off Pressure(psi) 2,413.0 2,123.64 LSND mud @ 9.2 ppg 9.30 377.0 12.72 1,403.0 _ mm HaO Qn Nm UMETH NA 8 0 _ 00 aO Emil iiii i I a 8188 88E4kiktvq k' J a08eaaVOV Y<VOO OOOVO OOQa0 QOOd0 QadVd a0a0a a0< a a oG pp yy p, Cp m„ 2 I HE HH§UU t§oo 8H U isa0§ s§g88 8UU U H 'ss .0. .0.0 2 N 0 N N .0. 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Casing Amp SWF1 0 (1/s)150 300 (us) 2000 40 (us/ft) 240 0 ( ) 150 300 (,\_/ US) 2000 GR(PeriS Casing Window Sto S/T Pro'ection-4m._ Casing Window Sta 0 (1/s)150 300 (us) 2000 40 (us/ft) 240 300 (us) 2000 IV (aBestDT-3;2.MPS 1 Casing Window Sto Casing . 300 (us 2000 300 (us) 2000 MD 1 240 ft Company: ENI Petroleum Well: 0124-08 Field: Nikaitchuq Borough: North Slope Scblumberger State: Alaska r M,,,,,,M.-, Ir ii u 700 `: ': r :1 Wit , _ __ i.._ HI---- /VVVV''. _ • • [ -•.^..,,,,,,,,.. • y wwvv. 1 -11 i 88. ` u )t • i H z 11 il i II - { i - -�.wwM.,. 74-4 V jvvv, 850 if i II , I -- „nnnn"� vV 8900 1 I,iir''.j t r LI: 1. 8950 1, 4i it 1 - 1` it _ �• I Illl._l_L : .:1 H-4---"-"--"'"-• = ..1 i 8400 -fit t 1 . . .,.......^.../... .-, . ; 't , , , 1 I 1 , A -,- _ - zt , I 8450 Jt'',., ' ...........-vv‘A, 1 : : .':t St;tlit i _....A., J , I— . i '`A"""" 1 i i 8500 14 to .. 0 ,-..: i ......,„,„" -4-1 ±----- ' 11_ L . ..,..".".".N.. 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MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg 7 DATE:Thursday,July 05,2012 P.I.Supervisor �f r l/7f(v SUBJECT:Mechanical Integrity Tests ENI US OPERATING CO INC 0I24-08 FROM: Bob Noble NIKAITCHUQ 0124-08 Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry —.)6(2— NON-CONFIDENTIAL 2NON-CONFIDENTIAL Comm Well Name NIKAITCHUQ 0I24-08 API Well Number 50-029-23457-00-00 Inspector Name: Bob Noble Permit Number: 211-130-0 Inspection Date: 7/3/2012 Insp Num: mitRCN120703141449 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 0124-08 . Type Inj W 'TVD 3498 - IA 1147 1727 - 1711 ] 1706 - PTD 2111300 , Type Test SPT Test psi 1500 - OA 200 200 200-1 200 Interval INITAL - P/F i P Tubing 94 . 94 94 94 =Notes: TVD of the packer was taken off operators paperwork. _ Thursday,July 05,2012 Page 1 of 1 ktttt OIZt-q, P7-6 Z() 1300 Regg, James B (DOA) From: Nofziger Laura [Laura.Nofziger@enipetroleum.com] J Sent: Thursday, June 28, 2012 4:51 PM ��1� 6l Z ��1 To: Regg, James B (DOA); DOA AOGCC Prudhoe Bay; Brooks, Phoebe L (DOA) Subject: Pre-injection MIT 0124-08 Attachments: MIT NIK 0124-08 June 2012.xls Good afternoon, I have attached the pre-injection MIT paperwork for 0124-08. Thanks, Laura Nofziger Sr. Production Engineer Office 907-865-3339 Cell 907-341-9659 laura.nofziger(c�enipetroleum.com 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 r ' I STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Submit to: jim.reaat alaska.aov doa.aoacc.orudhoe.bavaalaska.gov phoebe.brooks(caalaska.00v; tom.maunder alaska.gov OPERATOR: Eni US Operating Co Incl 6l7 (t Z FIELD/UNIT/PAD: Nikiatchuq Field/Oliktok Point Pad DATE: 06/10/12 OPERATOR REP: Ben Perry AOGCC REP: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well 0124-08 ' Type Inj. W ' TVD - 3,498' Tubing 1,400 '3,500 3,500 '3,500 Interval 1 P.T.D. 2111300 Type test P Test psi - 1,500 Casing "2,500 2,500 '2,500 P/F P Notes: Pre-injection MIT - OA Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. ND Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. ND Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. ND Tubing Interval - P.T.D. Type test Test psi Casing P/F Notes: OA TYPE INJ Codes TYPE TEST Codes INTERVAL Codes D=Drilling Waste M=Annulus Monitoring I=Initial Test G=Gas P=Standard Pressure Test 4=Four Year Cycle I=Industrial Wastewater R=Internal Radioactive Tracer Survey V=Required by Variance N=Not Injecting A=Temperature Anomaly Survey T=Test during Workover W=Water D=Differential Temperature Test 0=Other(describe in notes) Form 10-426(Revised 06/2010) MIT NIK 0124-08 June 2012 t3� 2J3 Schiumberger Drilling&Measurements MWD/LWD Log Product Delivery Customer ENI US Operating Co.Inc.Alaska Dispatched To: Makana Bender Well No 0124-08 Date Dispatched: 19-Jun-12 Installation/Rig Doyon 15 Dispatched By: Hector Echeto Data No Of Prints No of CDs 0124-08 Log 1 2 in MD 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 Schiumberger Drilling&Measurements MWD/LWD Log Product Delivery Customer ENI US Operating Co.Inc.Alaska Dispatched To: Makana Bender Well No 0124-08 Date Dispatched: 8-Jun-12 Installation/Rig Doyon 15 Dispatched By: Hector Echeto Data No Of Prints No of CDs 0124-08 Log 1 2 in MD 1 2inTVD 1 5 in MD 1 5inTVD 1 Received By: /"✓C(ltau_ / `_7 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 LzaA',, LP\ LLLI \ U\ L \ SEAN PARNELL,GOVERNOR ALASKA OIL AND GAS 333 W.7th AVENUE,SUITE 100 CONSERVATION COMlMISSION 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, 0124-08 ENI US Operating Co. Inc. Permit No: 211-130 (revised) Surface Location: 3126.4' FSL, 1710.5' FEL, SEC. 5, T13N, R9E, UM Bottomhole Location: 1121' FSL, 5238' 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 supersedes and replaces the permit previously issued for this well dated October 4, 2011. The permit is approved subject to full compliance with 20 AAC 25.055. Approval to inject is contingent upon issuance of a conservation order approving a spacing exception. ENI US Operating, Co. Inc. assumes the liability of any protest to the spacing exception that may occur. This permit to drill does not exempt you from obtaining additional permits or an approval required by law from other governmental agencies and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. Sincerely, Daniel T. Seamount, Jr. Chair DATED this day of January, 2012. cc: Department of Fish 86 Game, Habitat Section w/o end. (via e-mail) Department of Environmental Conservation w/o end. (via e-mail) STATE OF ALASKA i_.,, E 11/ED ALA�r A OIL AND GAS CONSERVATION COMMS ON DEC 2 2 201 PERMIT TO DRILL REVISION 20 MC 25.005 , s Lens.commission. 1a.Type of Work: lb.Proposed Well Class: Development-Oil ❑ Service- Winj L . Single Zone ❑ lc.Specify if we isrrpp�r��opppposed for: Drill 2c Redrill ❑ Stratigraphic Test ❑ Development-Gas ❑ Service-Supply ❑ Multiple Zone ❑ Coalbed Gas 0G owe}, ❑ Re-entry ❑ Exploratory ❑ Service- WAG ❑ Service-Disp ❑ Shale Gas ❑ 2.Operator Name: 5. Bond: Blanket Q Single Well ❑ 11.Well Name and Number: ENI US Operating Co.Inc. Bond No. RLB0008627 . 0124-08 - 3.Address: 6.Proposed Depth: 12.Field/Pool(s): 3800 Centerpoint Drive Suite 300,Anchorage 99503 MD: 18666 TVD: 3429- Nikaitchuq Schrader Bluff Oil Pool 4a. Location of Well(Governmental Section): 7.Property Designation(Lease Number): Surface: 3126.4 FSL 1710.5 FEL S5 T13N R9E UM ADL 355024,373301,391283 • Top of Productive Horizon: 8.Land Use Permit: 13.Approximate Spud Date: 286 FSL,3037 FEL,S31 T14N R9E UM ADL 417493 1/6/2012 • Total Depth: 9.Acres in Property: 14.Distance to Nearest Property: 1121 FSL 5238 FEL 25 T14N R8EUM 1280 286'south lease line 4b.Location of Well(State Base Plane Coordinates-NAD 27): 10.KB Elevation above MSL: 52.2 15.Distance to Near t 111 Ogen Surface:x- 516570 y- 6036479 Zone- 4 GL Elevation above MSL: 12.2 to Same Pool: to OP18-08ct 2,'2 i( 16.Deviated wells: Kickoff depth: 300 feet 17.Maximum Anticipated Pressures in psig(see 20 AAC 25.035) Maximum Hole Angle: 93.87 degrees Downhole: 1680 psig Surface: 1273 psig 18.Casing Program: Specifications Top - Setting Depth - Bottom Cement Quantity,c.f.or sacks Hole Casing Weight Grade Coupling Length MD TVD MD TVD (including stage data) Driven 20" 178.89 X-65 Welded 160 36 36 160 160 Pre-Installed 1351 TOTAL sx 16" 13-3/8" 68 L-80 BTC 2392 35 35 2427 2172 LEAD:1121 sx 10.7 ppg ASL TAIL:230 sx 12.5 ppg DeepCrete 12.25" 9-5/8" 40 L-80 Hydril 563 8904 33 33 893 ) 3525 801 TOTAL sx J 801 sx 12.5 ppg DeepCrete 8-3/4" 4-1/2" 11.6 L-80 Hydril 521 9929 8737 3504 18666 3429 Slottled liner in open hole 19. PRESENT WELL CONDITION SUMMARY(To be completed for Redrill and Op ations) ,Q�� f 8�� - Z-3'�� 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❑ Drilling Program ❑ Time v.Depth Plot ❑ Shallow Hazard Analysis❑ Diverter Sketch❑ Seabed Report ❑ Drilling Fluid Program ❑ 20 AAC 25.050 requirements 21. Verbal Approval: Commission Representative: Date 12/22/2011 22. I hereby certify that the foregoing is true and correct. Contact Luca Borriat 907-865-3328 Printed Name Maurizio Grandi Title Well Operations Project Manager Signature JkC\C•614) Phone (907)865-3325 Date 12/22/2011 Commission Use Only Permit to Drill API Number: 22 ��7 Permit Anne^ �' ^ I ;=r letterfor other 2/ F'13alVts. Conditions of approval: If box is checked,well may not be used to explore for,test,or produce coalbed methane as hydrates,or gas contained in shales: rr'Other: *3� �Osi� �ie I-e_s h Samples req'd: Yes❑ No Mud log req'd: Yes ❑ No HZS measures: Yes❑ No" Directional svy req'd: Yes 2/No ❑ - Cy(i);h a //5--// 2DATE: / , APPROVED BY THE COMMISSION ,COMMISSIONER arillif Form 10-401(Revised 7/2009) This permit is valid for 24IGIN oval(20 AAC 25.005(s1) Submit in Duplicate / 1ILr_�_�� 1.2;Z Enil ' tirHeum REQ .s . DECD I�:ka Ail&Gas: � . t®mr�►ssion ArlOgrage 3800 Centerpoint Drive Suite 300 Anchorage,Alaska 99503 Maurizio Grandi Phone(907)865-3320 Email: Maurizio.Grandi@enipetroleum.com December 22,2011 Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage,Alaska 99501 RE: REVISION to 0124-08 APD 211-130 Dear Commissioners, ENI US Operating Co.Inc.hereby applies for a Revision to Permit to Drill#211-130 regarding the 0124- 08 On shore Injector well. After a thorough review of the newly acquired seismic volume along the lateral of the proposed injector well 0124-08 and the offset producer well OP18-08, it was determined that the last approximately 1800' of the OP18-08 lateral would be fault separated from the offset injector 0124-08. In order to maximize the sweep efficiency and ultimate recovery of oil in the area it was deemed necessary to extend the lateral length of the 0124-08 into this separate fault block to provide pressure support. We are submitting a revision to the wellplan as it will deviate more that 500' from the original well path. Also due to our recent observations on 0113-03 we have moved the 9-5/8"casing shoe up�20 TVD to land in the shale above the OA Sand. 'fr6 c0 71- isS - ( (654- circ- Also ircAlso the new 10-401 reflects the new OA Sand Target to remain complainant with the approved spacing S8 z exception Attached(i.e. at least 250' from the south lease line) The planned spud date is 01/01/2012. 3rl L Please find attached for the review of the Commission 10-401 and updated directional If you have any questions or require further information,please contact Joseph Longo at 907-865-3323 or Luca Borri at 907-865-3328. Sincerely, Maurizio Grandi Well Operation Project Manager 0 0 Co o cr) o o o ‘=: 2 2 o o 0 A 0 0 a El 5 a `- " co ° 5 t . 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W s, 6 3T o 274 *.rf V• 0a 9T.♦ gS 27487y° . I 23,.•P�g.� `j®' OR4v� �$Ji • 6S • J69RT •• 294 ♦ .,,, 4 ® •, ��T • ♦•• ..1, •• `�6y4 Lp • N 26482647° • p . 314 j • N O 284) '• • • _ ♦F •;�Oo ,.�y',��j • O O 525 T2P• ♦ •♦• ' i• 1'.• -. L • 3j29if � J,p,�+ O e. • • 2 i+.1';'�'l•• •. � • .:. .�� p�} y,. ♦...• 341 tI3l• • .ra • � • '� ,p,,,, -, 3J • Vy�• 7^ �yWm� -..c-:,4,..-1.;..---...ice La •. _ E.-, 11*.4 '' g `�' 6 Q • ..r 0 OO I• I N o • a• .pt • H W o *.'l "'45 O oo ooSS o 0 CWO ' ' Ocri � � �0N -130(1W 0:0 1:7 P•1 W iP.1 Schlumherger 0124-08 (P10b) Anti-Collision Summary Report Analysis Date-24hr Time: December 22,2011-14:22 Analysis Method: 3D Least Distance Client: ENI Reference Trajectory: 0124-08(P10b)(Def Plan) Field: Nikaitchuq Depth Interval: Every 10.00 Measured Depth(ft) Structure: Oliktok Point Rule Set: DMM AntiCollision Standard S002 v5.1/5.2 Slot: OP24 Min Pts: All local minima indicated. Well: 0124-08 Borehole: 0124-08 Offset Trajectories Summary Offset Selection Criteria Wellhead distance scan: Global within 59676.63 ft Selection filters: Definitive Surveys -All Non-Def Surveys when no Def-Survey is set in a borehole Offset Trajectory Separation Allow Sep. Reference Trajectory Risk Level Alert Status Ct-Ct(ft)1 EOU(ft) Dev.(ft) Fact. MD(ft) I TVD(ft) Alert I Minor 1 Major OP23-W W02(Def Survey) Warning Alert =1-78-91= N/A 0.00 0.00 CtCt<=15m<15.00 Enter Alert 8.451 6.531 1.86 N/A 180.00 180.00 MINPT-O-EOU 11 8.971 6.33[ 2.371 N/A 300.00 300.00 MinPts 8.99 6.32 2.39 N/A 310.00 310.00 MINPT-O-EOU 42.56 37.72 35.91 Man 710.00 707.87 MinPt-O-SF 48.83 43.48 41.51 12.08 740.00 737.29 CtCt<=15m015.00 Exit Alert 280.68 273.63 270.71 47.97 1405.06 1352.20 MinPt-O-SF 578.71 567.41 563.38 71.30 2002.29 1852.20 MinPt-0-SF 4737.91 4711.73 4699.18 188.66 6620.00 3214.50 MinPt-O-SF 5897.89 5866.89 5851.93 197.05 7880.00 3411.02 MinPt-O-SF 6553.26 8513.53 649421 169.50 8750.00 3505.67 MinPt-O-SF 7113.87 7067.16 7044.30 155.55 9510.00 3551.98 MinPt-O-SF 7570.22 7518.76 7493.52 149.95 10110.00 3530.61 MinPt-O-SF 8641.45 8584.84 8557.02 155.32 11470.00 3512.17 MinPt-O-SF 8681.68 8624.81 8596.87 155.32 11520.00 3512.39 MinPt-O-SF 8946.44 8881.73 884986 140.37 11850.00 3514.15 MinPt-O-SF 9484.80 9413.33 9378.09 134.55 12530.00 3539.77 MinPt-O-SF 10362.35 10279.56 10238.65 126.661 13640.00 3532.27 MinPt-O-SF 12393.57 12305.36 12261.75 142.081 15840.00 3492.55 MinPt-O-SF 13904.23 13810.11 13763.54 149.281 17430.00 3442.43 MinPt-O-SF 14920.20 14821.91 1477326 153.331 18560.00 3427.84 MinPt-O-SF 15014.88 14916.10 14867.20 153.52 18666.14 3428.80 TD OP18-08(Def Survey) Warning Alert 55.91 54.69 23.10 N/A 0.00 0.00 Surface 53.31 49.83 20.50 N/A 400.00 399.99 MinPts 53.36 49.78 20.55 N/A 420.00 419.98 MINPT-O-EOU 394.19 371.79 361.211 18.561 1970.00 1825.61 MinPt-O-SF 543.04 513.19 498.871 18.921 2460.00 2194.38 MinPt-0-SF 572.66 541.24 526.141 18.921 2560.00 2258.92 MinPt-0-SF 648.94 612.94 595.471 18551 2820.00 2407.29 MinPt-0-SF 1391.80 1255.1611:7517.33 10.25 7090.00 3291.38 MinPt-O-ADP 790.53 631.08 551.85 4.98 9490.00 3552.17 OSF45.00 Enter Alert 414.77 291.27 230.011 3.381 10510.00 3513.35 MinPt-O-SF I1 305.1311 211.42 165.06 3.28 11180.00 3509.46 MinPt-CtCt 338.2711jljljljljljl 61 88.61 2.03 11560.00 3512.57 MINPT-O-EOU 372.29 177.50j1 80.601 1.92 11740.00 3513.37 MinPt-O-ADP 389.82 184.45 82.32 1.80 11820.00 3513.75 MinPt-O-SF 1288.48 951.75 793.871 4.011 14460.00 3505.47 MinPt-O-SF 1305.8711 978.6111 812.4711 3.981 15070.00 3490.73 MinPts 1328.42 993.08j1 825.901 3.97 15400.00 3494.47 MinPt-O-ADP 1329.01 993.30 825.9311 3.571 15410.00 3494.59 MinPt-O-SF 1346.391 993.9011 818.1511 3.831 15890.00 3491.67 MinPts 1252.621 884.7911 701.3711 3.411 16540.00 3484.85 MinPts 11 1087.2211 689.21 490.70 2.74 17890.00 3427.57 MinPt-CtCt 1090.131 686 5.1 485.31 2.71 18030.00 3425.52 MINPT-O-EOU 1094.57 887.5411 484.5211 2.691 18160.00 3424.25 MinPts 11 1067.9511 653.3811 446.5611 2.581 18666.14 3428.80 MinPts OP18-08PB2(Def Survey) Warning Alert 55.91 54.69 23.10 N/A 0.00 0.00 Surface 53.31 49.83 20.50 N/A 400.00 399.99 MinPts 53.36 49.76 20.55 N/A 420.00 419.98 MINPT-O-EOU 394.19 371.80 361.21 18.561 1970.00 1825.61 MinPt-O-SF 543.04 513.19 498.87 18.931 2480.00 2194.38 MinPt-O-SF 572.66 541.24 526.15 18.931 2560.00 2258.92 MinPt-O-SF 648.94 612.94 595.48 18.551 2820.00 2407.29 MinPt-O-SF 1391.80 1255.1711 1187.351 10.25 7090.00 3291.36 MinPt-O-ADP 790.53 631.10 551.87 4.98 9490.00 3552.17 OSF<5.00 Enter Alert 414.77 291.28 230.03 3.381 10510.00 3513.35 MinPt-O-SF II 305.1311 211.43 165.07 3.28 11180.00 3509.46 MinPt-CtCt 338.2711 171.5211 88.64 2.03 11560.00 3512.57 MINPT-O-EOU 372.29 177.521 80.631 1.92 11740.00 3513.37 MinPt-O-ADP 389.82 184.51 82.35 1.90 11820.00 3513.75 MinPt-O-SF 1268.48 951.78 793.931 4.011 14460.00 3505.47 MinPt-O-SF Drilling Office 2.5.1100.0 Nikaitchuq\Oliktok Point\0124-08\0124-08\0124-08(P10b) 12/22/2011 2:38 PM Page 1 of 11 Offset Trajectory Separation Allow Sep. Reference Trajectory Risk Level Alert Status Ct-Ct(ft)i EOU(ft Dev.(ft) Fact. MD(ft) I TVD(ft) Alert I Minor I Major 1305.87 976.65 812.531 3.981 15070.00 3480.73 MinPts 1328.42 993.121 825.961 3.97 15400.00 3494.47 MinPt-O-ADP 1328.01 993.34 825.9911 3.97 15410.00 3494.59 MInPt-O-SF 1346.39 993.9511 818.2111 3.83 15890.00 3481.67 MlnPts 1252.62 884.8311 701.4311 3.41 16540.00 3484.85 MinPts 1241.88 876.6711 694.5711 3.41 16600.00 3483.91 MinPts 1085.06 691.0011 4944611 2.76 17660.00 3431.78 • MinPts 11 1082.031 686.98 489.95 2.74 17770.94 3429.31 MInPt-CtCt 1084.201 684.1211 484.58 2.71 17840.00 3428.30 MINPT-O-EOU • 1085.64 684.4111 484.2911 2.71 17860.00 3428.01 MinPt-O-ADP 1089.63 886.50 485.4211 2.71i1 17900.00 3427.42 MinPt-O-SF 1402.89 1039.48 85827 3.87 18666.14 3428.80 TD • OP17-02(Del Survey) Warning Alert 63.92 62.70 31.11 N/A 0.00 0.00 Surface 62.27 58.86 29.471 N/A 330.00 330.00 MinPts 62.461 58.73 29.65 N/A 380.00 380.00 MINPT-O-EOU 11 429.001 395.34 379.01 13.10 3130.00 2544.49 MinPt-CtCt 431.01j1 393.1911 374.77 11.67 3240.00 2582.13 MINPT-O-EOU 432.63 3933911 374.2711 11.28 3280.00 2594.34 MinPt-O-ADP 583.73 511.84 476.3811 8.2211 4500.00 2839.78 MinPt-O-SF 624.95 543.1011 502.6711 7.72 4900.00 2931.12 MinPt-O-ADP 641.79 556.36 514.1311 7.5911 5140.00 2972.50 MinP1.0-SF 648.1211 559.4311 515.581 7.38 5210.00 2983.95 MinPts 725.23 606.1111 547.041 6.13 6400.00 3178.53 MinPt-O-ADP 750.48 623.38 560.3211 5.94i1 6790.00 3242.30 MinPt-O-SF 1 993.981 841.02 765.03 6.53 8590.00 3488.95 MinPt-CtCt 968.53 797.76 712.8611 5.701 9110.00 3543.61 MinPt-O-SF 950.62 768.5211 677.9611 5.241 9710.00 3550.09 MinPts 950.5311 768.5011 677.98 5.24 9720.00 3549.97 MINPT-O-EOU • 11 950.5111 768.73 678.33 5.25 9730.00 3549.83 MinPt-CtCt 1007.99 805.51 704.76 5.00 10490.00 3513.87 OSF<5.00 Enter Alert 11 1003.1011 798.63 696.89 4.92 10710.00 3508.15 MinPt-CtCt 1003.3411 798.4111 696.44 4.91 10760.00 3506.88 MINPT-O-EOU 1003.55 798.451 696.4011 4.91 10780.00 3506.36 MinPt-O-ADP 1003.99 798.67 696.50 4.91 10810.00 3505.85 MInPt-O-SF • 1011.52 808.37 707.29 5.00 10970.00 3506.95 OSF>5.00 Exit Alert 1036.04 827.82 724.20 4.99 11230.00 3510.05 OSF<5.00 Enter Alert ' 1039.38 828.751 11 4.95 11270.00 3510.53 1054.4211 832.1411 72149 4.76 11530.00 3512.43 M NIPT-O-EOU 1056.05 832.4011 721.0711 4.74 11610.00 3512.79 MInPt-O-ADP 1059.48 834.59 722.641 4.731 11720.00 3513.28 MinPt-0-SF 1076.95 850.74 738.131 4.781 11970.00 3518.36 MinPt-O-SF 1113.92 877.6811 760.0511 4.73 12350.00 3533.90 MinPt-O-ADP 1130.14 883.2811 760.35 4.59 12600.00 3541.62 MINPT-O-EOU 1133.37 884.2011 760.1111 4.56 12700.00 3544.26 MinPt-O-ADP 1134.85 885.33 761.061 4561 12740.00 3545.32 MinPt-O-SF 1144.62 - 892.34 766.701 4.551 12930.00 3549.69 MinPt-O-SF 1185.42 907.021 778.311 4.52 13240.00 3545.07 MinPt-O-ADP 1173.47 909.441 777.921 446 13417.78 3541.90 MinPt-O-ADP 1176.42 911.59 779.6711 4.4511 13480.00 3540.22 MinPt-O-SF 11 1177.7111 893.73 75223 4.16 13900.00 3518.91 MinPt-CICt 1178.2211 893.17i1 751.14 4.14 13950.00 3516.80 MINPT-O-EOU 1178.73 893.2611 751.0111 4.14 13970.00 3516.02 MinPt-O-ADP MIMI 874.13 726.37 3.96 14170.00 3510.44 J MinPt-CtCt 1171.081 725.76 3.95 14210.00 3509.82 MINPT-O-EOU 1171.98 874.0r IMINE 3.94 14250.00 3509.25 MinPt-O-ADP • 1175.09 874.83=MIE 3.92 14330.00 3508.00 MinPt-O-ADP 11 1178.86i1 870.08 716.18 3.83 14580.00 3503.11 MinPt-CtCt 1178.08 867.2911 712.3811 3.8011 14680.00 3500.04 MinPts 1 1166.3611 847.18 688.09 3.66 15060.00 3490.70 MinPt-CtCt 1169.311 844.6411 682.80 3.61 15230.00 3492.51 MINPT-O-EOU 1172201 845.0211 681.9211 3.591 15340.00 3493.78 MinPts 11 11104111 750.89 571.63 3.09 16536.77 3484.88 MinPt-CtCt 882.77 492.57 297.97 2.271 17960.00 3426.54 MinPt-O-SF 882.33 492.3711 297.891 2.27 17070.00 3426.40 MinPt-O-ADP 882.0011 492.3411 298.00 2.27 17980.00 3426.25 MINPT-O-EOU 11 881.6911 492.76 298.78 2.27 18000.00 3425.96 MinPt-CtCt 1102.88 812.97 668.51 3.81 18666.14 3428.80 TD OP17-02PB1(Def Survey) Warning Alert 63.92 62.70 31.11 N/A 0.00 0.00 Surface 62.27 58.8611 29.4711 N/A 330.00 330.00 MinPts 62.461 58.731 29.65 N/A 360.00 360.00 MINPT-O-EOU it 429.001 395.35 379.01 13.10 3130.00 2544.49 MinPt-CtCt 431.0111 393.1911 374.77 11.67 3240.00 2582.13 MINPT-O-EOU 432.63 393.40j1 374.2811 11.29 3280.00 2594.34 MinP1-0-ADP 583.73 511.85 476.4011 82211 4500.00 2839.78 MinPt-O-SF 824.95 543.1111 502.6811 7.72 4900.00 2931.12 MinPt-O-ADP 641.79 556.37 514.1511 7.5911 5140.00 2972.50 MinPt-O-SF 648.1211 559.4411 515.591 7.38 5210.00 2983.95 MinPts 725.23 606.1311 547.061 6.13 6400.00 3178.53 MinPt-O-ADP 750.48 623.39 560.34j1 5.94i1 6790.00 3242.30 MinPt-O-SF 11 993.9811 841.03 765.05 6.53 8590.00 3488.95 MinPt-CtCt 968.53 797.77 712.8811 5.70i1 9110.00 3543.61 MinPt-O-SF 11 953.56i1 772.76 682.86 5.30 9690.00 3550.28 MinPt-CtC1 Drilling Office 2.5.1100.0 Nikaitchuq\Oliktok Point\0124-08\0124-08\0124-08(P10b) 12/22/2011 2:38 PM Page 2 0111 • • Offset Trajectory Separation Allow Sep. Reference Trajectory Risk Level Alert Status Ct-Ct(ft) EOU(ft Dev.(ft) Fact. MD(ft) 1 TVD(ft) Alert I Minor I Major 953.801 772.4 682.32 5.28 9740.00 3549.64 MINPT-O-EOU 954.05 772.5311 682.2611 5.28 9760.00 3549.17 MinPt-O•ADP 949.81 758.82 663.82 4.99 9950.00 3539.69 OSF<5.00 Enter Alert 940.97 744.66 647.0011 4.8111 10240.00 3523.24 MinPt-O-SF 940.43 744.3411 646.7911 4.82 10270.00 3521.54 MinPt-O-ADP 940.3211 744.3111 648.80 4.82 10280.00 3520.97 MINPT-O-EOU 11 940.22i1 744.39 648.96 4.82 10300.00 3519.85 MinPt-CtCt 950.22 752.83 854.621 4.831 10600.00 3511.01 MinPt-O-SF 965.06 784.21 664.271 4.821 10810.00 3505.85 MInPt-O-SF 982.00 784.47 686.20 4.99 10980.00 3507.07 OSFx5.00 Exit Alert 998.74 798.01 698.14 5.00 11100.00 3508.50 OSF<5.00 Enter Alert 1019.28 802.5811 694.7211 4.72 11380.50 3511.77 MinPt-O-ADP 1021.96 804.57 696.3611 4.7211 11440.00 3512.03 MinPt-O-SF 1040.1' 810.20 695.69 4.54 11850.00 3514.15 MINPT-O-EOU 1044.92 807.36 689.07 4.41 12140.00 3525.31 MinPts 1045.06 807.46 689.15 11111111n1 12150.00 3525.72 MInPt-O-SF 1059.14 816.93 696.31 IMERC 12490.00 3538.71 MInPt-O-SF 1105.74 851.55 724.94 immin13090.00 3547.75 MinPt-O-SF 1122.0:=REIE=MB 4.25 13340.00 3543.29 MinPts 1123.95 858.86 726.81 a13420.00 3541.86 MinPt-O-SF 1128.82 859.89=Erg 4.21 13538.00 3537.65 MinPts Nang 842.88 700.53 3.96 13930.00 3517.62 MinPt-CtCt 1128.60 maws 70042 3.96 13940.00 3517.21 MINPT-O-EOU 1128.70 842.83 700.38 3.96 13950.00 3516.80 MInPt-O-ADP 1129.73 843.49 700.86 MIME 13990.00 3515.28 MinPt-O-SF 1142.8611 848.3511 701.58 3.89 14170.00 3510.44 MINPT-O-EOU 11 1116.4411 805.02 649.79 3.59 14660.00 3500.56 MinPt-CtCI 1117.0411 804.3411 648.48 3.58 14710.00 3499.24 MINPT-O-EOU 1117.94 804.4911 648.2611 3.57 14740.00 3498.43 MinPt-O-ADP 1134.41 814.33 654.781 3.551 15000.00 3491.26 MinPt-O-SF 1139.55 817.98 657.6991 3.551 15070.00 3490.73 MinPt-O-SF 1140.37 814.0911 651.4411 3.501 15370.00 3494.13 MinPts 1071.57 709.58 529.081 2.971 16740.00 3478.95 MinPt-O-SF 11 638.6411 228.411 23.79 1.56 1866614 3428.80 MinPts OP16-03(Del Survey) Warning Alert 71.91 70.68 39.10 N/A 0.00 0.00 Surface 71.90 70.41 39.10 N/A 110.00 110.00 MinPts 72.191 69.26 39.38 N/A 320.00 320.00 MINPT-O-EOU 69.861 52.851 N/A 2010.00 1858.54 MinPts 86.511 69.291 53.70 N/A 2090.00 1923.21 MINPT-O-EOU 8840 69.67 55.59 N/A 2160.00 1978.14 OSF<5.00 Enter Alert 100.99 77.64 66.501 4.481 2360.00 2125.94 MinPl-O-SF 124.54 96.28 82.681 4.541 2560.00 2258.92 MinPI.O-SF 11 193.3211 130.13 99.03 3.09 3670.00 2679.91 MinPt-CtCt 194.9111 126.7011 93.08 2.88 3880.00 2720.36 MINPT-O-EOU 199.05 127.5211 52.2511 2.81 4020.00 2747.32 Min%-O-ADP 215.02 135.69 96.511 2.731 4390.00 2818.59 MinP1-0-SF 225.00 141.90 100.851 2.731 4760.00 2898.48 MinP1-0-SF 188.08 109.12 70.12 2.40 5450.00 3023.19 MinP1-0-SF 185.39 107.8511 69.571 2.41 5500.00 3031.37 MinPt-O-ADP 181.1311 107.1211 70.60 2.47 5590.00 3048.08 MINPT-O-EOU 11 172.6511 119.20 92.97 3.27 5910.00 3098.41 MinPt-CtCt 196.65 152.8011 131.37i1 4.56 6490.00 3193.25 MinPt-O-ADP 356.17 245.27 190.3011 3.2311 7660.00 3381.11 MinP1-0-SF 837.77 868.64 584.56 4.98 8750.00 3505.67 OSF'5.00 Exit Alert 1378.24 1193.09 1101.001 7.481 10230.00 3523.81 MinPt-O-SF MIIMI 1117.76 1013.67 6.37 10880.00 3505.88 MinPt-CtCt 1329.,.10 1006.04 6.17 11030.00 3507.67 MinPts 1330.39 1113.95 1006.22 111111111.131M 11040.00 3507.79 MInPt-O-SF 1334.61 MEM MI= 6.06 11380.00 3511.76 MinPts 1*88*l 1109.27 997.63 5.97 11520.00 3512.39 MinPt-CtCt 1338.2:®r'°' 988.76 5.76 11760.00 3513.46 MINPT-O-EOU 1340.92 1105.34 988.04 5.71 11820.00 3513.75 MInPt-O-ADP 1341.43 1105.51 988.04® 11830.00 3513.85 MinPt-O-SF 1352.32=mac 990.05 5.61 12150.00 3525.72 MINPT-O-EOU 1355.37 1110.92 989.1• 5.56 12220.00 3528.58 MinPt-O-ADP 1361.99 1113.80 990.20 5.51 12340.00 3533.49 MinPt-O-ADP 1405.05 1141.10 1009.611 12710.00 3544.53 MInPt-O-SF 2019.6, 1709 8311116.54 14640.00 3501.08 MinPls 2027.88 1713.6:MEM 6.47 14730.00 3498.70 MinPt-O-ADP MEnEl 1899.10 1535.03 8.18 15310.00 3493.43 MinPt-ClCI 2028.56 1698.73 1534.30 6.17 15360.00 3494.01 MINPT-O-EOU 2028.88 1698.7:11111111 8.16 15380.00 3494.24 MinPt-O-ADP 2034.60 1702.72 1537.27 15530.00 3495.96 MinPt-O-SF 2055.27 1718.90® 613 15720.00 3494.67 MinPts 2060.85 1723.55 1555.39 morip 15770.00 3493.79 MinPt-O-SF 2152.77 1801.63 1626.56 6.15 16340.00 3486.56 MinPt-O-ADP 2161.67 1805.3311111111 608 16410.00 3485.96 MinPt-O-ADP 2180.57 M=j1MOMIMIIIINEI 16650.00 3482.50 MinPts 2172.90 1805.96 1622.98 16750.00 3478.55 MinPts 2155.48 1798.90 1621.10 6.06 16820.00 3475.72 MinPt-O-SF 2076.93 min mirm Emu 17100.42 3464.00 MinPts 1945.62 1555.49 1360.92 5.00 17900.00 3427.42 OSF<5.00 Enter Alert 11 1943.3211 1545.83 1347.58 4.90 18120.00 3424.28 MinPt-CtCt 1943.8711 1342.2811 4.85i1 18250.00 3425.05 MinPts Drilling Office 2.5.1100.0 Nikaitchuq\Oliktok Point\0124-08\0124-08\0124-08(P10b) 12/22/2011 2:38 PM Page 3 of 11 Offset Trajectory Separation Allow Sep. Reference Trajectory, Risk Level Alert Status ' Ct-Ct(ft) EOU(ft Dev.(ft Fact. MD(ft) I TVD(ft) Alert I Minor I Major 1940.011 1540.2 1340.9 4.861 18340.00 3425.86 MinPts 1 1915.9911 1506.0911 1301.6311 4.681 18666.14 3428.80 MinPts OP18-08PB1(Def Survey) Pass 55.91 54.69 23.10 N/A 0.00 0.00 Surface 53.31 49.83 20.50 N/A 400.00 399.99 MinPts 53.36 49.76 20.55 N/A 420.00 419.98 MINPT-O-EOU 1 8656.31 8633.26 8622.25 393.031 10769.26 3506.62 MinPt-O-SF 1 9596.94 9571.28 9558.97 389.601 11809.27 3513.68 MinPt-O-SF 11087.05 11057.82 11043.72 393.181 13417.78 3541.90 MinPt-O-SF 11329.90 11300.21 11285.88 395.301 13680.00 3530.16 MinPt-O-SF 11394.85 11364.99 11350.58 395.281 13750.00 3526.47 MinPt-O-SF 11822.33 11792.10 11777.49 404.751 14200.00 3509.97 MinP1-0SF 16195.35 16162.67 16146.85 511.71 18666.14 3428.80 TD OP14-S3(Def Survey) Pass 87.94 86.71 55.13 N/A 0.00 0.00 Surface , 1 87.731 85.4711 N/A 240.00 240.00 MinPts 87.71 85.10 54.91 N/A 310.00 310.00 MinPis 87.73 85.08 54.92 N/A 320.00 320.00 MINPT-O-EOU 444.04 421.73 411.191 21.001 2090.00 1923.21 MinPt-O-SF 6002.95 5952.93 5928.411 122.391 8840.00 3515.08 MinPt-O-SF 11 6502.8311 8212.29 6067.51 22.45 14550.00 3503.36 MinPt-CtCt • 6503.2811 6211.6611 6066.64 22.39 14590.00 3502.36 MINPT-O-EOU 6503,81 6211.9511 6066.511 22.36 14610.00 3501.85 MinPt-O-ADP 6515.141 6217.8911 6069.751 21.99 14770.00 3497.61 MinPts 6657.201 6330.5711 6167.741 20.44 0 3489.74 MinPts 11 6440.7911 6055.2611 5862.981 16.75 18666.14 3428.80 MinPts 0113-03 actual(Non-Det Survey) Pass 95.93 94.71 63.12 N/A 0.00 0.00 Surface 94.32 90.92 61.51 N/A 370.00 370.00 MinPts 94.37 90.86 61.56 N/A 390.00 389.99 MINPT-O-EOU 554.64 532.36 521.83 26.281 1910.00 1776.06 MinPt-O-SF 944.30 909.14 892.09 27.67 2770.00 2381.03 MinPt-O-SF 1155.42 1099.13 1071.47 20.87 3200.00 2569.13 MinPt-O-SF 1987.34 1916.24 1881.18 28.33 4640.00 2869.32 MinPt-O-SF 2424.13 2333.14 2288.14 26.92 5690.00 3062.44 MinPt-O-SF 2616.66 2517.50 2468.41 26.64 6170.00 3140.92 MinPt-O-SF • 2868.6511 2755.5611 2699.511 25.58 6760.00 3237.40 MinPts 3076.77 2951.31 2889.071 24.711 7330.00 3330.58 MinPt-O-SF ' 1=1 ,t11 3061.87 2986.52 21.32 8840.00 3515.08 MinPt-CtCt 1 3130.211 2926.35 2824.92 15.42 11080.00 3508.26 MinPt-CtCt 3130.3911 2926.1711 2824.55 15.40 11120.00 3508.74 MINPT-O-EOU 3130.71 2926.2311 15.38 11150.00 3509.10 MinPt-O-ADP ® 2924.09 2820.56 15.12 11250.00 3510.29 MinPt-CtCt 3134.50 280949 14.51 11670.00 3513.06 MINPT-O-EOU 3135.11 2917.62 2809.37 14.48 11710.00 3513.24 MinPt-O-ADP 3140.3: 2919.29 2809.24 14.26 11896.47 3515.40 MINPT-O-EOU • 2958.79 2687.54 2552.41 10.941 13750.00 3526.47 MinPt-O-SF 2958.3811 2687.2211 2552.131 10.95 13790.00 3524.36 MinPts 11 2958.3611 2887.23 2552.16 10.95 13800.00 3523.83 MinPt-CtCt 6286.09 6107.44 6018.61 35.38 18666.14 3428.80 TD OP26-DSPO2(Def Survey) Pass 11 232.0211 230.9011 199.2111 N/A 0.00 0.00 MinPts 109.871 99.54 77.06 N/A 1160.00 1135.93 MINPT-0-EOU • 1 109.86 99.69 77.05 N/A 1170.00 1145.03 MinPts 4 1329.31 1307.10 1296.49 62.59 3110.00 2537.01 MinPt-O-SF 2531.51 2499.48 2483.96 81.51 4430.00 2826.29 MinPt-O-SF 3125.62 3086.84 3067.94 82.66 5130.00 2970.87 MinPt-O-SF 3928.20 3881.74 3859.00 86.35 6120.00 3132.75 MinPt-O-SF • 4725.63 4674.67 4649.69 94.55 7070.00 3288.09 MinPt-O-SF ' 4913.13 4859.22 4832.75 92.81 7290.00 3324.06 MinPt-O-SF 5495.07 5434.27 5404.37 91.86 8080.00 3435.18 MinPt-O-SF 5889.27 5825.16 5793.60 93.281 8760.00 3506.72 MinPt-O-SF 6006.65 5940.91 5908.53 92.75 8956.80 352729 MinPt-O-SF 6061.84 5992.12 5957.76 88.191 9050.00 3537.37 MinPt-O-SF 7821.37 7541.79 7502.49 96.961 11390.00 3511.81 MinPt-O-SF 14067.05 13985.61 13945.38 174.83 18666.14 3428.80 TD OP12-01(Def Survey) Pass • 1 19.9111 118.690 87.101 N/A 0.00 0.00 MinPts • L. 119.15 115.80 86.34+ N/A 330.00 330.00 MinPts 119.34 115.80 86.53 N/A 370.00 370.00 MINPT-O-EOU 213.46 187.78 175.551 8.681 1040.00 1025.08 MinPt-O-SF 2936.27 2857.551] 2818.681 37.76 5450.00 3023.19 MinPt-O-ADP 2948.6411 2859.7711 2815.821 33.54 5480.00 3028.10 MinPts • 3255.48 3148.27 3095.16 1 _30.641 6450.00 3186.71 MinPt-O-SF ' • 3406.95 3293.96 3237.951 30.411 8840.00 3250.48 MinPt-O-SF • 3680.21 3559.96 3500.331 30.851 7470.00 3352.78 MinPt-O-SF 3742.421 3617.471 30.18 7640.00 3378.23 MinPts 3856.641 3716.0711 3646.271 27.62 8440.00 3473.27 MinPts 11 3681.0011 3454.78 3342,16 16.34 11920.00 3516.31 MinPt-CtCt 3681.3911 3454.4811 3341.52 16.29 11990.00 3519.17 MINPT-0-EOU 3681.94 3454.5911 3341.4011 16.26 12030.00 3520.81 MinPt-O-ADP • Drilling Office 2.5.1100.0 Nikaitchuq\Oliktok Point\0124-08\0124-08\0124-08(P10b) 12/22/2011 2:38 PM Page 4 of 11 ir • • Offset Trajectory Separation Allow Sep. Reference Trajectory Risk Level Alert Status Ct-Ct(ft) EOU(ft(_ Dev.(ft) Fact. MD(ft) I TVD(ft) Alert I Minor I Major 3785.041 3533.34 3407.99 15.09 13350.00 3543.11 MINPT-O-EOU 3787.67 3533.781 3407.321 14.87 13390.00 3542.39 MinPt-0-ADP 11 3789.0411 3527.03 3396.07 14.47 13480.00 3540.22 MinPt-CtCt 3789.9811 3526.5811 3395.3811 14.44 13500.00 3539.45 MinPts 3790.48 3527.01 3395.7611 14.44i1 13538.00 3537.65 MinPt-O-SF 7109.42 6912.32 6814.26 36.25 18668.14 3428.80 TD 0111-01PB1(Def Survey) Pace 127.91 126.69 95.11 N/A 0.00 0.00 Surface 127.75 126.04 94.94 N/A 140.00 140.00 MlnPts 128.21 125.62 95.40 N/A 310.00 310.00 MINPT-O-EOU 387.23 331.78 314.64 10.691 1380.00 1313.57 MinPt-O-SF 3142.68 3084.01 3055.17 54.461 5100.00 2965.96 MinPt-0-SF 3429.15 3365.08 3333.54 54.35 5490.00 3029.73 MinPt-0-SF 3879.06 3808.81 3773.87 55.82 6100.00 3128.48 MinPt-O-SF 4093.59 4019.71 3983.26 56.14 6390.00 3176.90 MinPt-0-SF 4293.15 4215.74 4177.53 56.16 6660.00 3221.04 MinPt-0-SF 5043.28 4952.3411 4907.371 56.06 7680.00 3383.96 MinPts 5116.32 5023.10 4976.981 55.46 7810.00 3401.86 MinPt-O-SF 5436.291 5335.7411 5285.961 54.59 8530.00 3482.88 MinPts 5768.711_ 5652.5411 5594.951 50.08 9280.00 3553.13 MinPts 13070.01 12970.93 1292188 133.23 18666.14 3428.80 TD 0111-01(Def Survey) Pass 127.91 128.69 95.11 N/A 0.00 0.00 Surface 127.75 126.04 84.94 N/A 140.00 140.00 MinPts 128.21 125.62 05.40 N/A 310.00 310.00 MINPT-0-EOU 367.23 331.76 314.64 10.69 1360.00 1313.57 MinPt-0-SF 3142.68 3084.01 3055.17 1 5100.00 2965.98 MinPt-0-SF 3429.15 3365.08 3333.541 5490.00 3029.73 MinPt-O-SF 3879.06 3808.61 3773.871 6100.00 3129.48 MinPt-0-SF 4093.59 4018.71 3983.261 6390.00 3176.90 MinPt-0-SF 4293.15 4215.74 4177.531 6660.00 3221.04 MinPt-0-SF 5043.28 4952.35 °®r 56.06 7680.00 3383.96 MinPts 5116.32 5023.10 4976.9!1 7810.00 3401.88 MinPt-0-SF 11 4945.3611 4767.82 4679.55 28.01 10740.00 3507.38 MinPt-CtCt 4945 A211 4767.73111_ 4679.38 27.98 10769.26 3506.62 MINPT-0-EOU 4945.43 4767.74j1 4679.3811 27.98 10770.00 3506.60 MInPt-0-ADP 4963.51 4784.40 4695.341 27. 1 11170.00 3509.34 MinPt-0-SF 9903.10 9762.01 9681.96 70.68 18886.14 3428.80 TD OP10-09(Def Survey) Pass I 135.92 134.69 103.11' N/A 0.00 0.00 MinPts 136.31 134.22 103.50 N/A 200.00 200.00 MINPT-0-EOU 285.66 260.26 248.17 11.77 1060.00 1043.75 MinPt-0-SF 1426.45 1300.46 1373.00 _ 40.81 2890.00 2442.17 MinPt-0-SF 1814.64 1769.38 1747,24 40.97 3420.00 2630.75 MinPt-0-SF 1857.86 1811.55 1788.89 40.97 3482.73 2643.84 MinPt-O-SF 1965.54 1916.32 1892.20 40.72 3840.00 2674.13 MinPt-0-SF 2128.91 2075.53 2049.34 40.62 3880.00 2720.36 MinPt-0-SF 2305.01 2247.45 2219.16 40.72 4140.00 2770.44 MinPt-0-SF 2439.66 2378.58 2348.54 40.58 4340.00 2808.96 MinPt-0-SF 4382.961 4230.0111 4154.031 28.84 9240.00 3552.02 MinPts 4436.081 4270.3611 4187.991 26.92 9680.00 3550.56 MinPts 4444.091 4270.0511_ 4183.52 25.67 9770.00 3548.88 MINPT-0-EOU 4444.46 4270.1711 4183.521 25.64 9780.00 3548.58 MinPt-0-ADP 4465.5711 4280.5811 4188881 24.26 10240.00 3523.24 MinPts 4494.17 4298.6011 4201.301 23.09 10780.00 3506.36 MinPt-0-ADP 1 4308.47 4200.63 20.98 11460.00 3512.12 MinPt-CtCt 1 4284.71 4168.94 19.51 12130.00 3524.90 MinPt-CtCt 4520.651 4159.62 18.83 12530.00 3539.77 MINPT-0-EOU 1 3890.30 3742.21 14.13 14320.00 3508.17 MinPt-CtCt 4188.25 3889.03 3739.92 14.04 14380.00 3506.91 MINPT-0-EOU 4188.50 3889.011 14.03 14400.00 3506.72 MinPt-0-ADP 4227.11 Mg=1 13.72 14720.00 3498.97 MinPts 4232.98 3922.28 3767.42 [E1E1 14790.00 3487.08 MinPt-0-SF 4235.93 3923.871 13.61 14870.00 3494.81 MinPt-0-ADP 4249.52 3931.27 3772.641 15100.00 3491.01 MinPI-0-SF 4251.04 3932.4*®1 15140.00 3491.47 MinPts 4231.41: 3898.04 1® 15770.00 3493.79 MinPts 4195.3:1 3676.80 MEC 18220.00 3487.58 MinPts 4105.81111 17100.42 3464.00 MinPts 4063.5:10 3500.9:imix2 17380.00 3445.73 MinPts 3995.29 3615.58 3426.221 17680.00 3431.21 MinPt-0-SF ®111 18686.14 3428.80 MinPts OP09-S1(Def Survey) Pass mrsza111®i N/A 0.00 0.00 MinPts 144.48 141.12 111.67 N/A 330.00 330.00 MINPT-0-EOU 467.47 443.23 431.72 20.26 1330.00 1287.55 MInPt-O-SF 6416.88 6367.00 6342.551 131.221 8180.00 3443.97 MinPt-0-SF 8153.34 8076.34 8038.331 107.241 10610.00 3510.75 MinPt-0-SF 8692.9111 8591.9811 8542.0111 86.971 11358.71 3511.59 MinPts 11 8950.5511 8672.43 8533.87 32.29 14430.00 3506.11 MinPt-CICt 8950.8411 8672.1511 8533.30 32.23 14460.00 3505.47 MINPT-0-EOU 8951.30 8672.2311 8533.181 32.19 14480.00 3505.03 MinPt-0-ADP 8979.511 8688.7711 8543.881 30.99 14760.00 3497.89 MinPts Drilling Office 2.5.1100.0 Nikaitchuq\Oliktok Point\0124-08\0124-08\0124-08(P10b) 12/22/2011 2:38 PM Page 5 of 11 Offset Trajectory Separation Allow Sep. Reference Trajectory Risk Level Alert Status Ct-Ct(ft)I EOU(ft) Dev.(ft) Fact. MD(ft) I TVD(ft) Alert I Minor I Major 9131.83 8814.74r 8656.691 28.89 16000.00 3489.74 MinPt-O-ADP 9170.0011 8841.1711 8677.251 27.97 16360.00 3486.39 • MinPts 11 9002.0911 8622.0311 8432 A911 23.741 18666.14 3428.80 MinPts OP08-04(Def Survey) Pass =1 150.661 119.08 N/A 0.00 0.00 MinPts 15224 150.02 119.43 N/A 190.00 190.00 MINPT-O-EOU 1383.39 1341.16 1330.571 64.371 2600.00 2283.61 MInPt-O-SF • 5502.94 5480.17 5439.281 131.671 7370.00 3337.03 MInPt-O-SF • 5986.71 5940.94 5918.551 133.67] 790.00 3421.04 MInPt-O-SF 6044.2711 5989.0411 5963.2611 113.291 040.00 3430.59 MinPts 6311.37 6252.78 6223.9711 109.541 8470.00 3476.41 MinPt-O-SF 11 6348.3011 6176.86 6091.63 37.24 10270.00 3521.54 MinPt-CtCt • 6348.3811 6176.7311 6091.39 37.19 10300.00 3519.85 MINPT-O-EOU 6348.57 8176.771 6091.361 37.18 10330.00 3518.42 MinPt-O-ADP 6429.25 6252.07 6163.97 38.48 11310.00 3511.01 MInPt-O-SF 11162.80 11001.27 10921.01 69.53 18666.14 3428.80 TD OP08-04PB1(Def Survey) Pass IMICIEZI 150.681 119.08 N/A 0.00 0.00 MlnPts 152.24 150.02 119.43 N/A 190.00 190.00 MINPT-O-EOU • 1363.39 1341.16 1330.57 imam2600.00 2283.81 MinPt-O-SF 5502.94 540.17 5439.2:=1E1n1 7370.00 3337.03 MInPt-O-SF 5986.71 5940.94 5918.55=En 7960.00 3421.04 MInPt-O-SF 6044.27 ManEM=IMO 8040.00 3430.59 MinPts 6311.37 6252.78 6223.97=MEI 8470.00 3476.41 MInPI-O-SF 605.35 8742.56 6711.6:=Ex 9240.00 3552.02 MinPt-O-SF 7211.74 7080.1• 7014.90® 9830.00 3546.45 MinPts 13327.71 13194.13 13127.84 100.51 18666.14 3428.80 TD 0107-04(Def Survey) . Pass 1 159.91 158.8k 127.10 N/A 0.00 0.00 MinPts • 10.10s6 157.361 127.29 N/A 310.00 310.00 MINPT-O-EOU 8698.81 8676.57 8665.94 409.171 10289.31 3520.44 MInPt-O-SF 9121.26 9097.71 9086.42 404.111 1070.26 3506.62 MinPt-O-SF 9307.621 9220.3011 9177.141 107.801 10980.00 3507.07 MlnPts 9927.241 9829.5811 9781.251 102.68 11890.00 3515.18 MinPts 9940.57 9842.73 9794.31 102.631 11910.00 3515.90 MinPt-O-SF 100.73 9961.65 9912.80 102.541 12090.00 3523.26 MinPt-O-SF 10421.9211 10308.6711 10252.541 92.83 12620.00 3542.15 MinPts 10579.19 10464.18 10407.17 52.77] 12865.59 3548.64 MinPt-O-SF 11158.96 11038.83 10879.25 93.641 13750.00 3526.47 MinPt-O-SF 11411.13 11281.2811 11216.841 88.541 14100.00 3511.92 MinPts 11605.21 11472.91 11407.251 88.37 14350.00 3507.65 MInPt-O-SF 13738.78 13597.66 13528.6011 99.451 16730.00 3479.35 MinPt-O-SF •• • 13 68.86 22.1211 13649.2311 95.14] .00 3473.29 0397885.86 14 9 49j1 98.461 18290.00 3425.411 MinPb inPts ' 150 .8 140MinPt-O-SF 15340.42 15185.25 15108.16 99.49 18666.14 3428.80 TD 0106-05(Def Survey) Pass 175.90 174.68 143.10 N/A 0.00 0.00 Surface 1 175.6311 173.22111.1MI N/A 220.00 220.00 MinPis 175.63 172.81 142.82 N/A 260.00 260.00 MlnPts 176.10 172.38 143.29 N/A 340.00 340.00 MINPT-O-EOU 469.41 447.09 436.54 22.19 1220.00 1190.22 MinPt-O-SF 7428.00 7405.77 7395.191 350.931 8860.00 3496.27 MinP1.0-SF 9769.04 9743.24 9730.821 393.531 1130.00 3511.60 MinPl-O-SF 9805.11 9779.21 970.751 393.471 11400.00 3511.85 MinPt-O-SF 11366.09 11336.95 11322.881 403.75] 13100.00 3547.57 MinPt-O-SF 12387.41 12356.74 12341.901 417.221 14200.00 3509.97 MinPt-O-SF 1673329 1670.70 16684.89 529.35 18666.14 3428.80 - TD 0106-05PB1(Def Survey) Pass 175.90 174.68 143.10 N/A 0.00 0.00 Surface 1 175.631 173.2211 N/A 220.00 220.00 MinPts 175.63 172.81 142.82 N/A 260.00 260.00 MinPts 176.10 172.38 143.29 N/A 340.00 340.00 MINPT-O-EOU 469.41 447.09 436.54 22.19 1220.00 1190.22 MinPt-O-SF • 7428.00 7405.77 7395.191 350.931 8660.00 3496.27 MInPt-O-SF 9769.04 9743.24 9730.821 393.531 11360.00 3511.60 . MinPt-O-SF • 9805.11 9779.21 9766.751 393.471 11400.00 3511.85 MinPt-O-SF • 11366.09 11336.95 11322.881 403.751 13100.00 3547.57 MinPt-O-SF 12387.41 12356.74 12341.901 417221 14200.00 3509.97 MinPt-O-SF 16733.29 16700.70 16684.89 529.35 18666.14 3428.80 TD OP05-06PB2(Del Survey) Pass 183.95 182.73 151.14 N/A 0.00 0.00 Surface 183.67 181.80 150.86 N/A 150.00 150.00 MinPts 183.71 181.73 150.90 N/A 170.00 170.00 MINPT-O-EOU 9231.66 9208.97 9198.12 Mngja 1076926 3506.62 MinPt-O-SF 10165.99 10140.66 10128.4.Main 1180927 3513.68 MinPt-O-SF 10714.68 10688.19 10675.44 1111111MIC 12406.11 3538.20 MinPt-O-SF 10976.90 10949.79 10938.72 MEM 12690.00 3544.00 MinPt-O-SF 11050.96 11023.67 11010.52=us 12770.00 3548.11 MinPt-O-SF 11106.57 11079.15 11065.93 MIME 12830.00 3547.70 MinPt-O-SF 11645.68 11616.68 1102.67 Marl 13417.78 3541.90 MinPt-O-SF • • 1208.48 11978.70 11964.2. 416.88 13812.0 3523.17 MinPt-O-SF • Drilling Office 2.5.1100.0 Nikaitchuq\Oliktok Point\0124-08\0124-08\0124-08(P10b) 12/22/2011 2:38 PM Page 6 of 11 Offset Trajectory Separation Allow Sep. Reference Trajectory Risk Level Alert Status Ct-Ct(ft)I EOU(ft) Dev.(ft) Fact. MD(ft) I TVD(ft) Alert I Minor I Major 12374.95 12344.95 12330.441 426.471 14200.00 3509.97 MinPt-O-SF 16724.13 16691.76 16676.06 532.74 18666.14 3428.80 TD OP05-06(Def Survey) Pass 183.95 182.73 151.14 N/A 0.00 0.00 Surface 183.67 181.80 150.86 N/A 150.00 150.00 MinPts 183.71 181.73 150.90 N/A 170.00 170.00 MINPT-O-EOU 9231.66 9208.97 9198.121 425.35 10769.26 3506.62 MinPt-O-SF 10165.99 10140.66 10128.491 417.50 11809.27 3513.68 MinPt-O-SF 10714.68 10688.19 10675.441 420.161 12406.11 3536.20 MinPt-O-SF 10976.90 10949.79 10936.721 420.11 12690.00 3544.00 MinPt-O-SF 11050.96 11023.67 11010.521 420.07 12770.00 3546.11 MinPt-O-SF 1 11106.57 11079.15 11065.931 420.07 12830.00 3547.70 MinPt-O-SF 11645.68 11616.68 11602.671 415.61 13417.78 3541.90 MinPt-O-SF 12008.48 11978.70 11964.291 416.88 13812.65 3523.17 MinPt-O-SF 12374.95 12344.95 12330.441 426.47 14200.00 3509.97 MinPt-O-SF 16724.13 16691.76 16676.06 532.74 18666.14 3428.80 TD OP05-06PB1(Def Survey) Pass 183.95 182.73 151.14 N/A 0.00 0.00 Surface 183.67 181.80 150.86 N/A 150.00 150.00 MinPts 183.71 181.73 150.90 N/A 170.00 170.00 MINPT-O-EOU 9231.66 9208.97 9198.12 425.35 10769.26 3506.62 MinPt-O-SF 10165.99 10140.66 10128.49 417.50 11809.27 3513.68 MinPt-O-SF 10714.68 10688.19 10675.44 420.16 12406.11 3536.20 MinPt-O-SF 10976.90 10949.79 10936.72 420.11 12890.00 3544.00 MinPt-O-SF 11050.96 11023.67 11010.52 420.07 12770.00 3546.11 MinPt-O-SF 11106.57 11079.15 11065.93 420.07 12830.00 3547.70 MinPt-O-SF 11045.68 11616.68 1160267 415.61 13417.78 3541.90 MinPt-O-SF 12008.48 11978.70 11964.29 416.881 13812.65 3523.17 MinPt-O-SF 12374.95 12344.95 12330.44 426.47 14200.00 3509.97 MinPt-O-SF 16724.13 16691.76 16676.06 532.74 18668.14 3428.80 TD OPO4-07P81(Def Survey) Pass 191.90 190.67 159.09 N/A 0.00 0.00 Surface 191.12 188.53 158.31 N/A 280.00 280.00 MinPts 191.15 188.47 158.34 N/A 300.00 300.00 MINPT-O-EOU 2429.74 2407.48 2396. Min 3730.00 2691.47 MinPt-O-SF 6405.32 6349.00 6321.32® 8250.00 3453.41 MinPt-O-SF 6442.04 6385.40 6357.57® 8310.00 3459.68 MinPt-O-SF 6659.84 6600.77 6571.72 min 8860.00 3496.27 MinPt-O-SF 7222.63 7100.01 7129.1!MEE 9530.00 3551.79 MinPt-O-SF 7282.96 7219.82 7188.75 MIMI 9620.00 3550.94 MinPt-O-SF 7572.45 7503.77 7468.92 man 10050.00 3534.02 MinPt-O-SF 8805.37 8716.65 8672.78=1:IM1 11809.27 3513.88 MinPt-O-SF 9227.92 9133.10 9086.1:111111.11131E1 12406.11 3536.20 MinPt-O-SF 9538.84 9438.56 938891 96.06 12840.00 3547.96 MinPt-O-SF 10173.75 10040.36 IIS ATIg 13720.00 3528.05 MinPts 10672.27 10533.80 10465.05 MIMI 14410.00 3506.52 MinPt-O-SF 11078.47 10935.05 10863.83® 14880.00 3494.53 MinPt-O-SF 12374.29 12217.25 MIEE 16330.00 3486.64 MinPts 12674.50 12511.64 12430.70 MTEE 16678.67 3481.43 MinPt-O-SF 12683.97 12514.4: ® 16690.00 3480.97 MinPts 12708.62 12537.07 12451.78 MT11113 16720.00 3479.76 MinPt-O-SF 14221.82 14041.84 13952.34 79.45 18666.14 3428.80 TD OPO4-07(Def Survey) Pass 191.90 190.67 159.09 N/A 0.00 0.00 Surface 191.12 188.53 158.31 N/A 280.00 280.00 MinPts 191.15 188.47 158.34 N/A 300.00 300.00 MINPT-O-EOU 2420.71 2398.47 2387.8!®" 3720.00 2889.54 MinPt-O-SF 6405.32 6348.95 6321.25 Man 8250.00 3453.41 MinPt-O-SF 6659.84 6600.73 6571.68=up 8660.00 3496.27 MinPt-O-SF 7209.27 7146.73 7115.95 9510.00 3551.98 MinPt-O-SF 7572.45 7503.74 7469.88=no 10050.00 3534.02 MinPt-O-SF 8805.37 8716.63 8672.7.MME1 11809.27 3513.68 MinPt-O-SF 9227.92 9133.08 9086.15 Thgli 12406.11 3538.20 MinPt-O-SF 9538.84 9438.54 9388.8! 96.04 12840.00 3547.96 MinPt-O-SF 10173.75 10040.34 Mr3M1MZEZI 13720.00 3528.05 MinPts • 10672.27 10533.78 10465.02 14410.00 3506.52 MinPt-O-SF 11078.47 10935.03 10863.81 14880.00 3494.53 MinPt-O-SF 12374.29 12217.23®'- r 16330.00 3486.64 MinPts 12538.4:NEKEE mg=moo16520.00 3485.03 MinPts 13267.97 13086.59 12998.3,IMMO 17420.00 3443.06 MinPt-O-SF 14145.48 13958.82 13865.98 Mr= 18610.00 3428.29 MinPt-O-SF 14187.02 14000.12 13907.16 76.30 18686.14 3428.80 TD OP03-P05PB2(Def Survey) Pass 199.86 198.64 167.06 N/A 0.00 0.00 Surface 199.82 198.50 MEM N/A 70.00 70.00 MinPts 1 199.921 197.711 167.111 N/A 240.00 240.00 MinPts 200.07 197.54 167.26 N/A 300.00 300.00 MINPT-O-EOU 9111.07 9088.71 9078.021 426.231 10769.26 3506.62 MinPt-O-SF 10047.52 10022.38 10010.311 416.001 11809.27 3513.68 MinPt-O-SF 10612.97 10586.61 10573.931 418.251 12423.39 3536.85 MinPt-O-SF 10874.54 10648.04 10635.281 418.281 12490.00 3538.71 MinPt-O-SF 11530.57 11501.64 11487.671 412.571 13417.78 3541.90 MinPt-O-SF Drilling Office 2.5.1100.0 Nikaitchuq\Oliktok Point\0124-08\0124-08\0124-08(P10b) 12/22/2011 2:38 PM Page 7 of 11 0 . • Offset Trajectory Separation Allow Sep. Reference Trajectory Risk Level Alert Status ' Ct-Ct(ft)I EOU(ft) Dev.(ft) Fact. MD(ft) I TVD(ft) Alert I Minor 1 Major 11895.21 11865.46 11851.08 413.47 13812.65 3523.17 MinPt-O-SF 12263.79 12233.80 12219.301 422.841 14200.00 3509.97 MinPt-O-SF 16639.25 16606.84 16591.12 529.38 18666.14 3428.80 TD OP03-P05(Def Survey) Pass 199.86 198.64 167.06 N/A 0.00 0.00 Surface 199.82 198.50 167.01 N/A 70.00 70.00 MinPts 1 199.921 197.711 167.1111 N/A 240.00 240.00 MinPts 200.07 197.54 167.26 N/A 300.00 300.00 M1NPT-O-EOU 9111.07 9088.71 9078.02 426.23 10769.26 3508.62 MinPt-O-SF ' 10047.52 10022.38 10010.31 416.00 11809.27 3513.88 MinPt-O-SF • 10612.97 10586.61 10573.93 418.25 12423.39 3536.85 MinPt-O-SF 10874.54 10648.04 10635.28 418.28 12490.00 3538.71 MinPt-O-SF 1 11530.57 11501.64 11487.67 412.57 13417.78 3541.90 MinPt-O-SF 11895.21 11865.46 11851.08 413.47 13812.65 3523.17 MinPt-O-SF 12263.79 12233.80 12219.30 422.84 14200.00 3509.97 MinPt-O-SF 16161.5211 16001.4711 15921.9311 101.601 18180.00 3424.42 MinPts 16543.33 16381.29 16300.76 102.71 18666.14 3428.80 TD OP03-P05PB1(Def Survey) Pass 199.86 198.64 167.06 N/A 0.00 0.00 Surface 199.82 198.50 167.01 N/A 70.00 70.00 MinPts 1 199.921 197.711 167.111 N/A 240.00 240.00 MinPts 200.07 197.54 167.26 _ N/A 300.00 300.00 MINPT-O-EOU 9111.07 9088.71 9078.021 426.23 10789.26 3506.62 MInPt-O-SF 10047.52 10022.38 10010.311 416.00 11809.27 3513.68 MinPt-O-SF 10612.97 10586.61 10573.931 418.25 12423.39 3538.8.5 MinPt-O-SF 10674.54 10648.04 10635.281 418.28 12490.00 3538.71 MInP1-0-SF 11530.57 11501.64 11487.67 412.57 13417.78 3541.90 MinPt-O-SF 11895.21 11865.46 11851.081 j 41347 13812.85 3523.17 MInPt-O-SF 12263.79 12233.80 12219.301 422.84 14200.00 3509.97 MInP1-0-SF 16639.25 16606.84 16591.12 529.38 18666.14 3428.80 TO Oliktok Point I-2PB2(Def Survey) Pass 208.41 207.34 175.61 NIA 0.00 0.00 Surface 1 208.411 207.341 175.611 N/A 40.00 40.00 MinPts 205.68 202.60 172.87 N/A 420.00 419.98 MinPts 464.08 439.14 427.21 19.401 2020.00 1886.73 MinPt-O-SF 706.60 672.47 855.89 21.281 2830.00 2301.68 MinPt-O-SF 1242.55 1173.35 1139.23 18.201 4150.00 2772.36 MinP1-0-SF 1367.11 1288.73 1250.03 17.651 4500.00 2839.78 MinPt-O-SF 1985.93 1848.76 1780.67 14.581 7080.00 3289.72 MinP1-0-SF 2137.5011 1987.1611 1912.481 14.31 780000 3400.53 MinPts 11 2115.9711 1962.43 1886.16 13.86 8490.00 3478.50 MinPt-CtCt • 2115.9911 1962.4211 1886.131 13.86 8500.00 3479.54 MinPts 2117.08 1962.8411 1886.211 13.81 8590.00 3488.95 MInPt-O-ADP 11 2118.9211 1959.58 1880.40 13.37 8730.00 3503.58 MinPt-CtCt 2119.0011 1959.4911 1880.23 13.36 8760.00 3508.72 M1NPT-O-EOU 2119.07 1959.5011 1880.2211 13.36 8770.00 3507.76 MinPt-O-ADP • 2120.88 1960.86 1881.331 13.331 8870.00 3518.22 MinPt-O-SF 2134.24 1971.83 1891.121 13.221 9140.00 3548.20 MinP1.0-SF 2158.59 1995.15 1913.921 13281 9400.00 3553.02 MinPt-O-SF 2200.65 2026.96 1940811 12.741 9760.00 3549.17 MinPt-O-SF 2278.1011 2084.4111 1988.06 11.82 10377.96 3516.78 MINPT-O-EOU 2283.99 2085_6611 1986.991111.57 10540.00 3512.57 MinPi-O-ADP • 2290.17 2088.99 1988.89 11.431 10700.00 3508.41 MinPI-O-SF • 8623.17 8554.69 8520.94 127.74 18666.14 3428.80 TD Oliktok Point I-2PB1(Def Survey) Pass 208.41 207.34 175.61 N/A 0.00 0.00 Surface 1 208.411 207.341 175.611 N/A 40.00 40.00 MinPts 205.68 202.60 172.87 N/A 420.00 419.98 MinPts 464.08 439.14 427.21 19.401 2020.00 1866.73 MinPt-O-SF 706.60 672.47 655.89 21.281 2630.00 2301.69 MinPt-O-SF 1242.55 1173.34 1139.23 18201 4150.00 2772.36 MinPt-O-SF 1339.14 1262.56 1224.77 17.701 4420.00 2824.37 MinPt-O-SF 1848.93 1543.48 1491.25 15.781 5740.00 3070.81 MinPt-O-SF 1795.12 1678.41 1620.55 15.501 6330.00 3167.09 MinPt-O-SF 1911.54 1786.30 1724.18 15.381 6750.00 3235.76 MinPt-O-SF ' 1962.97 1833.51 1769.27 15.271 6930.00 3265.19 MinPt-O-SF 2031.73 1897.92 1831.51 15.291 7170.00 3304.44 MInPt-O-SF 2070.04 1933.69 186801 15.291 7300.00 3325.69 MinPt-O-SF 11433.69 11393.30 11373.60 290.16 18666.14 3428.80 TO Oliktok Point 1-2(Def Survey) Pass 208.41 207.34 175.61 N/A 0.00 0.00 Surface 1 208.411 207.341 175.611 N/A 40.00 40.00 MinPts 205.68 202.60 172.87 N/A 420.00 419.98 MinPts 464.08 439.14 427.21 19.401 2020.00 1888.73 MinPt-O-SF 706.60 672.47 655.89 21.281 2630.00 2301.69 MinPt-O-SF 1242.55 1173.34 1139.23 18.201 4150.00 2772.36 MinPt-O-SF 1367.11 1288.73 1250.03 17.651 4500.00 2839.78 MinPt-O-SF 1985.93 1848.76 1780.66 14.581 7080.00 3289.72 MinPt-O-SF 2137.5011 1987.1611 1912 A81 14.30 7800.00 3400.53 MinPts 11 2115.9711 1962.43 1886.15 13.86 8490.00 3478.50 MinPt-CtCt Drilling Office 2.5.1100.0 Nikaitchuq\Oliktok Point\0124-08\0124-08\0124-08(P10b) 12/22/2011 2:38 PM Page 8 of 11 111110 • r Offset Trajectory Separation Allow Sep. Reference Trajectory Risk Level Alert Status Ct-Ct(ft)0111 EOU(ft) Dev.(ft� Fact. MD(ft) TVD(ft) Alert Minor Major 2115.9 1962.42 1886.13 13.88 8500.00 3479.54 MinPts 2117.08 1962.841 1886.211 13.81 8580.00 3488.95 MinPt-O-ADP 11 2118.9211 1959.58 1880.40 13.37 8730.00 3503.58 MinPt-CtCt 2119.0011 1880.22 13.36 8760.00 3506.72 MINPT-O-EOU 2119.07 1959.5011 1880.211 13.36 8770.00 3507.76 MinPt-O-ADP 2120.88 1960.85 1881.33 13.331 8870.00 3518.22 MinPt-O-SF 2134.24 1971.82 1891.11 13.211 9140.00 3546.20 MinPt-O-SF 2158.59 1995.14 1913.91 13.281 9400.00 3553.02 MinPt-O-SF 2200.85 2026.96 1940.60 12.741 9760.00 3549.17 MinPI-O-SF 2263.28 2079.12 1987.53 12.351 10230.00 3523.81 MinPl-O-SF 2267.641 2078.601 1984.57 12.05 10270.00 3521.54 MINPT-O-EOU 2270.171 2078.571 1983.2711 11.90 10310.00 3519.34 MinPts 2276.651 2080.701 1983.22 11.67 10450,00 3514.91 MINPT-O-EOU 2277.01 2080.701 1983.041 11.65 10460.00 3514.65 MinPt-O-ADP 2284.8611 2081.351 1980.08 11.28 10710.00 3508.15 MINPT-O-EOU 2285.08 2081 A21 1980.0811 11.27 10720.00 3507.89 MinPt-O-ADP 2300.72 2092.70 1989.1911 /1.11i1 11100.00 3508.50 MinPt-O-SF 2330.3511 2114.421 2006.9411 10.84 11400.00 3511.85 MinPts 11 2319.8211 2088.42 1973.21 10.06 11830.00 3513.85 MinPt-CtCt 2319.9111 2088.331 1973.03 10.06 11860.00 3514.36 MINPT-O-EOU 2320.07 2088.371 1973.0111 10.05 11880.00 3514.87 MinPt-O-ADP 2325.88 2093.15 1977.28j1 /0.03i1 12080.00 3522.86 MinPt-O-SF 2345.2'IMEME1 1978.22 9.61 12440.00 3537.38 MINPT-O-EOU 2345.95 2100.38 1978.08 959 12480.00 3538.45 MinPt-O-ADP 2351.38 2104.74 1981.92 m r KE 12640.00 3542.68 MinPt-O-SF 2363.94 2115.80 1992.23 MIMI 12830.00 3547.70 MinPt-O-SF 11 2383.44i1 2116.41 1983.38 8,96 13370.00 3542.75 MinPt-CtCt 2383.9511 2115.4811 1981.75 8.91 13460.00 3540.88 MINPT-O-EOU 2384.25 2115.5311 1981.661 8.90 13476.44 3540.35 MinPt-O-ADP 2396.00 2124.80 1989.69 8.861 13710.00 3528.58 MinPt-0-SF 6117.85 5970.60 5897.46 41.82 18666.14 3428.80 TD Oliktok Point I-1(Def Survey) Pass 216.45 215.34 183.64 N/A 0.00 0.00 Surface 216.45 215.34 183.64 N/A 40.00 40.00 MinPts 216.53 215.23 183.73 N/A 80.00 80.00 MINPT-O-EOU 10192.58 10167.76 10155.851 427.641 11809.27 3513.88 MinPt-O-SF 10755.61 10729.56 10717.03 L 429.061 12423.39 3536.85 MinPt-O-SF 11888.39 11839.76 11625.931 421.981 13417.78 3541.90 MinPt-O-SF 12030.44 12000.99 11986.751 422.471 13812.65 3523.17 MinPt-O-SE 12396.44 12366.75 12352.391 431.811 14200.00 3509.97 MinPt-O-SF 16746.31 16714.02 16698.37 534.89 18666.14 3428.80 TO Tuvaaq ST 1(Def Survey) Pass 17127.27 17125.35 17094.46 N/A 0.00 0.00 Surface 1 17127.211 17124.511 17094.401 N/A 160.00 160.00 MinPts 17127.661 17123.901 17094.85 N/A 300.00 300.00 MINPT-O-EOU 9898.25 9735.78 9656.581 62.461 12310.00 3532.26 MinPt-O-SF 7434.07 7137.35 6990.041 25.231 18510.00 3427.39 MinPt-O-SF 11 7399.101 7099.551 6950.901 24.881 18666.14 3428.80 MinPts Kigun 1(Def Survey) Pass 17127.27 17125.35 17094.46 N/A 0.00 0.00 Surface 1 17127.211 17124.511 17094.401 N/A 160.00 160.00 MinPts 17127.661 17123.901 17094.85 N/A 300.00 300.00 MINPT-O-EOU 10131.70 9974.25 9897.541 66.011 12000.00 3519.58 MinPt-O-SF 7469.941 7171.791 7023.52 25.18 18666.14 3428.80 MinPts Kigun 1 PB1(Def Survey) Pass 17127.27 17125.35 17094.46 N/A 0.00 0.00 Surface 1 1 17127.211 17124.511 17094.40 N/A 160.00 160.00 MinPts 17127. 1 17123.901 17094.85N/A 300.00 300.00 MINPT-O-EOU 9898.25 9735.78 9656.581 62.461 12310.00 3532.26 MinPt-O-SF 1 7520.891 7222.451 7074.14 25.35 18666.14 3428.80 MinPts SP27-N1 actual(Non-Def Survey) Pass 17136.27 16872.24 16741.31 65.43 0.00 0.00 Surface 9011.98 8340.19 8006.711 13.501 14800.00 3496.78 MinPt-O-SF 8941.67 8271.28 7938.411 13.421 15340.00 3493.78 MinPt-O-SF 8822.641 8040.501 7750.921 14.881 18666.14 3428.80 MinPts SP18-N5(Det Survey) Pass 17269.17 17261.49 17236.36 N/A 0.00 0.00 Surface 11 11722 11498.45 11386.95 52.56 14550.00 3503.36 MinPt-CtCt 11722. 11498.11 11386.24 52.39 14590.00 3502.36 MINPT-O-EOU 11723.21 11498.15 11386.20 52.35 14600.00 3502.11 MinPt-O-ADP 12373.97 12091.00 11650.01 43.881 18686.14 3428.80 MinPt-O-SF SP18-N5PB1(Dei Survey) Pass 17269.17 17261.49 17236.36 N/A 0.00 0.00 Surface 1 11722.64 11498.45 11386.95 52.56 14550.00 3503.36 MinPl-CtCt 11722.98 11498.11 11386.24 52.39 14590.00 3502.36 MINPT-O-EOU 11723.21 11498.15 11386.20 52.35 14600.00 3502.11 MinPt-O-ADP 12373.97 12091.00 11950.01 43.881 18666.14 3428.80 MinPt-O-SF SD37-DSP1(Def Survey) Pass <: Drilling Office 2.5.1100.0 Nikaitchuq\Oliktok Point\0124-08\0124-08\0124-08(P10b) 12/22/2011 2:38 PM Page 9 0111 Offset Trajectory Se.aration Allow Sep. Reference Trajectory Risk Level Alert Status • Ct-Ct(ft EOU(ft Dev.(ft)_ Fact. MD(ft) I TVD(ft) Alert I Minor I Major • 17891.47 17890.25 1785867 N/A 0.00 0.00 MinPts 17892.6:1 17889.351 17859.87 N/A 300.00 300.00 MINPT-O-EOU 11904.17 11677.71 11565.23 52.91 14690.00 3499.77 MinPt-CtCt 11904.44 11877.43 11584.86 52.78 14720.00 3498.97 MINPT-O-EOU 11904.88 11677.50 11584.54 52.69 14740.00 3498.43 MinPt-O-ADP 12282.90 11994.25 11850.41 42.701 18666.14 3428.80 MinPt-O-SF • Nikaitchuq 3(Def Survey) Pass 18565.34 18563.43 18532.53 N/A 0.00 0.00 Surface 18565.33 18563.411 18532.52 N/A 20.00 20.00 MINPT-O-EOU 1 18565.331 18563.3711 18532.521 N/A 50.00 50.00 MinPts 18566.03 18561.981 18533.22 N/A 300.00 300.00 MINPT-O-EOU 18573.31 18562.161 18540.50 N/A 750.00 747.08 MINPT-O-EOU 11 18852.331 18768.66 18727.70 230.13 5870.00 3091.87 MinPt-ClCt 18855.481 18765.5311 18721.43 213.79 6220.00 3149.10 MINPT-O-EOU 18859.29 18766.2911 18720.6611 206.67 6390.00 3176.90 MinPt-O-ADP I 11 17750.71 17545.26 17443.35 87.08 13880.00 3520.77 MinPt-CtCt 17750.90 17545.03 17442.91 86.90 13890.00 3519.37 MINPT-O-EOU 17751.06 17545.05 17442.86 86.84 13900.00 3518.91 MinPt-O-ADP 19463.96 19200.77 19069.98 74.401 18666,14 3428.80 MinPt-O-SF Nikaitchuq 3P83(Def Survey) Pass 18565.34 18563.43 18532.53 N/A 0.00 0.00 Surface 18565.33 111E=11 18532.52 N/A 20.00 20.00 MINPT-O-EOU N/A 50.00 50.00 MinPts ' 1856803 18561.98 18533.22 N/A 300.00 300.00 MINPT-O-EOU 18573.31 18562.16 18540.50 N/A 750.00 747.08 MINPT-O-EOU IMME1 18768.66 18727.70 230.13 5870.00 3091.87 MinPt-CtCt 18855.4: 18721.43 213.79 6220.00 3149.10 MINPT-O-EOU 18859.29 18766.29 18720.6. 208.67 6390.00 3176.90 MinPt-O-ADP 11 17750.71 17545.26 17443.35 87.08 13860.00 3520.77 MinPt-CtCt i 17750.90 17545.03 17442.91 86.90 13890.00 3519.37 MINPT-O-EOU 17751.06 17545.05 17442.86 86.84 13900.00 3518.91 MinPt-O-ADP 19483.96 19200.77 19089.98 74.401 18666.14 3428.80 MinPt-O-SF Nikaitchuq 3PB1(Del Survey) Pass- 18565.34 18563.43 18532.53 N/A 0.00 0.00 Surface 18565.33 18563.411 18532.52 N/A 20.00 20.00 MINPT-O-EOU 1 18565 331 18563.3711 18532.521 N/A 50.00 50.00 MinPts 1856603 18561.981 18533.22 N/A 300.00 300.00 MINPT-O-EOU ' 18573.31 18562.161 18540.50 N/A 750.00 747.08 MINPT-O-EOU 2.331 1876886 18727.70 230.13 91.87 MinPt-Ctet U 18855.481 18765.5311 18721.43 213.79 6220.00 314 t 9.110 MINPT-O-EOU 18859.29 18766.2911 18720.6611 206.67 6390.00 3176.90 MinPt-O-ADP 1 17750.71 17545.26 17443.35 87.08 13860.00 3520.77 MinPt-CtCt 17750.90 17545.03 17442.91 86.90 13890.00 3519.37 MINPT-O-EOU 17751.06 17545.05 17442.86 86.84 13900.00 3518.91 MinPt-O-ADP 19463.96 19200.77 19069.98 74.401 18666.14 3428.80 MinPt-O-SF Nikaitchuq 3PB2(Def Survey) Pass 185655.34 18563.43 18532.53 N/A 0.00 0.00 Surface 18565.331 18563.411 18532.52 N/A 20.00 20.00 MINPT-O-EOU 18565.331 18563.371 18532.521 N/A 50.00 50.00 MinPts 18568.031 18561.981 18533.22 N/A 300.00 300.00 MINPT-O-EOU 18573.311 18562.161 18540.50 N/A 750.00 747.08 MINPT-O-EOU 1jjjjjjj,= 18768.66 18727.70 230.13 5870.00 3091.87 MinPt-CtCt 18855.4811 18765.531 18721.43 213.70 6220.00 3149.10 MINPT-O-EOU 18859.29 18766.291�l11 206.87 6390.00 3176.80 MinPt-O-ADP 11 17750.71 17545.28 17443.35 87.08 13860.00 3520.77 MinPt-CtCt 17750.90 17545.03 17442.91 88.90 13890.00 3519.37 MINPT-O-EOU 17751.06 17545.05 17442.86 86.84 13900.00 3518,91 MinPt-O-ADP 19463.96 19200.77 19069.98 74.401 18666.14 3428.80 MinPt-O-SF Nikaitchuq 4(Del Survey) Pass 1 18604.56 18573.67 N/A 0.00 0.00 Surface 18606.47 18604.551 18573.65 N/A 20.00 20.00 MINPT-O-EOU 1 18606.461 18604.5011 18573.651 N/A 50.00 50.00 MinPts • 18607,471 18603.501 18574.66 N/A 300.00 300.00 MINPT-O-EOU 18615.9 18604.881 18583.18 N/A 750.00 747.08 MINPT-O-EOU 11 18938.301 18861.45 18823.91 252.20 5500.00 3031.37 MinPt-CtCt 18941.451 18858.3811 18817.73 232.93 5850.00 3088.60 MINPT-O-EOU 18945.27 18859.1611 18816.9911 224.59 6020.00 3116.40 MinPt-O-ADP 1 17904.31 17693.93 17589.54 85.75 13960.00 3516.41 MinPt-CtCt 17904.61 17693.64 17588.95 85.51 14000.00 3514.92 MINPT-O-EOU 17904.80 17693.68 17588.92 85.45 14010.00 3514.57 MinPt-O-ADP I 19360.72 19088.82 18953.68 71.621 18066.14 3428.80 MinPt-O-SF Nikaitchuq 4PB1(Def Survey) Pass 18606.47 18604.56 18573.67 N/A 0.00 0.00 Surface 18606.4 18604.551 18573.65 N/A 20.00 20.00 MINPT-O-EOU 1 18606.461 18604.5011 18573.651 N/A 50.00 50.00 MinPts 18807.47 18603.501 18574.66 N/A 300.00 300.00 MINPT-O-EOU 18615.99 18604.881 18583.18 N/A 750.00 747.08 MINPT-O-EOU 11 18938.301 18861.45 18823.91 252.20 5500.00 3031.37 MinPt-CtCt 18941.451 18858.3811 18817.73 232.94 5850.00 3088.60 MINPT-O-EOU 18945.46 18859.1911 18816.9311 224.14 6030.00 3118.03 MinPt-O-ADP 17766.93 17685.58 88.65 13830.00 3522.27 MinPt-CtCt Drilling Office 2.5.1100.0 Nikaitchuq\Oliktok Point\0124-08\0124-08\0124-08(P10b) 12/22/2011 2:38 PM Page 10 of 11 Offset Trajectory Separation Allow Sep. Reference Trajectory Risk Level Alert Status Ct-Ct(ft) EOU(ftj. Dev.(ft)_ Fact. MD(f11 TVD(ft) Alert I Minor 1 Major 17971.40 17786.67 17665.10 88.47 13860.00 3520.77 MINPT-O-EOU 17971.75 17768.73 17665.03 88.35 13880.00 3519.83 MinPt-O-ADP 19736.62 19474.69 19344.53 75.811 18066.14 3428.80 MinPt-O-SF Nikaitchuq 1(Def Survey) Peen 18636.28 18633.72 18603.48 N/A 0.00 0.00 Surface 11 18631.6611 18627.1611 18598.8511 N/A 410.00 409.98 MinPts 18631.741 18627.101 18598.93 N/A 450.00 449.95 MINPT-O-EOU 18632.981 18626.951 18600.18 N/A 580.00 579.44 MINPT-O-EOU 18636.771 18625.641 18603.97 N/A 750.00 747.08 MINPT-O-EOU 11 19060.5911 18995.29 18959.02 262.85 5360.00 3008.48 MinPt-CtCt 19072.6811 18992.36i1 18953.08 242.77 5700.00 3064.07 MINPT-O-EOU 19076.48 18993.1411 18952.3511 233.82 5870.00 3091.87 MinPt-O-ADP 1 18078.30 17873.63 17772.10 89.02 13870.00 3520.30 MinPt-CtCt 18078.501 17873.40 17771.66 88.84 13900.00 3518.91 MINPT-O-EOU 18078.86 17873.43 17771.83 88.78 13910.00 3518.47 MinPt-O-ADP 19767.28 19504.29 19373.00 75.831 18666.14 3428.80 MinPt-O-SF Nikaitchuq 2(Def Survey) Pass 19179.26 19177.34 19146.45 N/A 0.00 0.00 Surface 19178.80 19174.77 19145.99 N/A 320.00 320.00 MinPts 19178.83 19174.74 19146.02 N/A 340.00 340.00 MINPT-O-EOU 26011.32 25789.16 25678.8r MIMI 18666.14 3428.80 MinPt-O-SF Drilling Office 2.5.1100.0 Nikaitchuq\Oliktok Point\0124-08\0124-08\0124-08(P10b) 12/22/2011 2:38 PM Page 11 of 11 STATE OF ALASKA ALASKA OIL AND OIL CONSERVATION COMMISSION 333 West 7th Avenue, Suite 100 Anchorage Alaska 99501 Re: THE APPLICATION OF Eni US ) Docket CO-11-36 Operating Company for an exception to the ) Conservation Order No. 654 spacing requirements of 20 AAC 25.055 to ) drill and complete a water injection well within ) Nikaitchuq 0I24-08 500 feet of a property line where ownership or ) Water Injection Well landownership changes. ) ) December 16, 2011 IT APPEARING THAT: 1. On September 26, 2011, Eni US Operating Company (Eni) requested the Alaska Oil and Oil Conservation Commission (AOGCC) grant an exception to the spacing requirements of 20 AAC 25.055 to drill and complete deviated water injection well Nikaitchuq 0124- 08 within 500 feet of a property line a property line where ownership or landownership changes. Eni's request proposed opening the oil-bearing OA-sand reservoir of the Schrader Bluff Formation (Schrader Bluff OA-sand) to water injection a minimum of 105 feet from the property line that separates Eni's Nikaitchuq Unit from the adjacent Kuparuk River Unit, which is operated by ConocoPhillips Alaska, Inc. (CPAI). 2. Pursuant to 20 AAC 25.055, on September 29, 2011 a notice of a public hearing was published on the State of Alaska's Online Public Notice website, published on the Commission's Internet website, sent via email to all parties on AOGCC's electronic mailing list, and submitted to the ALASKA JOURNAL OF COMMERCE for publication. The notice advised that a hearing was tentatively scheduled for November 15,2011 at 9 AM. 3. On October 6, 2011, an amended notice of a public hearing was published on the State of Alaska's Online Public Notice website, published on the Commission's Internet website and sent via email to all parties on AOGCC's electronic mailing list. The amended notice was published in the ALASKA JOURNAL OF COMMERCE on October 16, 2011. The amended notice advised that the hearing was tentatively scheduled for November 17, 2011 at 9 AM. 4. On November 2, 2011, AOGCC received a written comment from CPAI regarding Eni's spacing exception application. CPAI considered Eni's request and the potential impacts that Eni's proposed well might have on future drilling activities conducted in the adjacent Kuparuk River Unit. Eni and CPAI then worked together to resolve CPAI's concerns by altering the proposed well trajectory so that the Schrader Bluff OA-sand would not be open to water injection within 250 feet of the property line that separates the Nikaitchuq Unit from the Kuparuk River Unit. 5. On November 2, 2011, Eni submitted to AOGCC an amended request for an exception to the spacing requirements of 20 AAC 25.055 that alters the proposed trajectory of Order 654 December 16,2011 Page 2 of 3 Nikaitchuq 0124-08 and moves the interval open to the Schrader Bluff OA-sand 250 feet or more from the property line that separates the Nikaitchuq Unit from the Kuparuk River Unit. The November 2, 2011 written comment from CPAI states that the 250-foot minimum distance from the Kuparuk River Unit boundary was agreed upon by Eni and CPAI. 6. On November 3, 2011, a second amended notice of a public hearing was published on the State of Alaska's Online Public Notice website, published on the Commission's Internet website and sent via email to all parties on AOGCC's electronic mailing list. The second amended notice was published in the ANCHORAGE DAILY NEWS on November 4, 2011. The amended notice advised that the hearing tentatively scheduled for November 17, 2011 had been vacated and tentatively rescheduled for December 6, 2011 at 9 AM. 7. No protest to the amended application or request for hearing was received. 8. Because Eni provided sufficient information upon which to make an informed decision, Eni's request can be resolved without a hearing. 9. On December 1, 2011, AOGCC's Commissioners vacated the public hearing that was tentatively scheduled for December 6, 2011. FINDINGS: 1. Eni currently owns and operates the State lease affected by Nikaitchuq 0124-08 (ADL0391283). Lease ADL0391283 is committed entirely to the Nikaitchuq Unit. 2. Eni is the operator of the proposed Nikaitchuq 0124-08 water injection well. 3. Nikaitchuq 0124-08 is a deviated water injection well with a surface location of 3126 feet from the south section line (FSL) and 1711 feet from the east section line (FEL) of Section 5, T13N, RO9E, Umiat Meridian (UM); a proposed productive interval intercept location of 250 feet FSL and 3005 feet from the east section line (FEL) of Section 31, T14N, RO9E, UM; and a proposed bottom-hole location of 47 feet FSL and 4017 feet FEL of Section 25,T14N, RO8E, UM. 4. Nikaitchuq 0124-08 targets the oil-bearing Schrader Bluff OA-sand reservoir. 5. As re-designed, Nikaitchuq 0124-08 will intercept the Schrader Bluff OA-sand 250 feet or more from a property line where ownership or landownership changes. 6. Reservoir modeling by Eni indicates that opening the Schrader Bluff OA-sand to water injection from Nikaitchuq 0124-08 as re-designed will increase resource recovery in offset producing wells with a minimal increase in reservoir pressure at the nearby boundary with the Kuparuk River Unit. CONCLUSIONS: 1. As re-designed, Nikaitchuq 0124-08 will improve resource recovery with minimum risk to future drilling operations in offset leases. Order 654 December 16,2011 Page 3 of 3 2. An exception to spacing requirements of 20 AAC 25.055 is necessary to allow drilling and completion of the Nikaitchuq 0I24-08 water injection well. 3. A spacing exception to allow drilling and completion of the Nikaitchuq 0124-08 well will not result in waste or jeopardize correlative rights of adjoining or nearby owners and operators. NOW,THERFORE,IT IS ORDERED: Eni's November 2, 2011 amended application for exception to the well spacing provisions of 20 AAC 25.055 for the purpose of drilling and completion of the Nikaitchuq 0124-08 well is approved. Eni may proceed with the drilling and completion of the Nikaitchuq 0124-08 as long as it is in compliance the terms of the leases and applicable Alaska Law. AOGCC must approve a separate order granting exception to the spacing requirements of 20 AAC 25.055 before Nikaitchuq 0124-08 is converted to production. ��OILN�� A DONE at Anchorage,Alaska and dated December 16, 2011. `T 001' ,AL Daniel T. Seams t, Jr. 1 • � , Norman "et, Chair, Commissioner a m' 'over RECONSIDERATION AND APPEAL NOTICE As provided in AS 31.05.080(a),within 20 days after written notice of the entry of this order or decision,or such further time as the AOGCC grants for good cause shown,a person affected by it may file with the AOGCC an application for reconsideration of the matter determined by it. if the notice was mailed,then the period of time shall be 23 days. An application for reconsideration must set out the respect in which the order or decision is believed to be erroneous. The AOGCC shall grant or refuse the application for reconsideration in whole or in part within 10 days after it is filed. Failure to act on it within 10-days is a denial of reconsideration. If the AOGCC denies reconsideration,upon denial,this order or decision and the denial of reconsideration are FINAL and may be appealed to superior court. The appeal MUST be filed within 33 days after the date on which the AOGCC mails, OR 30 days if the AOGCC otherwise distributes, the order or decision denying reconsideration, UNLESS the denial is by inaction,in which case the appeal MUST be filed within 40 days after the date on which the application for reconsideration was filed. If the AOGCC grants an application for reconsideration,this order or decision does not become final. Rather,the order or decision on reconsideration will be the FINAL order or decision of the AOGCC,and it may be appealed to superior court. That appeal MUST be filed within 33 days after the date on which the AOGCC mails,OR 30 days if the AOGCC otherwise distributes,the order or decision on reconsideration. As provided in AS 31.05.080(b),"[t]he questions reviewed on appeal are limited to the questions presented to the AOGCC by the application for reconsideration." In computing a period of time above,the date of the event or default after which the designated period begins to run is not included in the period;the last day of the period is included.unless it falls on a weekend or state holiday,in which event the period runs until 5.00 p m.on the next day that does not fall on a weekend or state holiday. 3800 Centerpo ra Drive.Suite 300 RECEIVED Anchorage,Alaska 99503 Phone(907)865-3300enn N O V 0 2 20 1! pei1r®plum Alaska Oil & Gas Cans.Commission 1%ncnorage November 2, 2011 Mr. Daniel T. Seamount Jr. Alaska Oil & Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Re: Amended Well Spacing Exception Nikaitchuq Unit — Well 0124-08 North Slope, Alaska ADL 391283 Dear Mr. Seamount: Reference is made to Eni US Operating Company's (eni) letter dated September 26, 2011, requesting the Alaska Oil and Gas Conservation Commission (AOGCC) to issue an order for an exception to the spacing requirements from the standard 500-foot setback to a 100-foot setback from the property line. After the AOGCC's amended 30-day Notice of Public Hearing was published, eni was advised by ConocoPhillips Alaska, Inc. (CPAI) of its objections to the spacing exception, as it may have impact on future Kuparuk River unit drilling in that area. As a result of CPAI's concerns for the spacing exception, eni held subsequent discussions with CPAI and has mutually agreed to move the requested well location from 100 feet back to 250 feet from the lease line (see attached map). CPAI has sent a letter notifying the AOGCC that it will not object to a spacing exception for this well at a distance of 250 feet from the lease line. The improved recovery is less at a 250-foot offset; most of the benefit can be realized at the new proposed spacing exception. Below is the new well location coordinates with the amended heel location. Also attached are the revised PowerPoint slides to replace the PowerPoint slides found in eni's letter dated September 26, 2011 . - 1 - The amended coordinates for well 0124-08 are as follows: Surface Location: 3126 FSL, 1711 FEL, T13N R09E Sec.5, UM Top of Shrader-Bluff Interval, Proposed: 250 FSL, 3005 FEL, T14N R09E Sec.31 ,UM; 47 FSL, 4017 FEL, T14N R08E Sec.25,UM Bottom Hole, Proposed: 47 FSL, 4017 FEL, T14N R08E Sec.25, UM The benefit of the a well at a location of 250 feet from the lease line would be the improved recovery of approximately 280 kSTB over 10 years, and 680 kSTB over 20 years. Without this spacing exception, the area would be unsupported. There are no other wells to be drilled in the area and this would result in waste amounting to as much as 800 kSTB. The impact on adjacent leases would be a minimal increase in reservoir pressure along the lease line. Any pressure increase would be limited, due to the nature of the cold reservoir temperature and heavy oil. Moreover, there is also an east- west sealing fault that is 1 ,000 feet south of the proposed heel location. The throw of the fault in the vicinity of the proposed heel location is greater than the Schrader Bluff OA reservoir thickness. Eni respectfully requests AOGCC to accept this letter as an addendum to the original well spacing exception letter dated September 26, 2011 . Should you have any questions or need additional information, please contact me. Sincerely, e9s Robert A. 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Permit No: 211-130 Surface Location: 3126.4' FSL, 1710.5' FEL, SEC. 5, T13N, R9E, UM Bottomhole Location: 47' FSL, 4017' FEL, SEC. 25, T14N, R8E, UM Dear Mr. Grandi: Enclosed is the approved application for permit to drill the above referenced service well. The permit is approved subject to full compliance with 20 AAC 25.055. Approval to inject is contingent upon issuance of a conservation order approving a spacing exception. ENI US Operating, Co. Inc. assumes the liability of any protest to the spacing exception that may occur. This permit to drill does not exempt you from obtaining additional permits or an approval required by law from other governmental agencies and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. Sincerely, I ilk I i // -/ Daniel T. Seamount, Jr. Chair DATED this tday of October, 2011. cc: Department of Fish & Game, Habitat Section w/o end. (via e-mail) Department of Environmental Conservation w/o end. (via e-mail) STATE OF ALASKA R EC E I E Ak ,CA OIL AND GAS CONSERVATION COM, ;ION 3 2011PERMIT TO DRILL 20 MC 25.005 1a.Type of Work: lb.Proposed Well Class: Development-Oil ❑ Service- Winj E • Single Zone Alaskoi)hidiy SAID Drill Q • Redrill ❑ Stratigraphic Test ❑ Development-Gas ❑ Service-Supply ❑ Multiple Zone ❑ Coalbed Gtl f0 -lydrates Re-entry ❑ Exploratory ❑ Service- WAG El Service-Disp ❑ ShVle Gas ❑ 2.Operator Name: 5. Bond: Blanket Q Single Well ❑ 11.Well Name and Number: ENI US Operating Co.Inc. Bond No. RLB0008627 0124-08 ' 3.Address: 6.Proposed Depth: 12.Field/Pool(s): 3800 Centerpoint Drive Suite 300,Anchorage 99503 MD: 16856' • TVD: 3479'• Nikai huq. 4a. Location of Well(Govemmental Section): 7.Property Designation(Lease Number): < -/74 r- '7,(1- C,),/1 /4/ Surface: 3126.4 FSL 1710.5 FEL S5 T13N R9E UM , ADL 355024;373301,391283 /'n 9 2,•rr Top of Productive Horizon: 8.Land Use Permit: 13.Approximate Spud Date: 105 FSL 2865 FEL 31 T14N R9EUM ' ADL 417493 11/23/2011 Total Depth: 9.Acres in Property: 14.Distance to Nearest Property: 47 FSL 4017 FEL 25 T14N R8EUM - 1280 • 2153'to unit boundary 4b.Location of Well(State Base Plane Coordinates-NAD 27): 10.KB Elevation above MSL: • 53.2 feet 15.Distance to Nearest Well Open Surface:x- 516570 y- 6036479• Zone- 4 GL Elevation above MSL: 12 feet to Same Pool: OP18-08 16.Deviated wells: Kickoff depth: 300 feet . 17.Maximum Anticipated Pressures in psig(see 20 AAC 25.035) Maximum Hole Angle: 90° degrees Downhole: 1591 psig, Surface: 1202 psig - 18.Casing Program: Specifications Top - Selling Depth - Bottom Cement Quantity,c.f.or sacks 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 16" 13-3/8" 68 L-80 BTC 2523 35 35 2558 • 2172 1245 sx 10.7#ASL,225 sx 12.5#Deeperete 12.25" 9-5/8" 40 L-80 Hydril 563 8497 33 33 8530 • 3536 • 701 sx 12.5#Deeperete 8.75" 4.5" 11.6 L-80 Hydril 521 8526 8330 3536 16856 • 3479 • uncemented liner in open hole 19. PRESENT WELL CONDITION SUMMARY(To be completed for Redrill and Re-Entry Operations) Total Depth MD(ft): Total Depth TVD(ft): Plugs(measured): Effect.Depth MD(ft): Effect.Depth TVD(ft): Junk(measured): Casing Length Size Cement Volume MD ND Conductor/Structural - Surface Intermediate Production Liner Perforation Depth MD(ft): Perforation Depth TVD(ft): 20. Attachments: Property Plat ❑� BOP Sketch❑✓ Drilling Program 2 Time v.Depth Plot ❑ Shallow Hazard Analysis❑✓ 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 MACY/ ,e A- Phone 907-865-3320 ' Date 9/19/2011 6 Commission Use Only Permit to Drill / / /�, API Number. f Permit Appr ••-' / See cover letter for other Number: �` / L` 1� 50 "zee ��-, - Date: �� f requirements. Conditions of approval: If box is checked,�� well may not be used to explore for,test,or produce coalbed m ane,gas hydrates,or gas contained in shales: Other: -• 35ov p52 o f 1 e- Samples req'd: Yes❑ No 2// Mud log req'd: Yes ❑ o 12/ $ZS'� Sc of 44.(sV. I s � C/ H2S measures: Yes❑ No El Directional svy req'd: Yes [1 No ❑ �,ier,-u- Vet!uJ �-r 2c /4/1"C-Z! O.jS 00(Z) 1- M IT i et 'L re c .Q 41-1 u 4 - o p r- 0'o.•. 1 h. 44c..e r.Q. 4 Aro 3 9/14/ ////f/ , APPROVED BY THE COMMISSION DATE: lir. / ,COMMISSIONER 47 30/11 ORIGINAL ,,,,, ,( 'i Form 10-401(Revised 7/2009) This permit is valid for 24 months from the date of approval(20 AAC 25.005(9)) Sub iinnDuplicate ri"f/ RECEIVED, SEP 2 3 2011 • En �) Est HeuirnAlaska Oil& Gas Cons.ons.Corrrrnsn Anchorage 3800 Centerpoint Drive Suite 300 Anchorage,Alaska 99503 Maurizio Grandi Phone(907)865-3320 Email: Maurizio.Grandi@enipetroleum.com September 19,2011 Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage,Alaska 99501 RE: Application for Permit to Drill Injector 0124-08 Dear Commissioners, ENI US Operating Co. Inc.hereby applies for a Permit to Drill for the onshore injection well 0124-08.The well will be drilled and completed using Nabors rig 245E. The planned spud date is 11/23/2011. Please find attached for the review of the Commission forms 10-401 and the information required by 20 ACC 25.005 for this well bore. If you have any questions or require further information,please contact Joseph Longo at 907-865-3323 or Jason Brink at 907-865-3321 or Luca Borri at 907-865-3328. Sincerely, Maurizio Grandi Well Operation Project Manager cf* Oliktok Point Nikaitchuq Field en� I N7E4r Z petroleum 0124-08 (P8) Alaska DIR/LWD FORM DEPTH HOLE CASING MUD INFO Drilling MWD MD TVD SIZE SPECS Hazards Cement to Surface 20" Hole Angle X-65 0' 20"Conductor Shoe 160' 160' N/A Welded/Driven N/A 0 GR/Res '-.1 Surface Csq Dir v 13-3/8" ta Base Permafrost 2,000' 1.741' > 68 lbs/ft MW(ppg) Wellbore Stability Mud Motor Nr L-80,BTC 9.2-9.5 Lost Circulation Hole Cleaning N 9: a at A o<. -TA z*' A 13-318"Casing Point 2,558' 2,172' ' 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 6,268' N'. N to in "N"Sand Top 7.268' v ra 41) Injection Packer 7,330' CI . _ 2, NOTE: Injectors REQUIRE CBL on Intermediate Casing v° TOL 8.330' 3`-' fD 9-5/8"Casing Point 8,530' 3,536' 41111119 rillir 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 16,856' 3,479' 8-1/2" 85"F OBM N co Ea. Inco 11 a a. CO co d CD d O N O CO In O O CO _ 0 OO O N 00CO O O O O (n V (n O O N O 00 i I� i i oo a OO ,— ,— oo a o = o O a a o a a N n� :4/ O r �/ co 0� v O o Y O�Q �O Q N d d 1 j 1 1 1 0 o • o M , r • o • .Q� •r ♦°A M r O� ?� 0 p_ 6,F B• `�.00 O • `7e r Or •..1, •_ i Qi 6b • r 6a��•. • .66 O .cg ' - •• •• f Po6jN:• OZI f c6 Or p � O 4 f. _,6.. 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V c 7 f 3 / a ,'sr ••14,,IFillri1 y 6FFF IO.t,L it V 1 076 6Df C14.1.14, 0,�1 6DF O.LL Flp V • 11 L. v�FF ••�Rz6F •O�FIpFE m •O-WFF ` 1966F 0^16�DF :$ a • EDF O g / �c o • . - eD ON ••41-94-6'''t �^ ] Q•,,,60, N •••• LL y RDF • cele Q ICO •0.Q.d 1,, N 01ZFD£ • •/ �F , FDF 6GFF C • 4 z1 RF•cd ¢,, �OD • 6RF �,N- ! ail-1'44r R �o ffE ••Oi1RGFF � 8 • 6� oO0� • r o r_ w. 6 i D 6MDD f i/ItryDclL \ -`,6FF Tr N z 1 . D 0, • A� £ •O E U M CN°:7..• Ql!10 - t. •3 • ' J' 'a `( O Q'1 N 41 •011 °4r •Qj. FS1f Ry(£ I R4., !-r . 1 1 I I I O O O O O O o., o ,n o ..n m r upv rn «< N (1-)0051:(01 = ele3S S >>> • Eno PetiroHeum eno Application for Permit to Drill Saved: 19-Sep-11 Application for Permit to Drill Document Injector Well Table of Contents 1. Well Name 3 Requirements of 20 MC 25005(f) 3 2. Location Summary 3 Requirements of 20 MC 25005(c)(2) 3 Please see Attachment 7:Surface Platt 3 Requirements of 20 MC 25050(b) 3 3. Blowout Prevention Equipment Information 4 Requirements of 20 MC 25005(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 25005(c)(5) 4 6. Casing and Cementing Program 5 Requirements of 20 MC 25005(c)(6) 5 7. Diverter System Information 5 Requirements of 20 MC 25005(c)(7) 5 8. Drilling Fluid Program 6 Requirements of 20 MC 25005(c)(8) 6 Surface Hole Mud Program(extended bentonite) 6 Intermediate Hole Mud Program(LSND) 6 Lateral Mud Program(MI FazePro Mineral Oil Base) 6 9. Abnormally Pressured Formation Information 6 Requirements of 20 MC 25 005(c)(9) 6 10. Seismic Analysis 7 Requirements of 20 AAC 25.005(c)(10) 7 AOGCC PERMIT Document.doc Page 1 of 9 Printed: 19-Sep-11 it EnJLr Oo Petroleum eno Application for Permit to Drill Saved: 19-Sep-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 9 Attachment 1 Directional Plan 9 Attachment 2 Drilling Hazards Summary 9 Attachment 3 BOP and Diverter Configuration 9 Attachment 4 Cement Loads and CemCADE Summary 9 Attachment 5 Well Schematic 9 Attachment 6 Formation Integrity And Leak Off Test Procedure 9 Attachment 7 Surface Platt 9 AOGCC PERMIT Document.doc Page 2 of 9 Printed: 19-Sep-11 %It • Enfl Petirolleum cin 0 Application for Permit to Drill Saved: 19-Sep-11 1. Well Name Requirements of 20 MC 25.005(t) 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: 0124-08 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. (B)the coordinates of the proposed location of the well at the surface, referenced to the state plane coordinate system for this state as maintained by the National Geodetic Survey in the National Oceanic and Atmospheric Administration; (C)the proposed depth of the well at the top of each objective formation and at total depth; Location at Surface 3126.4 FSL 1710.5 FEL S5 T13N R9E UM ASP Zone 4 NAD 27 Coordinates RKB Elevation 52.2'AMSL Northing 6036479.380'_ Easting: 516569.840' _ Pad Elevation 12.2'AMSL Location at Top of Productive Interval 105 FSL 2865 FEL 31 T14N R9EUM - ("OA"Sand) ASP Zone 4 NAD 27 Coordinates Measured Depth, RKB: 8530' Northing: 6038726.600' Easting:510123.8' Total Vertical Depth, RKB: 3536' Total Vertical Depth, SS: 3484' Location at Total Depth 47 FSL 4017 FEL 25 T14N R8EUM • ASP Zone 4 NAD 27 Coordinates Measured Depth, RKB: 16856' Northing:6043941.5' Easting: 503822' Total Vertical Depth, RKB: 3479' Total Vertical Depth, SS: 3427' Please see Attachment 7:Surface Platt and (D)other information required by 20 AAC 25.050(b); Requirements of 20 MC 25.050(6) If a well is to be intentionally deviated, the application for a Permit to Drill(Form 10-401)must (1)include a plat,drawn to a suitable scale,showing the path of the proposed wellbore,including all adjacent wellbores within 200 feet of any portion of the proposed well; Please see Attachment 1: Directional Plan AOGCC PERMIT Document.doc Page 3 of 9 Printed: 19-Sep-11 fl l* Enil PtiroIIuim ens Application for Permit to Drill Saved: 19-Sep-11 and (2)for all wells within 200 feet of the proposed wellbore (A)list the names of the operators of those wells, to the extent that those names are known or discoverable in public records, and show that each named operator has been furnished a copy of the application by certified mail;or (B)state that the applicant is the only affected owner. The Applicant is the only affected owner. 3. Blowout Prevention Equipment Information Requirements of 20 MC 25.005(c)(3) An application for a Permit to Doll must be accompanied by each of the following items, except for an item a/ready on file with the commission and identified in the application: (3)a diagram and description of the blowout prevention equipment(BOPE)as required by 20 AAC 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 Doll must be accompanied by each of the following items, except for an item a/ready 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 = (3536' TVD)(0.45 - 0.11 psi/ft) = 1202 psi (B)data on potential gas zones; The well bore is not expected to penetrate any gas zones. and (C)data concerning potential causes or note 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 AAC 25005(c)(5) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (5)a description of the procedure for conducting formation integrity tests, as required under 20 AAC 25.030(>); Please see Attachment 6: Formation Integrity And Leak Off Test Procedure AOGCC PERMIT Document.doc Page 4 of 9 Printed: 19-Sep-11 Tiokt • Enli Petirolleurn ena Application for Permit to Drill Saved: 19-Sep-11 6. Casing and Cementing Program Requirements of 20 MC 25.005(c)(6) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (6)a complete proposed casing and cementing program as required by 20 MC 25.030,and a description of any slotted liner,pre- perforated liner, or screen to be installed; Casing and Cementing Program See also Attachment 4: Cement Summary Hole Casing Weight Grade Coupling Length MD TVD MD TVD (including stage data) Driven 20" 178.89 X-65 Welded 124 36 36 160 160 pre-installed 16" 13-3/8" 68 L-80 BTC 2523 35 35 2558 2172 1245sx 10.7#ASL,225 sx 12.5#Deeperete 12.25" 9-5/8" 40 L-80 563i1 8497 33 33 8530 3536 701 sx 12.5#Deeperete 8.75" 4.5" 11.6 L-80 521 it 8526 8330 3536 16856 3479 uncemented liner in open hole 7. Diverter System Information Requirements of 20 MC 25.005(c)(7) An application for a Permit to Drill must be accompanied by each of the following items,except for an item already on file with the commission and identified in the application: (7)a diagram and description of the diverter system as required by 20 MC 25.035, unless this requirement is waived by the commission under 20 MC 25.035(h)(2); Please see Attachment 3: BOP Configuration. ENI requests that AOGCC waive diverter requirements per 20 MC 25.035. (h). (2). C5 Y— AOGCC PERMIT Document.doc Page 5 of 9 Printed: 19-Sep-11 „oil* c ' Eno PketriIeum en Application for Permit to Drill Saved: 19-Sep-11 Drilling Fluid Program Requirements of 20 MC 25.005(c)(8) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (8)a drilling fluid program,including a diagram and description of the drilling fluid system,as required by 20 MC 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 (seconds) 150 250 200 300 Yield Point 50 70 30 50 (lb/100 sf) 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 st) 15 - 20 (CP) 12 - 18 HTHP Fluid loss Yield Point 18-24 (ml/30 min <5.0 (lb/100 sf) 200psi& 100°F API Filtrate4 - 6 Oil/ Water 60/ 40 (cc/30 min)) Ratio Chlorides(mg/I) <500 Electrical >600 pH 9.0 - 10.0 Stability MBT <18.0 Drilling fluid practices will be in accordance with appropriate regulations stated in 20 MC 25.033. 8. Abnormally Pressured Formation Information Requirements of 20 MC 25.005(c)(9) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (9)for an exploratory or stratigraphic test well, a tabulation setting out the depths of predicted abnormally geo pressured strata as required by 20 MC 25033(t); AOGCC PERMIT Document.doc Page 6 of 9 Printed: 19-Sep-11 spo • Enil Petirolleum 2n° Application for Permit to Drill Saved: 19-Sep-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 MC 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 MC 25.061(6); 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 MC 25.025{Bonding}have been met; Evidence of bonding for ENI is on file with the Commission. 12. Proposed Drilling Program Requirements of 20 MC 25.005(c)(13) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: The proposed drilling program is listed below. Please refer also to Attachment 5, Well Schematic. 1. Move in / rig up Nabors 245E. her Z" A,kc Z-S 63sCkkz) 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 - Lot results. 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 ran 'in the BOP and test to 3500 PSI. 11. RU casing drive system. AOGCC PERMIT Document.doc Page 7 of 9 Printed: 19-Sep-11 10,* • Einiii PtIroIIeLuIm 2nll Application for Permit to Drill Saved: 19-Sep-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. 19. Drill out cement and between 20' and 50' of new hole. Perform formation integrity test, recording F I r 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 per 20 MC 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. • 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 25005(c)(14) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (14)a general description of how the operator plans to dispose of drilling mud and cuttings and a statement of whether the operator intends to request authorization under 20 AAC 25.080 for an annular disposal operation in the well.; Waste fluids generated during the drilling process will be disposed of by injection down an Oliktok Point Class I disposal well or by hauling the fluids to the Prudhoe Bay Grind and Inject Facility. All cuttings generated will be disposed of either down an Oliktok Point Class I grind and inject disposal well or hauled to the Prudhoe Bay Grind and Inject Facility for temporary storage and eventual processing for injection down an approved disposal well. AOGCC PERMIT Document.doc Page 8 of 9 Printed: 19-Sep-11 vot j En i Petirolleum Application for Permit to Drill Saved: 19-Sep-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 9 of 9 Printed: 19-Sep-11 co O N N N N N N N N tO N N NrNN N 2N MrNNWNWNN N N NNN dN ON QNr d 822:2g M M N rro ro 1dq qP^ ddNN '72,7' " Nq r MN M NrN 7 Ny r mNENN NOa yyr,iNN NNOO p202 NnrN .2aN NN 4N aW NNNNND0NpD 0iNNNNNNNNpNNNN NNNN MNNNN 0.,„„,NNN N m a U, C y 82 W MN g888° -,8,88 222 ONrO,2 8.18 FV N - '0 ""'" h nWaaic4 ";327 W2 7 N< m WVm o �O c O N ^ d MMO N 2- 1IMI aapp71 M1y • p•• ..2 . nAM 2• • nrr, ONE0000 00000 08220 00000 20000 E2NNN eNNN. 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Ii ) 9 \7,t A •!» A AI. ■ w ! r ®� ! u ° / !v 7 t'® $ in )|| - » ti 7 11_ II (| s 3 0 •- ) 2 |§ | P| m |�� - s § \ I & ■ | (|%v — — it ■ kK U 0 o ■ � ® . % - 3 8 $2 a y U U iE &P . ■ -_ /§ &07C—L 1s s Sr | iti - ! ■ � | � O � 9 3=k 4 _ 122 & & 2 0 i§ ! ■ & a ooLac- ƒ: a 69 CV. ! & [ |, R ! - ° § / ) ( ) .- «< < N UmQ&6=oleos S »> Schlumberger 0124-08 (P8) Anti-Collision Summary Report Analysis Date-24hr Time: September 13,2011-13:23 Analysis Method: Normal Plane Client: ENI Reference Trajectory: 0124-08(P8)(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: OP24 Min Pts: All local minima indicated. Well: 0124-08 Borehole: 0124-08 Offset Trajectories Summary Offset Selection Criteria Wellhead distance scan: Not performed! Selection filters: Definitive Surveys-Definitive Plans-Definitive surveys exclude definitive plans -All Non-Def Surveys when no Def-Survey is set in a borehole-All Non-Def Plans when no Def-Plan is set in a borehole Offset Trajectory Separation Allow Sep. Reference Trajectory Separation Factor Alert Status Ct-Ct(ft)I EOU(ft) Dev.(ft) Fact. MD(ft) I TVD(ft) Alert I Minor I Major OP23-W W02(Def Survey) Warning Alert I79111 6.6911 1.31 5.46 0.00 0.00 CtCt<=15m<15.00 Enter Alert 7 91 6.69 1.32 5. 9.00 9.00 MinPt-O-SF 8.481 6.5'1 1.89 3.73 184.00 184.00 MinPt-O-EOU ®® 298 294.00 294.00 MinPts 9.01 6.30 2.42 2.87 318.97 318.97 MinPt-O-EOU 9.09 6.33 2.49 336.52 336.52 MinPt-O-SF 48.56 42.77 40.49 10.36 721.41 718.41 CtCt<-15m>15.00 Exit Alert 1086.96 1067.47 1058. 'M,; 2306.63 2020.14 MinPt-O-SF 9423.04 9377.86 9355.76 213.15 4277.92 2662.73 TD OP22-W W01(P2)(Def Plan) Warning Alert 15.97 14.74 2.95 12.04 0.00 0.00 CtCt<=15m<15.00 Enter Alert 15.97 12.94 2.95 4.87 300.00 300.00 MinPts 16.06 12.83 3,05 4.58 334.91 334.91 MinPt-O-EOU 16.49 13.07 3.47 379.79 379.78 MlnPt-OSF 16.98 13.46 3.96 11.111EM 409.65 409.64 MinPt-O-SF 48.83 42.84 35.81 7.95 687.21 684.98 CtCt<=15m>15.00 Exit Alert 3757.58 3733.86 3722.4.=nu 2614.34 2201.71 MinPt-O-SF 9385.79 9353.24 9337.46 297.36 2889.26 2323.42 TD OP18-08PB1(Def Survey) Warning Alert - I 52.791 48.911 19.981 13.32 436.91 436.87 MinPts 57.20 44.61 24.39 4.45 743.97 740.38 OSF<5.00 Enter Alert 58.59 44.49 25.78 4.07 773.88 769.39 MinPt-O-EOU 67.02 48.52 34.21 MEMO 898.79 888.96 MinPt-O-SF 103.99 82.07 71.1:MI= 1172.47 1139.17 MinPt-O-SF 104.18 82.26 71.37 4.69 1173.46 1140.04 OSF>5.00 Exit Alert 140.14 116.71 105.67 6.28 1344.79 1285.95 TD 0120-07(P12)(Def Plan) Warning Alert 31.87 30.65 6.13 25.04 0.00 0.00 CICt<=15m<15.00 Enter Alert 31.86 28.98 6,11 10.65 304.97 304.97 MinPts 31.86 28.98 612 10.63 309.95 309.95 MinPt-O-EOU 31.92 29.02 6.1 man 329.84 329.84 MinPt-O-SF 32.19 29.28 6 1.its 364.63 36462 MinPt-O-SF 41.50 36.88 15.76 515.99 515.74 MinPt-O-SF 48.52 43.24 22.78 8.95 568.59 567.99 CICI<=15m>15.00 Exit Alert 505.82 403.78 353.25 5.00 5194.21 2875.83 05F<5.00 Enter Alen 210.47 94.44 36.921 1.821 6440.79 3165.75 MinPt-0SF 207.74 93.351 36.65' 1.82 6464.67 3171.31 MinPt-O-ADP 202. 92.3 37.79 1.85 6517.21 3183.53 MinPt-0-EOU I 194.29 104.83 60.59 2.18 6703.48 3226.85 MinPt-CtCt 272.68 206.70 174.21'' ;10 7337.25 3373.00 MinPt-0-SF 340.18 271.25 23727 4.99 7948.00 3479.72 OSF>5.00 Exit Alert 373.01 297.54 260.30 4.99 8481.49 3532.47 OSF<5.00 Enter Alert 414.66 309.771 257.82) 3.98 8834.85 3550.58 MinPt-O-ADP 502.15 356.66 284.411 3.4 9273.78 3551.55 MinPt-0SF 982.17 784.65 686 38 4.99 10044.76 3522.61 OSF>5.00 Exit Alert 3319. 3045.3 2908.93 12.16 13253.11 3540.91 MinPt-O-EOU 3320.22 3045.6 2908 84 1 12. 13271.61 3540.30 MinPts 3367.4 3060.35 2507.27 11.00 14160.40 3507.58 MinPt-CtCt 3368.71 3058.7 2904.26 10.90 14266.87 3505.21 MinPt-O-EOU 3369.84 3058. 2903.9 10.87 14309.35 350420 MinPt-O-ADP 3383.64 3069.21 2912.4 10.791 14561.29 3497.68 MinPt-O-SF 2990.36 2598.87 2403.61 7.66 16856.31 3479.60 TD 3370.74 3069.96 2920.,•MOE 13975.40 3511.13 MinPt-O-SF 0115-84(P5)(Def Plan) Warning Alert 79.89 76.86 47.08 25.97 300.00 300.00 MinPts 80.01 76.74 47.20 24.09 339.50 339.50 MinPt-0-EOU 113.66 91.48 80.86 M't 924.28 912.99 MinPt-O-SF 121.14 95.79 83.73 4.97 986.14 970.77 OSF<5.00 Enter Alert • 171.48 121.45 97.rEIZE 1305.51 1253.34 MinPt-O-SF 257.16 204.71 179.10 5.00 1710.57 1575.45 OSF>5.00 Exit Alert 5639.20 5357.50 5217.1 4:E 13297.15 3539.32 MinPt-O-SF 5310.0 4993.20 4835.26 16.81 14367.40 3502.78 MinPt-CtCt 5310. 4993.0 4834.94 16.79 14382.48 350240 MinPt-O-EOU 5310.37 4993.0 4834. 16.78 14388.51 3502.25 MinPt-O-ADP 5326.48 5007.03 4847.7 16.74 14519.43 3498.82 MinPt-O-SF Drilling Office 2.0.960.0 NikaitChuq\Oliktok Point\0124-08\0124-08\0124-08(P8) 9/13/2011 1:24 PM Page 1 of 13 Offset Trajectory Separation Allow Sep. Reference Trajectory Separation Factor Alert Status Ct-Ct(ft)I EOU(ft) Dev.(ft) Fact. MD(ft) 1 TVD(ft) Alert I Minor I Major 5569.21 5192.36 5004.44 14.81 16856.31 3479.60 MinPt-O-SF OP16-08(Def Survey) Warning Alert • 46.91 19.98 13.32 436.91 436.87 MinPts 57.20 44.61 24.39 4.45 743.97 740.38 OSF<5.00 Enter Alert 58.59 ML120 25.78 4.07 773.88 769.39 MinPt-O-EOU 67.02 48.52 34.21.1=11151 898.79 888.96 MinPt-OSF 90.75 71.61 57.94 4.68 1149.80 1119.18 OSF>5.00 Exit Alert 156.74 131.66 119.7 migis 1931.78 1746.36 MinPt-0SF 262.36 228.33 211.:'® 2711.74 2249.42 MinPt-0-SF 347.86 296.55 271.3: 6.89 3255.73 2424.99 MinP1-0SF 1258.34 1107.92 1033.2. Flal 7810.53 3460.28 MinPt-0-SF 1121.08 973.69 900.49" 8556,83 3539.03 MinPt-O-SF 687.01 548.68 480.01 4.99 9699.52 3542.19 OSF<5.00 Enter Alert 409.60 300.27 246.1011MH 10384.17 3511.28 MinPt-O-SF 212.44 166.59 3.32 10967.53 3509.38 MinPt-CtCt 333.41. 99.66 2.14 11296.51 3512.31 MinPt-O-EOU 364.71 182.6 2.01 11458.85 3513.04 MinPt-O-ADP 389.26 192.91 9522 M11111111 11565.25 3513.51 MinPt-O-SF 1227.85 922.97 771.0211 13861.86 3513.10 MinPt-0SF 1305.461 974.2 809.06 3.95 14830.94 3490.77 MinPt-O-EOU 1305.87 974 26 808.95 3.95 14845.76 3490.70 MinPt-0-ADP 1311.45 977 81 811.48 3.94 14929.31 3491.40 MinPt-O-SF 4 1100.801 718.751 528.22 2.89 16856.31 3479.60 MinPts OP18-08PB2(Def Survey) Warning Alert MEE 48.911 19.981 13.32 436.91 436.87 MinPts 57.20 44.61 24.39 4.45 743.97 740.38 OSF<5.00 Enter Alen 58.59 25.78 4.07 773.88 769.39 MinPt-O-EOU • 67.02 48.52 34.21 MEM] 898.79 888.96 MinPt-0SF 90,75 71.61 57.94 4 68 1149.80 1119.18 OSF>5.00 Exit Alert 156.74 131.66 119.73` 6 521 1931.76 1746.36 MinPt-O-SF 262.36 228.33 211.85 7.93 2711.74 2249.42 MinPt-O-SF 347.86 296.55 271.39 6.89 3255.73 2424.99 MinPt-OSF 1258,34 1107.93 1033.2? 8.411 7810.53 3460.28 MinPt-OSF 1121.08 973.71 900.51 7 6'5'11 8556.83 3539.03 MinPt-O-SF 687.01 548.69 480.03 5.00 9699.52 3542.19 OSF<5.00 Enter Alert 409.60 300.28 246.11 IlMin 10384.17 3511.26 MinPt-OSF 305.1 212.45 166.60 3.32 10967.53 3509.38 MinPt-CtCt 333.41 177. 99.68 2.14 11296.51 3512.31 MinPt-0-EOU 364.71 182.6 92.1 2.01 11458.85 3513.04 MinPt-O-ADP 389.26 192.93 95.26 1.99 11565.25 3513.51MinPt-OSF 1227.85 923.00 771.0 4.04 13861.86 3513.10 MinPt-OSF 1305.461 974.244 809.12 3.95 14830.94 3490.77 MinPt-O-EOU • 1305.87 974.3 809.01 3.95 14845.76 3490.70 MinPt-0-ADP 1311.45 977.85 811.54 3. 14929.31 3491.40 MinPt-O-SF 1 1087.551 705 861 515.51 2.8 16856.31 3479.60 MinPts OP16-03(Del Survey) Warning Alert 71.90 70.39 39.1 46.64 114.11 114.11 MinPts 72.22 69.23 39.41 23.70 328.78 328.78 MinPt-0-EOU 74.21 70.80 41. r® 448.00 447.94 MinPt-O-SF 92.05 82.63 59.2' 830.29 823.73 MinPt-OSF 168.36 149.76 135.:Nmiz 1605.63 1493.43 MinPt-O-SF 282.07 253.59 239.': flEp 2246.01 1979.23 MinPt-O-SF 300.14 269.97 255.'.MUD 2391.97 2074.98 MinPt-0SF 319.17 254.54 222.71 5.00 3900.66 2574.99 OSF<5.00 Enter Alert NEIEE 228.30 187.66 3.81 4415.57 2894.74 MinPt-C1Ct 303., 198.26 145.91 2.89 5253.67 2889.66 MinPt-C1Ct 197.084 143.63 2.84 5353.02 2912.77 MinPt-0-EOU 305.78 197.2"'11 143. 2.83 5387.72 2920.84 MinPt-O-ADP 308.23 198.54 144.1 2.831 5447.17 2934.66 MinPt-O-SF 717.18 572.70 500.95 4.99 8106.43 3498.57 OSF>5.00 Exit Alert 1279.16 1106.56 1020.7.®I 9114.18 3552.56 MinPt-0SF 1326.91 1115.64 1010.50 6.31 10679.07 3505.94 MinPt-CtCt 1327.51 1115.104 1009.39 6.27 10729.02 3506.54 MinPt-O-EOU 1328.25 1115. 1009.261 6.26 10753.98 3506.84 MinPt-0-ADP =gm 1107.51 995.00 5.92 11317.07 3512.40 MinPt-CtCt 1335.11 992.41 5.86 11432.06 3512.92 MInPt-O-EOU 1336.90 1106.:: 992.0 5.83 11492.03 3513.19 MinPt-O-ADP 1351.04 1112.1'mrzEig 5.68 11883.78 3523.27 MinP1-0-ADP 1371.55 1125.70 1003. :1003. , iicE 12182.57 3535.49 MinPt-0SF 1380.41 1132.86 1009.5r.®1 12241.61 3537.60 MinPt-0SF 1804.71 153082 1394. :.111.1111111 13266.49 3540.47 MinPt-0SF 1977.42 1682. 144 6.72 13792.29 3514.98 MinP1-0-ADP 1985.38 1687.26 1538.6'11111111111111E 13864.73 3513.05 MinP1-0SF 1 2228 521 1697.77 1532.88 6.15 15096.13 3493.25 MinPt-CICt 2029 05 1697.19 1531.75 6.13 15140.98 3493.75 MinPt-0-EOU 2029 51 7697.33 1531.5 6.12 15165.90 3494.03 MinPt-0-ADP 1 2071 701 1695.71 1508. 5.521 16856.31 3479.60 MinPts OP17-02PB1(Def Survey) Warning Alert 62.25 58.78 29. 17.62 333.40 333.40 MinPts 62.50 58.59 29.70 15.66 372.82 372.82 MinPt-0-EOU 101.22 89.96 68.41 8.88 771.12 766.72 MinPt-0SF 167.68 149.85 134.8 ® 1060.68 1039.22 MinPt-O-SF 553.53 534.42 520.7 '® 2558.20 2172.01 MinPt-0SF 448.49 426.31 415.69 3568.88 2497.82 MinPt-O-SF 1 366.821 329.10 310.73 9.96 4829.19 2790.94 MinPt-C1Ct 368 01 MIME 308.36 9.38 4882.79 2803.40 MinPt-O-EOU Drilling Office 2.0.960.0 Nikaitchuq\Oliktok Point\0124-08\0124-08\0124-08(P8) 9/13/2011 1:24 PM Page 2 of 13 Offset Trajectory Separation Allow Sep. Reference Trajectory Separation Factor Alert Status Cf-Cf(ft) EOU(ft L Dev.(ft) Fact. MD(ft) I TVD(ft) Alert Minor Major 394.001 325.23 291.34 5.80 5475.95 2941.36 MinP1-O-EOU 407.10 327.42 288.071 5.16 5676.60 2988.02 MinP1-0-ADP 414.28 330.49 289.10 4.99 5754.90 3006.23 OSF<5.00 Enter Alert 511.25 390.33 330.31 4.251 6537.36 3188.21 MinPt-O-SF 732.26 584.85 511 63 4.99 7093.64 3317.59 OSF>5.00 Exit Alert 987.01 820.46 737.68 5.961 8550.94 3538.52 MinPts MEEIII 770.37 679.28 5.23 9483.64 3550.23 MinPt-CtCt 949.11 758.36 663 47 5.00 9780.23 3537.81 OSF<5.00 Enter Alert I 940 22 742.33 643.87 4.77 10100.31 3519.51 MinPt-CtCt 940.48 742.06 643.35 4.76 10131.48 3518.10 MinPt-O-EOU 940.91 742.151 643.2 4.75 10151.78 3517.36 MinPt-O-ADP 941.96 742,49+ 643.2 4.74 10187.93 3516.35 MInPt-O-ADP 966.72 758.33Y 654.620 4.;; 10588.97 3506.09 MinPt-O-SF 8 1041.1807.10p 69055 4.46 11678.43 3515.02 MinPt-O-EOU 1045.541 804 81 684.94 4.36 11958.20 3526.31 MinP1-0-EOU 1046.61 805.02 684.71 4.35 11993.16 3527.74 M1nPt-O-ADP 1094.13 836.19 707.721 4.251 12659.40 3548.64 MInPt-OSF 1122.3 854.9 721.68 4.21 13151.05 3543.07 MinPt-O-EOU • 1124.0 855.1 721.20 4.19 13204.25 3542.13 MinPt-0-EOU 1127.39 855.4 1 719.97 4.161 13270.08 3540.35 MinPts MIEM, 840.68 698 57 3.96 13662.17 3520.17 MInPt-CtCt 1127.11 ilMMI 695 09 3.92 13722.88 3517.60 MinPt-O-EOU 1128.36 839.00 694 821 3.91 13743.10 3516.80 MinPt-O-ADP 1 1116. 803.32 647 25 3.57 14453.60 3500.57 MinPt-CtCt 1116.6 803.111 646.83 3.57 14477.13 3499.95 MinPt-O-EOU 1116.85 803.1 646.78 3.57 14487.22 3499.69 MInP1-0-ADP 1118.20 803.94 647.31 3.571 14524.17 3498.70 MinPt-O-SF MMIGl 785.98 617.24 3.33 15520.41 3494.33 MinPt-CtCt 781.07 609.77 3.28 15725.29 3491.18 MInPt-CtCt 1126.1'�i"'11 606.04 3.25 15860.27 3489.10 MinPt-O-EOU 1134.36 780.83604.56 3.21 16099.98 3487.74 ! MinPt-O-ADP I�'.',,� 'I� 16856.31 3479.60 MinPts OP17-02(Def Survey) Warning Alert 62.25 58.69 29.44 18.16 333.40 333.40 MinPts 62.50 58.67 29.70 15.99 372.82 372.82 MinPt-O-EOU 101.22 90.01 68.41 ZIEE 771.12 766.72 MinPt-0SF 167.68 149.93 134.8 1060.68 103922 MinPt-O-SF 553.53 534.45 520.7 2558.20 2172.01 MinPt-O-SF • 448.49 426.32 415.6' EiDEE 3568.88 2497.82 MinPt-O-SF 329.11 310.74 9.96 4829.19 2790.94 MinPt-CtCt 368.01 MEM. 308.38 9.39 4882.79 2803.40 MinPt-O-EOU • 394...11.11EMEM, 291.35 5.80 5475.95 2941.36 MinPt-O-EOU 407.10 327.4! 0] 5.16 5676.60 2988.02 MinPt-O-ADP 414.26 330.50 289.11 4.99 5754.90 3006.23 OSF<5.00 Enter Alert 511.25 390.33 330. • 3FM 6537.36 318821 MInPt-OSF 732.26 584.84 511.63 4.99 7093.64 3317.59 OSF>5.00 Exit Alen 987.01 820.4 8550.94 3538.52 MinPts 950.5 766.37 674.80 5.18 9521.73 3549.85 MinPl-0tCt 950.7 766.0 874.24 5.17 9540.52 3549.49 MinPt-O-EOU 951.07 766.141 674.11 5.16 9549.91 3549.27 MinPt-O-ADP • 958.91 771.78 678.65.151 9629.85 3546.12 MinP1-0SF 1006.96 804.65 703.98 5.00 10329.43 3512.68 OSF<5.00 Enter Alen ENEEK 796.79 894.13 4.88 1049935 350827 MinPt-CtCt • • 1004..'WOE 691.76 4.83 10599.55 3505.90 MinPt-O-EOU 1004.35 795.5'=Ma 4.83 10609.61 3505.78 MinPt-O-ADP 1055.71 WEE!'i-1 716.21 4.67 11376.82 3512.67 MinPt-O-EOU 1057.80 829..E MBE 4.85 1144873 3512.99 MinPt-O-ADP 1133.36 880.41 MEZE, 449 12473.31 3543.72 MinPt-O-ADP 1143.38 885.83 757.55®l 12663.70 3548.75 MinPt-O-SF 1175.42 905.7 ® 4.37 13228.10 3541.60 MinPt-O-ADP 1178.70 907.06 77173 U 13270.71 3540.33 MinPt-O-SF 1MI=1 890.42 748.92 4.15 13644.08 3520.98 MinPt-CtCt 117612' 888.661 745.42 4.10 13710.40 3518.11 MinPt-O-EOU ® 873.03 724.22 3.93 14008.29 3510.55 MinPt-CtCt 1172 91 M3IEW 722.35 3.91 14057.91 3509.64 MinPt-O-EOU 1176.75 873.0• 3.88 14133.90 3508.13 MinPt-O-ADP .MERM 868.53 713.86 3.81 14351.68 3503.17 MinPt-CtCt M" i 845.19 685.10 3.64 14858.39 3490.71 MinPt-CtCt 1188.31 843.96 682.28 3.61 14979.13 3491.95 MinPt-O-EOU MEEIS 802.21 628.93 3.31 15870.63 3488.94 MinPt-CtCt • 1150.83 M.'. ;n 627.29 3.30 15942.97 3488.32 MinPt-0-EOU 1152.77 801.8 8i'I 3.29 16004.10 3488.09 MinPt-O-ADP 1167.56 810.29 632.15® 16252.43 3487.17 MinPt-O-SF 1207.51 839.30 655.6" EIE 16675.46 3482.52 MinPt-O-SF 1219.3'mrE 660.6 illEe 16856.31 3479.60 MinPts OP14-S3(Def Survey) Pees MEM 85. MEE 37.88 243.97 243.97 MinPts 87.71 85.09 54.90 32.98 308.85 308.85 MinPts 87.75 85.04 54.94 31.95 333.51 333.51 MinPt-0-EOU 123.47 106.67 90.66 899.95 890.05 MinPt-0SF 7719.19 7574.45 7502.5 7608.15 3426.67 MinPt-O-SF 7673.67 7532. 54.75 7867.67 3468.70 MInPt-O-ADP 7873.61 MIME 7462.51 54.78 7871.20 3469.20 MinPt-O-EOU MIEBEE 7532.59 7462.60 54.81 7876.49 3469.96 MinPt-CtCt 6888.81 6654.47 6537.80 29.52 13049.72 3544.85 MinPt-CtCt 6502.83 6210.62 6065.00 2233 14342.28 3503.40 MinPt-CtCt 6503.10 MIME 6064.51 22.29 14354.00 3503.11 MinPt-O-EOU 650346 6210 45 6064 4 22.27 14360.52 3502.95 MinPt-O-ADP Drilling Office 2.0.960.0 Nikaitchuq\Oliktok Point\0124-08\0124-08\0124-08(P8) 9/13/2011 1:24 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 6510.86& 6214.4 6066.77 22.04 14441.21 3500.89 MinP1-0-EOU 6511.17 6214. 6066.70 22.02 14447.72 3500.72 MinPt-O-ADP 6559.13 6257.35 6106.95 21.809 14593.76 3496.79 MinPt-O-SF 6712.2' 1� 6208.93 20.04 15915.48 3488.42 MinPt-O-EOU 6713.34 6376.6•=KEE 19.99 15950.51 3488.29 MinPt-O-ADP II 6726.4 6369.45 6191.43 18.89 16729.21 3481.66 MinPt-CtCt 6726.50 6367.79 6188.93 18.80 16794.16 3480.61 TD OP12.01(Def Survey) Pass Milla1 110 69IMMEI 96.95 2.62 2.62 MinPts .1111=11.1.11MmizEj 33.84 341.77 341.77 MinPts 119.41® 86.61 28.19 410.31 410.29 MinPt-O-EOU 165,85 143.71 133..'KO 895.09 885.46 MinPt-O-SF 183.31 156.07 143.06 Milin 991.25 975.50 MinPt-O-SF 3386.62 3267.99 320916' 5978.88 3058.33 MinPt-O-SF 3870.24 3713.74 3635.//j_ 58817963.62 3481.75 MinPt-O-SF 3857.6'' „ 24.20 8617.87 3543.62 MinPts MIME. 3697.56 3618.02 24.24 8708.65 3548.23 MinPt-CtCt 3681.0••, 3453.19 3339.77 16.22 11714.29 3516.34 MinPt-CtCt 3681.77 3452.46 3338.30 16.12 11779.24 3518.99 MinPt-O-EOU 3682.93 3452 691. 16.06 11819.19 3520.63 MinPt-O-ADP 3789 88 3526 37 3395.11 14.43 13248.25 3541.06 MinP1-CtC1 3790 COI 3525 39 3393501 14.31 13299.62 3539.22 MinPts OP26-DSPO2(Def Survey) Pass 232.02 230.90 199,21 207.14 3.99 3.99 MinPts 175.55 160.01 142.74 11.231 956.74 943.42 MinPt-O-SF 1 167.701 153.96 134.89 12.13 1085.76 1061.93 MinPt.O-EOU 167.51 154.18 134.70 12.49 1107.54 1081.53 MinPts 586.35 565.99 553. 28.7 2096.16 1871.50 MinPt-O-SF 5372.60 5325.83 5302.95 117.34 4310.62 2670.33 TD OP10-09(Def Survey) Pass 1 135.92 134.691 103.111 110.03 4.07 4,07 MinPts 136.311 134.22 103.50 64.60 199.07 199.07 MinPt-O-EOU 207.62 185.56 174.81 iMillani 855.79 848.11 MinPt-O-SF 243.71 215.70 202.31®'' 969.06 954.90 MinPt-O-SF 1892.61 1836.48 1808.90�� 3293.08 2433.68 MinPt-O-SF 1910.77 1854.10 1826.26®i 3316.73 2439.18 MinPt-O-SF 3638.83 3528.76 3474.22 MEM 5559.25 2960.73 MinPt-O-SF 3777.92 3663.66 3607.02 mosEpa 5729.44 3000.31 MinP1-0SF 4058.85 3936.50 3875.62.: 6053.28 3075.63 MinPt-O-SF 4372.16 4215.60 4137.81 8095.37 3497.38 MinP1-0SF 4396.06 4234.57 4154. . STAE 8575.92 3540.59 MinPt-O-SF 4444.93 4266.51=ME 25.05 9514.26 3549.96 MinPt-O-ADP rEME 4306.66 4197.91 20.80 11258.26 3512.14 MinPt-CtCt 4283.25 4166.75 19.38 11919.12 3524.71 MinPl-CtCt 4520.9.MOO 4156.80 18.67 12294.29 3538.99 MinPt-O-EOU 3889.01 3740.26 14.07 14109.89 3508.62 MinPt-CtCt 4187.9,' 3887.821 3738.23 14.00 14154.11 3507.71 MinPt-O-EOU 4188.15 3887.86 13.99 14157.64 3507.64 MinPt-0-ADP 4222.48J 3914.1• 13.77 14390.87 3502.19 MinPt-O-ADP i 4232.5 3922.09 3767.35 13.67 14535.65 3498.38 MinPt-CtCt 4232.6 3922.0 3767.19 13.67 14546.18 3498.10 MinP1-0-EOU 4232.75 3922.0 3767.1 13.66 14551.44 3497.95 MinPt-O-ADP 4236.46 3925.14 3769.98 13.61 14593.54 3496.79 MinPt-O-SF 3910.49 3745.67 12.86 15359.67 3496.15 MinPt-CtCt 3884.90 3713.08 12.30 15906.90 3488.47 MinPt-CtCt 4230.03Man 3712.05 12.27 15947.30 3488.30 MinPt-O-EOU G' I 3861.55 3683.13 11.82 16416.06 3486.56 MinPt-CtCt 4221.01 -00 ,, 3680.77 11.74 16520.80 3485.03 MinP1-0-EOU 4226. '1111103CE 3676.21 11,54 16780.72 3480.82 MinPt-O-EOU 4228.',MEDZIMENEE 1.111BIY: 16856.31 3479.60 MinPts Oliktok Point I-2PB1(Def Survey) Pass 208.41 207 34 175.61 192.31 0.00 0.00 Surface 207.3,Forum 192.31 40.00 40.00 MinPts 205.0:_ 201.731 ] 60.89 451.47 451.41 MinPts 205.1 mars 172.32 59.00 474.85 474.74 MinPt-0-EOU ®" 'IIMEIMOMIINEK 17.96 765.93 761.68 MinPts 206.2173.43 13.23 898.42 888.60 MinPt-O-EOU MIME c ••f M.5 11.17 1278.91 1230.96 MinPts 205.43 186.88 172.62 11.01 1302.89 1251.14 MinPt-O-EOU 217.89 195.71 185.0. a] 1566.98 1463.07 MinP1-0SF 250.18 217.95 202.37 8.00 2103.86 1877.25 MinPt-O-SF 452.94 403.33 379.0 ;®l 2941.32 2341.85 MinPt-O-SF 465,91 414.93 389.931 r1 1 2988.42 2357.21 MinPt-O-SF 1714.43 1583.47 1518.48 13.18 6347.45 3144.05 TD 0116106 Point 1-2(Def Survey) Pass' 208.41 207.34 175,61 192,31 0.00 0.00 Surface 207.3,=Ma� 192,31 40.00 40.00 MinPts 201.7 ® 60.89 451.47 451.41 MinPts 205.13M:11E 172.32 59.00 474.85 474.74 MinPt-O-EOU 204.59=IEEM MEE 17.96 765.93 761.68 MinPts 206 23 M 173.43 13.23 898.42 888.60 MinPt-O-EOU �' "•MVO 11.17 1278.91 1230.96 MinPts 205 43 186.88 172.62 11.01 1302.89 1251.14 MinPt-O-EOU 217 89 195.71 185.08) 9 78 1566.98 1463.07 MinPt-O-SF 25018 217.95 202.37 8.00 2103.86 1877.25 MinPt-O-SF Drilling Office 2.0.960.0 Nikaitchuq\Oliktok Point\0124-08\0124-08\0124-08(P8) 9/13/2011 1:24 PM Page 4 of 13 Offset Trajectory Separation Allow Sep. Reference Trajectory Separation Factor Alert Status Ct-Ct(ft)I EOU(ft) Dev.(ft) Fact. MD(ft) I TVD(ft) Alert I Minor I Major 452.94 403.33 379.0 9 29 2941.32 2341.85 MinPt-O-SF 465.91 414.93 389.9 9.30 2988.42 2357.21 MinPt-O-SF 1692.05 1557.80 1491.1 12.69 6381.15 3151.88 MinPt-O-SF 2095.76 1930.23 184796 12.73 7878.03 3470.17 MinPts 2094.67 1930 2111 1848 48 12.81 8029.28 3489.87 MinPt-O-EOU 2120.45 1951.61 1867 691 12.631 8548.80 3538.34 MinPt-O-SF 2152.48 1979.57 1893 61 12.51 9030.72 3552.63 MinPt-O-SF 2284.66 207821 1975.48 11.11 10469.77 3509.03 MinPt-O-EOU 2287.19 2078.70 1974.961 11,02 10559.71 3506.70 MinPt-O-ADP Wall 2086.87 1970.89 10.00 11622.35 3513.84 MinPt-CtCt 2320.55 2086.15 1969.43 9.94 11688.28 3515.34 MinP1-0-EOU 2321.39 2086.33 1969.28 9.91 11718.74 3516.52 MinPt-O-ADP 2345.9. 2097.89 1974.36 9.49 12247.69 3537.76 MInPt-O-EOU 2346.98 2098.10®, 9.46 12282.63 3538.69 MinPt-O-ADP mgEggi 2114.81 1981.12 8.91 13174.91 3542.65 MinPt-CtCt • 2384.41 1977.91 8.82 13248.89 3541.04 MinPt-O-EOU 2385.49 2113.3.• 8.79 13267.44 3540.44 MinPt-O-ADP 2385.71 2113.39 1977.7- 13271.77 3540.29 MinPt-O-SF 2387.39 2114.8'=ME 8.79 13369.55 3535.70 MinPt-O-ADP 2389.06 2115.52 1979.2'MIKE 13415.47 3533.08 MinPt-OSF Oliktok Point I-2P82(Def Survey) Pass . 208.41 207 43 175.61 210.75 0.00 0.00 Surface 208.41 207 3•! IWI] 40.00 40.00 MinPts 205.08 201.76®'; 61.59 451.47 451.41 MinPts 205.1 =EZE1 172.32 59.62 474.85 474.74 MinPt-0-EOU ®" •=MI MOM 17.98 765.93 761.68 MinPts 206.2IITIMEEE 173.43 13.23 898.42 888.60 MinPt-0-EOU 151®' ' MEMI 11.17 1278.81 1230.96 MinPts 205.43 MIME 172.62 11.02 1302.89 1251.14 MinPt-O-EOU . 218.20 195.97 185 39 9.77' 1571.94 1466.97 MinPt-O-SF 250.18 217.95 202.38 8.00 2103.86 1877.25 MinPt-O-SF 452.94 403.33 379.02 9.29 2941.32 2341.85 MInPt-OSF I 465.91 414.94 389.94. 9.30 2988.42 2357.21 MinPt-O-SF 1692.05 1557.80 1491.17` 12.89 6381.15 3151.88 MinPt-0SF 209576 1930.2 1847.97 12.73 7878.03 3470.17 MinPts 2094.67 1930.22 1848.48 12.81 8029.28 3489.87 MinPt-O-EOU 2120.45 1951.62 1867 69 MEM 8548.80 3538.34 MinPt-O-SF 2152.48 1979.57 1893.61 12.51 9030.72 3552.63 MinPt-O-SF 2283.15 2081.34 1980.92ii 11.38 10270.39 3514.21 MinP1-0-ADP 2288.12 208343 1981 581 11.231 10396.79 3510.93 MinPt-0SF 0107-04(Del Survey) Piga 1 159.911 158.68 127.101 129.64 3.88 3.88 MinPts 160.11 157.3-,'11 127.31 57.29 318.42 318.42 MinPt-O-EOU • 238.08 226.98 205.27 21.34 799.89 794.51 MinPt-O-SF 2002.41 1984.57 1969.61 2071.67 1853.04 MinPt-O-SF 2313.48 2292.81 2280.67 2174.69 1929.10 MinPt-O-SF 2497.22 2475.01 2484.41 112.41 2224.29 1964.19 MinPt-O-SF 3246.48 3216.78 3202.47 2362.97 2056.71 MinPt-O-SF 4356.90 4324.37 4308.60. 138.10 2499.74 2139.40 MinPt-OSF 10817.49 10682.53 10615.55 80.74 8947.23 3551.76 MinPt-O-SF OP08-04PB1(Def Survey) Pass =EC 150.661 119.08 123.09 0.00 0.00 MinPts 152.20 119.39 69.24 183.90 183.90 MinPt-0-EOU 249.24 229.60 216.43 MBE 853.98 846.38 • MInPt-0-SF 5935.76 5868.96 5836.06. 90.181 4134.29 2629.32 MinPt-0-SF OP06-04(Def Survey) Pass 151.89 150.661 119.081 123.09 0.00 0.00 MinPts 152.20 150.02 119.39 69.24 183.90 183.90 MinPt-O-EOU I 249.24 229.60 216.431 853.98 846.38 MinPt-O-SF 6675.09 6527.93 6454.: 'NEM 7584.87 3422.44 MinP1-0SF 6661.35 8515.0'" :51 45.85 7704.82 3443.45 MinPt-O-ADP 6661.3.=DEE 6442.46 45.86 7706.94 3443.80 MinPt-O-EOU 666 2, 6515.11 6442.52 45.87 7713.31 3444.86 MinPt-CtCt 6661.35 6515.76 6443.45 46.06 7766.75 3453.50 MinPt-CtCt 6348.30 617451 6088.10 36.73 10061.10 352168 TD 0106-05(P9c)(Def Plan) Pass 175.90 174.68 143.10 142.72 0.00 0.00 Surface 175.90 172.88 143.10 57.76 299.11 299.11 MinPts 175.93 172.84 143.13 56.48 318.59 318.59 M1nPt-O-EOU 261.71 246.94 228.90 17.64 827.03 820.60 MinPt-O-SF 597.93 584.40 565.1 44.10 1113.74 1087.09 MinPt-O-SF 4746.37 4724.15 4713.5 213.49 1304.51 1252.50 MinPt-O-SF 5723.55 5684.86 5666.05 15211 1394.76 1326.66 MinPt-0SF 5855.11 5815.54 5796.29 152.05 1420.92 1347.61 MinPt-0SF 6280.12 6236.70 6215.4 147.99 1601.46 1490.16 MinPt-O-SF 6925.43 6874.30 6849.2 138.10 1879.01 1705.85 MinPt-O-SF 7207.17 7151.43 7124.06 13161 2018.14 1812.35 MinPt-O-SF 7767.12 7702.14 7670.1 121361 2149.46 1910.86 MinPt-O-SF 8041.76 7974.47 7941.3 121.27 2191.67 1941.23 MinPt-O-SF 8433.04 8363.38 8329. 122.77 2236.15 1972.43 MinPt-O-SF 8721.09 8649.99 8614. 124.38 2264.69 1992.01 MinPt-O-SF 8754.07 8682.71 8647.5 124.38 2267.94 1994.21 MinPt-O-SF 11241.73 11155.21 11112.45 131.42 2476.90 2126.21 TD Drilling Office 2.0.960.0 Nikaitchuq\Oliktok Point\0124-08\0124-08\0124-08(P8) 9/13/2011 1:24 PM Page 5 of 13 Offset Trajectory Separation Allow Sep. Reference Trajectory Separation Factor Alert Status Ct-Ct(ft)I EOU(ft) Dev.(ft) Fact. MD(ft) I TVD(ft) Alert I Minor I Major 0106-05 current(Non-Def Survey) Pass IMEICEI 173.07IMEMi 68.08 224.07 224.07 MinPts mum 172.66 miEus 58.69 264.01 264.01 MinPts 176.33® 143.52 42.07 361.94 361.94 MinPt-O-EOU 284.94 247.78 232.13 mg2E0 792.18 787.07 MinPt-O-SF 1428.72 1406.42 1395.91=EMI 1301.87 1250.29 MinPt-O-SF 1691.41 1670.20 1658.61 79.67 1323.97 1288.73 TD 0111-01PB1(Def Survey) Pas 127.75 126.0594.94 74 38 138.95 138.95 MinPts 128.20 125.61 95.39 49.07 308.77 308.77 MinPt-O-EOU 238.57 216.40 205.7 MI113511 1049.48 1029.02 MinPt-O-SF 298.61 263.61 246.7 ma= 1216.86 1177.88 MinPt-O-SF 4203.28 4129.96 4093.79 58.09 4347.02 2678.80 TD 0111-01(Def Survey) Pas. 127 75 126.05 94 94 74.38 138.95 138.95 MlnPts 128.20 12561 95.39 49.07I 308.77 308.77 MinPt-O-EOU 238.57 216.40 205.77�J 1049.48 1029.02 MInPt-O-SF 298.61 263.61 246.72 8.80 1216.88 1177.88 MinPt-O-SF 5325.79 5184.08 5113.71® 7791.48 3457.36 MinPt-O-SF 5324...M'.MNIM 37.85 7824.04 3462.31 MinPts MEM 5183.33 5113.00 37.85 7827.01 3462.76 MinPt-CtCt IIETZED,®MIMEO 10536.70 3507.30 MinPts OP05-06PB2(Def Survey) Pas 183.67 181.78 150.86 96.77 153.94 153.94 MinPts 183.7 181.73 150.92 91.22 173.94 173.94 MinPt-O-EOU 287.93 275.90 255.13 23.82 799.86 794.28 MinPt-O-SF 6500.17 6477.96 6467.36 292.561 1201.44 1164.50 MinPt-O-SF 9592.79 9509.84 9468.8 117.081 2078.56 1858.26 MinPt-OSF 9788.02 9683.85 9642.281 117.471 2092.87 1868.88 MinPt-O-SF 10110.38 10023.50 9980.561 117.731 2121.33 1890.22 MInPt-OSF 11134.90 11042.06 10996.161 121.271 2205.82 1951.24 MinPt-O-SF 11186.77 11093.59 11047.50 121.36 2211.27 1955.08 TO OP05-06PB1(Def Survey) Pas 183.67 181.78 150.86 96.77 153.94 153.94 MinPts 183.73 181.73 150.92 91.22 173.94 173.94 MinPt-O-EOU 287.93 275.90 255.1 ME133 799.66 794.28 MinPt-O-SF 1793.32 1781.04 1760.51 145.90 1407.27 1338.71 TD I 1798.301 1786.011 1765 490 146 261 1407.27 1336.71 MinPts OP05-06(Def Survey) pas 183.67 181.78 150.86 96.77 153.94 153.94 MinPts 183.73 181.73 150.92 91.22 173.94 173.94 MinPt-O-EOU 287.93 275.90 255.13 EiliS 799.66 794.28 MinPt-O-SE 6500.17 6477.96 6467.36=ME 1201.44 1164.50 MinPt-O-SF 9592.79 9509.84 9468.8 2078.56 1858.26MinPt-O-SF 9771.82 9687.62 9646.0.NM= 2093.01 1869.14 MinPt-O-SF 10110.38 10023.49 9980. :MBE 2121.33 1890.22 MinPt-O-SF 12535.11 12435.50 12386.19 127.10 2308.38 2021.30 TD OPO4.07(Def Survey) Pas 191.12 188.53 158.31 73.47 278.84 278.84 MinPts 191.18 188.47 158.36 70.54 303.72 303.72 MinPt-O-E0U 192.46 189.61 159.6 386.21 386.20 MinPt-O-SF 297.52 283.74 264.71® 899.02 889.17 MinPt-OSF 8256.47 8201.15 8173.9 Man 3674.40 2522.36 MinPt-0SF 8699.70 8641.23 8612. •=EMI 3828.15 2558.12 MinPt-O-SF 9481.99 9340.60 9270.41® 9096.37 3552.66 MinPt-O-SF 9866.94 9719.51 9646.2.® 9463.60 3550.36 MinPt-O-SF 10526.81 10368.97 10290.5 IMRE 9999.69 3525.17 MinPt-OSF OPO4-07PB1(Def Survey) Pas 191.12 188.53 158.31 73.47 278.84 278.84 MinPts 191.16 188.47 158.36 70.54 303.72 303.72 MinPt-O-EOU 192.46 189.61 159.6 MME 386.21 386.20 MinPt-O-SF 297.52 283.74 264.71)J® 899.02 889.17 MinPt-O-SF 8180.79 8126.07 8099.2.I® 3639.81 2514.32 MinPt-0SF 943906 9298.80 9229.15 67.76 9076.21 3552.73 TD OP03-P05PB1(Def Survey) Pass MIMI 198.52 16T01 153.00 64.00 64.00 MinPts 199.9- 197.691 167.1) 89.19 244.00 244.00 MinPts 200.06 197.55 167.26 78.95 299.00 299.00 MinPt-O-EOU 302.19 290.15 269.38 mum850.07 842.65 MinPt-O-SF 4072.65 4050.40 4039.8- 183.06 1924.57 1740.84 MinPt-O-SF 4114.84 4092.23 4081.51-M1M 1946.89 1757.95 MinPt-O-SF 4581.15 4554.88 4542.34�� 2118.70 1888.28 MinPt-O-SF OP03-P05(Def Survey) Pas 199.81 198.52 167.01 153.00 64.00 64.00 MinPts 199.9 1 197.69 167.11 89.19 244.00 244.00 MinPts 200.06 197.55 167.26 78.95 299.00 299.00 MinPt-O-EOU 302.19 290.15 269.38 mom850.07 842.65 MinPt-O-SF 3983.45 3962.32 3950.6' 188 46 1877.67 1704.82 MinPt-O-SF 4069.56 4047.58 4036.7mom 1922.23 1739.05 MinPt-O-SF 4112.50 4090.30 4079.6.=EMI 1944.80 1756.35 MinPt-O-SF 4454.62 4427.80 4414...MEMO 2101.64 1875.60 MinPt-O-SF Drilling Office 2.0.960.0 Nikaitchuq\Oliktok Point\0124-08\0124-08\0124-08(P8) 9/13/2011 1:24 PM Page 6 of 13 Offset Trajectory Separation Allow Sep. Reference Trajectory Separation Factor Alert Status • Ct-Ct(ft)I EOU(ft) Dev.(ft) Fact. MD(ft) I TVD(ft) Alert I Minor I Major 4750.09 4721.92 4708. 174.91 2151.48 1912.33 MinPt-O-SF 5154.28 5123.34 5108.3 172.22 2221.25 1962.07 MinPt-O-SF 6506.80 6469.62 6451. 179.92 2377.06 2085.64 MInPt-OSF 9556.21 9507.82 9484.12 201.57 2688.18 2238.34 TD �. OP03-P05PB2(Def Survey) Pass 199.81 198.52 167.01 153.00 64.00 64.00 MinPts 199.92 197.69 167.11 89.19 244.00 244.00 MinPts 200.06 197.55 167.26 78.95 299.00 299.00 MinPt-O-EOU 302.19 290.15 269.38®" 850.07 842.65 MinPt-OSF 3983.45 3962.32 3950.. 188.47 1877.67 1704.82 MinPt-OSF 4089.56 4047.58 4036.7 IN= 1922.23 1739.05 MirrPt-0SF 4112.50 4090.30 4079.6.INNS 1944.80 1756.35 MinPt-0SF 4454.62 4427.80 4414.•r INNS 2101.64 1875.60 MinPt-0SF 4750.09 4721.92 4708. '- 2151.48 1912.33 MinPt-OSF 5154.28 5123.34 5108. :- 222125 1962.07 MinPt-O-SF 6506.80 6469.62 6451. •- 2377.06 2065.64 MinPt-O-SF 7477.79 7436.44 7416.28 18540 2483.83 2130.24 TD OP09-S1(Def Survey) Pass I 143.91 142.68] 111.101 116.57 0.00 0.00 MinPts • 144.47 141.071 111.86 42.12 333.05 333.05 MinPt-O-EOU 256.60 240.19 223.7. J$8 902.58 892.54 MinPt-O-SF 330.92 308.68 298.11- 1037.80 1018.35 MinPt-O-SF 365.29 339.70 327.5.- 1092.78 1068.27 MinPt-O-SF 10432.81 10292.78 10223. - 7649.83 3434.06 Min191-0SF •• 10390.69 10251.23 10181.x+- 7700.56 3442.74 MinP1-0SF 10198.26 10060.74 9993.':- 7927.24 3476.96 MinPt-O-SF 10181.31 10028.24 9959. •- 7949.31 3479.89 MinPt-OSF i 10123.27 9988.68 9921.8:- 7971.21 3482.72 MinPt-O-SF 10082.22 9948.13 9881.5:- 7992.92 3485.45 MinPt-O-SF 8950.5 8670.88 8531.53 32.11 14220.69 3506.27 MinPt-CtCt 8950.66 8670.71 8531.34 32.09 14224.76 3506.18 MinPt-0-EOU 8950.80 8870.8 8531.321 32.08 14226.80 3506.13 MInPt-O-ADP • 8975.6 8685.71 8541.22 31.08 14432.75 3501.11 MInPt-CtCt 8975.7 8685.62' 8541.04 31.04 14436.81 3501.01 MinPt-O-EOU 8975.89 8885.6'57 8541.021 31.03 14438.85 3500.96 MinPt-O-ADP 9287.81 8924.71 8753.66 27.09 18407.99 3486.60 TD '.I•^ - °' 9389.0.mmsE 12657.57 3548.59 MinPts Oliktok Point I-15-106(P5)(Def Plan) Peas 216 45 215.34 183 64 193.14 40.10 40.10 MinPte 216.56 215.23 183.75 163.08 84.20 84.20 MinPt-O-EOU 360.60 350.07 327.79 MINN 801.78 796.31 MinPt-O-SF 2070.1. 2055.86 2037.2•,.a 1301.07 1249.62 MinPts 7430.41 7407.90 7397.60 MErki 1126.80 1098.75 MinPt-O-SF 11725.38 11617.75 11564.89 110.89 1952.28 1782.08 MinPt-O-SF 12120.87 12010.05 11955.60 MINK. 2070.73 1852.34 MinPt-O-SF 13458.04 13338,79 13277.12 112.75 2170.12 1925.82 TD Oliktok Point 1-1(Def Survey) Pass 216.45 215.34 183.64 193.14 40.10 40.10 MinPts 216.56 215.23 183.75 163,08 84.20 84.20 MinPt-O-E0U 360.60 350.07 327.79- 801.76 796.31 MinP1-04F 2254.87 2241.53 2999.06 169.01 1302.49 1250.81 TD 7665.04 7642.89 7632. '-, 1215.51 1176.71 MinPt-O-SF 7788.21 7764.53 7753.1 342 991 1236.45 1194.77 MinPt-O-SF 0113-03(P6)(Def Plan) Pass ® 92.88 91.93 49.78 339.40 339.40 MinPt-CtCt 9585 92.68 91.59 43.46 422.70 422.67 MinPt-O-EOU 95.90 92.69- 42.55 432.36 432.33 MinPt-O-ADP 96.96011(EIE91.95 35.58 504.89 504.68 MinPt-O-EOU • 97.61 93.41- 30.03 529.07 528.75 MinPt-O-ADP 125.84 109.04 101.1'-'-O 901.61 891.62 MinPt-OSF 428.97 378.71 354.0 11111111111012. 2174.21 1928.75 M1nPt-OSF • 3243.83 3073.74 2989.1:- 7945.54 3479.39 MinPt-OSF 3227.08 3059.7'.BEM 19.39 8185.86 3506.55 MinP1-0-ADP 3228.5; 3059.6. 2976.63 19.43 8207.92 3508.59 MinP1-0-EOU NEEIn 3058.08 2971.91 18 74 8592.59 3541.86 MinPt-CtCt 3216.62 3039.84 2951.r•- 9022.57 3552.55 MinPt-O-SF • 2658.48 2345.75 2190.:r. 14399.46 3501.97 MinPt-O-SF 2655.75 2345.1,•.NRENI 8.58 14429.52 3501.20 MinPt-O-ADP 2655.71 Ng= 2190.42 8.58 14434.14 3501.08 Min191-0-EOU 2345.22 2190.47 8.58 14441.08 3500.90 MinPt-CtCt 2685.46-• ,_ 2169.63]- 16856.31 3479.60 MinPts SP36-W5(P2)(Def Plan) Pass 7888.651 7885 301 841 5338.15 300.57 300.57 MinPts 17889.77 17888.54 17856.96 14615.32 0.00 0.00 Surface I 4169.091 3887.911 3749.941 15.091 16858.31 3479.60 MinPts 5135-W4(P2)(Def Plan) Pass I 17884.4:1 '�r7' 5342.87 300.57 300.57 MinPts 17889.00 17887.78 17856.19 14614.70 0.00 0.00 Surface I 5000.751 4718 881 4580.441 18.041 16856.31 3479.60 MinPts SP33-W 3(P2)(Def Plan) Pass IL. 17886.09f :tE1g. 5349.15 300.58 300.58 MInPts 17887.38 17886.16 17854.57 14613.37 0.00 0.00 Surface Drilling Office 2.0.960.0 Nikaitchuq\Oliktok Point\0124-08\0124-08\0124-08(P8) 9/13/2011 1:24 PM Page 7 of 13 Offset Trajectory Separation Allow Sep. Reference Trajectory Separation Factor Alert Status Ct-Ct(ft), EOU(ftL Dev.(ftL Fact. MD(ft) I TVD(ft) Alert I Minor I Major 5604.69 5323.86 5185.84 20.29 16856.31 3479.60 MinPts SI32-W2(P2)(Def Plan) Pass 'MEM 7881.931 7852 461 5347.26 300.58 300.58 MinPts 17886.58 17885.35 17853.77 14612.71 0.00 0.00 Surface I 6716.811 6436.44 6298.41 24.32 16739.94 3481.48 MinPt-CtCt 6717.28 6436.06 6297.61 24.24 16779.54 3480.84 MinPt-O-EOU 6717.82 6436.18 6297.53 24.21 16799.34 3480.52 MinPt-O-ADP 6720.56 6437.71 629845 24.111 16856.31 3479.60 MinPt-O-SF SP30-W 1(P2)(Def Plan) Pass II=IMEEKIE MEESE 5344.68 300.58 300.58 MinPts 17884.25 17883.03 17851.44 1461081 0.00 0.00 Surface I 7982.291 7704.57 7567.63 29.13 18759.45 3481.17 MinPt-CtCt 7982.69 7704.14 7566.79 29.04 16799.12 3480.53 MinPt-0-EOU 7983.20 7704.24 7566.68 29.00 16818.95 3480.20 MinPt-O-ADP 7984.75 7705.00 7567.04 28.931 16856.31 3479.60 MinPt-O-SF Tuvaaq ST 1(Def Survey) Peas �__ 1 l7094 6300.00 162.14 162.14 MinPts 1717® _17124.49 A0 17094 55 5736.09 197.17 197.17 MinPt-O-EOU �, 17094.97 4283,18 336.95 336.95 MinPts 17127.7:I®. 17094.97 4270.64 338.75 338.75 MinPt-O-EOU MEM 7706.59=ME 29.88 16856.31 3479.60 MinPts Kigun 1(Def Survey) Pass 17124.4•i 1709440 6300.00 162.14 162.14 MinPts 17127. •NUM 17094.55 5736.09 197.17 197.17 MinPt-O-EOU IMMUIE MIME 17094.97 4283.18 336.95 336.95 MinPts 17127.7,.11511E1in 17094.97 4270.64 338.75 338.75 MinPt-0-EOU 7706.59 IIMEMI MEE 16856.31 3479.60 MinPts Kigun 1 PB1(Def Survey) Peas. 17124.4' 17094.'( 6300.00 162.14 162.14 MlnPts 17127 36.IMEMEE. 17094.55 5736.09 197.17 197.17 MinPt-O-EOU Malt.mgrEiim17094.9 4283.18 336.95 336.95 MinPts 17127.7•EN/12155 17094.97 4270.84 338.75 338.75 MinPt-O-EOU 7706 59 MEEKIIIIMIE 16856.31 3479.60 MinPts SI29-S2(P2)(Def Plan) Pass 17883.7 17880.1 17850,92 4983.62 331.55 331.55 MinPts 17883.7 17880.1 17850 92 4972.80 333.93 333.93 MinP1-0-EOU 17883.45 17882.22 1785064 14610.16 0.00 0.00 Surface 17883. 17880.8 17850. 7003.65 198.80 198.80 MinPts 17883.7 17880. 17850.92 5718.88 258.80 258.80 MinPt-O-EOU 1 8096. 7812.2 7672.34 28.911 16853.42 3479.65 MinPts 11030.22 10754.34 10617,44 40.28 16856.31 3479.60 TD 7642.68 7393.35 7270.. MEM 14310.68 3504.17 MinPt-O-SF 7642.51 7393.15 7270.24 31.08 14324.52 3503.84 MinPts 7642.51 7393.15 7270.24 31.08 14325.68 3503.81 MinPt-O-EOU 8094.91 7810.96 7671.06 . 16848.63 3479.72 MinPt-O-SF SP27-N1(P3)(Def Plan) Pass :E:r MEEEIEll MEM 5413.56 300.58 300.58 MinPts 17881.82 17880.60 17849.02 14608.83 0.00 0.00 Surface II 8935.411 8665.68 8532.52 33.54 16386.58 3486.68 MinPt-C1C1 8935.78 8665.32 8531.78 33.45 16421.31 3486.53 Min181-0-EOU 8936.43 8665.44 8531.64 33.38 16446.80 3486.22 MinPI-0-ADP 899520 871564 8577.54 32.561 16856.31 3479.60 MinPt-0SF 5125-N2(P2)(Def Plan) Pass 1 17879.05 17875 701 17846 5337.03 300.58 300.58 MinPts 17880.35 17879.13 17847.54 14607.83 0.00 0.00 Surface 1 9738.19 9479.54 9351.69 38.07 15764.48 3490.57 MinPt-CtCI 9738.54 9479.25 9351.08 37.98 15794.30 3490.12 MinPt-O-EOU 9738.95 9479.34 9351.02 37.94 15809.21 3489.89 MinPt-0-ADP 9999.37 9717.05 9577.29 35.761 16856.31 3479.60 MinPt-O-SF SP23-N3(P3)(Det Plan) Pass I :P. :T :_:yIl�l 5408.72 300.58 300.58 MinPts 17877.49 17876.27 17844.68 14605.29 0.00 0.00 Surface 1 10293.35 10061.95 9947.52 44.97 14525.22 3498.67 MinPt-CtCt 10293.36 10061.94 9947.51 44.96 14526.06 3498.64 MinPt-0-EOU 10293.38 10061.95 9947.51 44.96 14526.90 3498.62 MinPt-0-ADP 10308.81 10076.65 9961.88 44 14562.84 3497.64 MinPt-O-SF 11225.86 10949.54 10812.50 40 95 16856.31 3479.60 MinPt-0SF SP24SEI(P2)(Def Plan) Pass 17878.5 17874.92 1784571 4962.84 334,13 334.12 MinPts 17878.5 17874.92 1784572 4952.30 336.52 336.52 MinPt-0-EOU 17878.23 17877.01 17845.42 14605.89 0.00 0.00 Surface 17875.6:: 17845.42 6999.39 198.80 198.80 MinPts 17878.51 MiTEMEr 17845.70 5787.63 253.80 253.80 MinPt-0-EOU unTEE11580.08 11476.43 56.86 7914.89 3475.29 MinPt-CtCt 11789.2 M"' 11474.53 56.36 7942.61 3479.01 MinPt-0-EOU 11790.50 11579.3 I 6 9I 56.10 7957.00 3480.89 MinPI-0-ADP 11620.92 11398.71 11288.0•' 10175.06 3516.69 MinPt-0SF MIME 11953.54 11835.44 51.61 14973.91 3491.89 MinPt-CtCt 11842.63 1158501 11457.14 46.30 15900.58 3488.53 TD 1 10634.24 10401.66 10286.02 45.97 14132.26 3508.16 MinPt-CtCt 10634.25 10401.651 10285.99 45.97 14135.81 3508.09 MinPt-O-EOU Drilling Office 2.0.960.0 Nikaitchuq\Oliktok Point\0124-08\0124-08\0124-08(P8) 9/13/2011 1:24 PM Page 8 of 13 II 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 , • 10634.27 10401.651 10285.99 45 97 14137.58 3508.06 MinPt-O-ADP • 10655.08 10421.23 10305.16 45.89 14262,37 3505.32 MinP4-0-5F 10658.01 10424.07 10307.97 45.89 14271.20 3505.11 MinPt-O-SF 11521,77 11267,49 11141.44 45.70 15710.69 3491.40 MinPt-O-SF 6120-N4PB1(P1)(Def Plan) Paw �. 17870.61.1�il 5402.29 300.58 300.58 MinPts EliME 11486.28 11373.24 51.81 14393.27 3502.12 MinPt-CtCt 11713.62 11486.27 11373.23 51.81 14393.31 3502.12 MinPt-0-EOU 11713.63 11486.27® 51.81 14393.33 3502.12 MInPI-0-ADP 11716.58 11489.07 11375.96 14394.37 3502.10 MinPt-O-SF 1251806 12295.00 12183.97 56,36 14474.52 3500.02 TD 17875 21 17873 98 17842.40 14603.43 0.00 0.00 Surface Ej=1 17870.621 17841 1111 5424.54 298.79 298.79 MinPts 5114-146(P2)(Def Plan) Pass I17868.831 17865 32) 17836.02 5082.04 300.59 300,59 MinPts • 17870.55 17866.75 17837.74 4696.371 348.94 ,348.94 MinPt-O-SF • ( 11798.361 11571.491 11458.62 52.26 14368.92 3502.74 MlnPta • 11798.45 11571.57 11458.70 62.261 14369.82 3502.72 MinPt-OSF 17870.13 17868.90 17837.32 14599.27 0.00 0.00 Surface 15487.26 15210.11 15072.021_ 56.08 16856.31 3479.60 MinPt-O-SF SD37-0SP1(P4b)(Def Plan) Pass 17891.47 17888.1 17858.67 5341,28 300.57 300.57 MinPts 17891.48 17888.1 17858.67 5329.63 305.30 305.30 MinPt-O-EOU 1 11914.64 11685.52 11571.67 52.32 14480.91 3499.85 MinPt-CtCt 11914.64 11685.52 11571.66 52.31 14480.93 3499.85 MinPt-O-EOU i 11914.64 11685.52 11571.66 52.31 14480.95 3499.85 MinP1-0-ADP 11916.51 11687.29 11573.38 52.301 14481.81 3499.83 MinPt-O-SF 12418.32 12195.06 12083.94 55.87 14495.97 3499.45 TO 17891 47 17890.36 17858 67 16051.16 0.00 0.00 Surface 1 17891 4711 17886 1411 17858 671 298.80 298.80 MinPts SP11-N7(P2)(Def Plan) Pass L17865.501178621 17832.70 5302.62 300.59 300.59 MinPts 1924.46 11698.2 11585.67 52.95 14334.30 3503.60 MinPts 11924.73 11698.54 11585.93 52.941 14336.38 3503.55 MinPt-O-SF 17866.70 17865.48 17833.89 14596.47 0.00 0.00 Surface 15877.17 15446.74 15332...I 14447.45 3500.73 MinPt-O-SF 15698.07 15467.32 15352.''I 14458.54 3500.44 MinP1-0SF 15719.39 15488.33 15373. .I 14469.61 3500.15 MinPt-O-SF 15742.36 15510.96 15395.7 68. . 14481.27 . 3499.84 MinPt-O-SF 15764.56 15532.82 15417. 68.31 14492.28 3499.55 MinPt-O-SF 15780.85 15548.88 15433.3. 68.31 14500.22 3499.34 MinPt-O-SF 15792.26 15560.12 15444, 68.311 14505.70 3499.19 MinPt-O-SF 16732.76 16453.15 16313.85 60.051 16856.31 3479.60 MinPl-OSF Sx34-N Sand(P2)(Def Plan) Pass 17888.20 17884.7 17855,39 5170.28 300.57 300.57 MinPts 17888.2 17884.7 1785540 5159.20 305.31 305.31 MinPt-O-EOU 17888.20 17888.97 17855.39 14814,04 0.00 0.00 Surface 1 10962.41 10732.52 10618.51 48.07 14500.73 3499.33 MinPt-CtCt 10962.42 10732.521 10618.51 48.07 14501.28 349931 MinPts 10969.54 10739.33 10625.1 48. 14519.30 3498.83 MinPt-O-SF 12108.16 11830.04 11691.71 43.76 16856.31 3479.60 MinPt-OSF SP22-FN1(P2)(Def Plan) Pass 17877. 17873.4 17844.2 4960,22 334.18 334.18 MinPts • 17877. 17873. 17844.23 4949.86 336.58 336.58 MinPt-O-EOU 17876.74 17875.52 17843.93 14604.68 0.00 0.00 Surface 17876.7 17874.1 17843.9 8998.17 198.80 198.80 MinPts 17876.9 17873. 17844.17 5876.08 248.80 248.80 MinPt-O-EOU 1 12148.95 11873.06 11735.931 44.291 16856.31 3479.60 MinPts 5117SE2(P2)(Del Plan) Pass 17872.6 17869.01 17839.81 4953.08 334.35 334.35 MinPts 17872.6 17889.01 17839.81 4943,15 336.76 336.76 MinPt-O-EOU 17872.32 17871.09 17839.51 14601.06 0.00 0.00 Surface 17872.3 17869.7 17839.51 6994.53 198.80 198.80 MinPts 17872.5 17869.5 17839.76 5863.71 248.80 248.80 MinPt-O-EOU II 12994.3 12788.36 12685.87 63.39 7922.59 3476.34 MinPt-CtCI , • • 12995.3 12787.291 12683.75 62.75 7950.00 3479.98 MinPt-0{OU 12996.77 12787.5,'11 12683.1 62.42 7964.64 3481.88 MinPt-O-ADP 12851.95 12629.12 12518. 57.931 10170.50 3516.81 MinPt-O-SF 12078.43 11965.05 54.27 14538.94 3498.30 MinPt-CtCt 12306.511• - 1.: 11964.99 54.25 14540.69 3498.25 MinPt-O-EOU • 12306.53 12078.4.=UM 54.25 14541.28 3498.23 MinPt-O-ADP 12364.77 12116.51 11993.18 50.12 15459.05 3495.28 TD 1 11880.851 11630.53 11515.86 51.71 14124.58 3508.32 MinPt-CtCI 11880.85 11630.52 11515.85 51.71 14126.20 3508.29 MinPt-0-EOU 11860.86 11630.52 11515.851 51.71 14127.82 3508.26 MInPt-O-ADP 11897.55 11666.07 11550 821 51.6114 14289.36 3504.68 MinPt-O-SF 11902.75 11671.15 11555.861 51611 14300.62 3504.41 MinPt-O-SF 11999.32 11765.72 11649621 51671 14450.34 3500.66 MinPt-0SF 12354.71 12106.55 11983 28 50 101 15453.37 3495.36 MinPt-OSF 5119-FN2(P2)(Def Plan) Pap 17874.70 17871.0 17841.8 4956,04 334.26 334.26 MinPts 17874.70 17871.0 17841.89 4946.00 336.67 336.67 MinPt-O-EOU 17874.40 17873.17 17841.59 14602.76 0.00 0.00 Surface Drilling Office 2.0.960.0 Nikaitchuq\Oliktok Point\0124-08\0124-08\0124-08(P8) 9/13/2011 1:24 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 17874 4 17871.84 17841.59 6996.29 198,80 198.80 MinPts 17874.65 17871.60 17841.84 5867.95 248.80 248.80 MinPt-0-EO1J 1 12252.20 12022.39 11908.22 53.65 14583.49 3497.07 MInPt•CtCI 12252.28 12022.32 11908.08 53.62 14587.78 3496.95 MInPt-0-EOU 12252.35 12022.33 11908.07 53.61 14589.39 3498.91 MinPt-O-ADP 12467.27 12191.38 1205420 45.441 16856.31 3479.60 MinPt-0-SF SI07-SE4(P2)(Def Plan) Pass 17865.26 17861.67 1783246 4968.1 300.59 300.59 MinPt-0-SF 17864.31 17860.6 17831.50 4925.51 337.12 337.12 MinPts 17864.31 17860.68 1783150 4916.73 339.56 339.56 MinPt-O-EOU 17863.99 17862.76 17831.18 14594.26 0.00 0.00 Surface IllarIM 17861. MIME 6987.54 198.80 198.80 MinPts 17864.1'mum 17831.38 6023.36 238.80 238.80 MinPt-0-EOU jj 15197.94 15097.90 76.96 7916.36 3475.49 MinPt-CtCt 15400.3• 15196.61 15095.25_ 75.96 7944.85 3479.30 MinPt-0-EOU 15401.88 15196.9 15094.9 75.51 7958.36 3481.07 MinPt-0-ADP 15305.33 15080.45 14968.5.M•-rte, 10170.87 3516.80 MinPt-O-SF 15218.67 14995.14 14883.86 M.1 10603.20 3505.85 MinPt-O-SF 12453.16 12227.53 12115.24 55.44 14468.69 3500.18 MinPt-CtCt 12453.18 12227.51 12115.20 55.44 14469.14 3500.16 MinPt-O-EOU 12453.21 12227.52 12115.20 55.43 14469.37 3500.16 MinPt-O-ADP 12481.04 12254.14 1214125 55.27 14488.63 3499.85 MinPt-O-SF 13048.90 12814.67 12698.21 56.0 14787.50 3491.39 MinPt-0SF 13491.94 13253.38 13134.64 56.81 15026.93 3492.48 TD 14254.7 14025.86 13911.88 62.53 14128.94 3508.23 MinPt-CtCt 14254.8 14025. 13911.87 62.53 14131.01 3508.19 MinPt-0-EOU 14254.80 14025. 13911.87 62.53 14131.71 3508.18 MinPt-0-ADP I 13494.51 13256.0 13137.30 56.8211 15026.92 3492.48 MinPts SP04-SE5(P2)(Def Plan) Pap 1l 17861.21 17857.64 17828.481 4958.58 300.59 300.59 MinPts 17861.29 17860.07 17828.48 14592.05 0.00 0.00 Surface L.16611.92 16411 74 16312.14 . 83.39 7931.32 3477.51 MInPt-ClCI 16613.27, 16410.34 16309.37 82.26 7958.79 3481.12 MinPt-O-EOU 16614.97 16410.6 16309.01 81.71 7972.54 3482.89 MinPI-O-ADP 16535.76 16309.81 16197.3 73. 10175.29 3516.68 MinPt-0SF 16453.84 1622927 16117. 73.5 10596.40 3505.94 MinPt-0SF j 12459.41 12233.86 12121.60 55.49 14458.58 3500.44 MinPt-CtCt 12459.42 12233.85 12121.58 55.48 14458.71 3500.44 MinPt-0-EOU 12459.44 12233.88 12121. 55.48 14458.85 3500.43 MinPt-0-ADP 12481.95 12255.49 12142.7 55.38$ 14468.99 3500.17 MinPt-0SF 14019.34 13785.86 13669.61 60.30 14779.82 3491.57 TD 15948.23 15715.80 15600.0 min 13481.06 3529.35 MinP1-0SF 15670.40 15442.13 15328.4' 13683.78 3519.23 MinPt-O-SF 15508.6 15280.35 15166.68 68.21 14113.80 3508.54 MinPt-CtCt 15508.6 15280.34 1516667 68.21 14115.73 3508.50 MinPt-O-EOU 15508.69 15280.34 15166.66 68.21 14116.38 3508.49 MinPt-O-ADP L14023.2. 13789.72 13673.47 60.31 14779.81 3491.57 MinPts SP01SE7(P2)(Def Plan) Pap 17859.351 17855.7, 17826.54 4957.1911 300.59 300.59 MinPts 17859.35 17858.12 17826.54 14590.47 0.00 0.00 Surface 19001.8 18803.94 18705.45 96.47 7926.10 3476.81 MinPt-CtCt 19003.5 18802. 18702.10 94.86 7954.40 3480.55 MinPt-0-EOU 19005.88 18802.62691 18701.69 94.08 7968.56 3482.38 MinPt-O-ADP 18439.33 18203.06 18085.42L 78.3 13197.66 3542.25 MinPt-O-SF 18572.72 18342.30 18227.591 80.9 12217.32 3536.86 MinPt-O-SF 18977.20 18744.99 18629.381 82.0 10173.93 3516.72 MinP1-0SF 1 12486.791 12261.64 12149.56 55.70 14450.35 3500.66 MinPts 12486.81 12261.64 12149.561 55.70 14450.38 3500.66 MinPt-0-ADP 12503.28 12277.49 12165.10 55.621 14452.30 3500.61 MinPt-0SF 16348.21 16118.22 16003.71 71.38 14577.42 3497.24 TD 18392.85 18154.95 1803644 77.63) 13480.78 3529.36 MinPt-O-SF 17919.04 17689.74 17575.581 78.481 13977.20 3511.10 MinPt-O-SF ISME 17650.26 17536.29 78.43 14121.27 3508.39 MinPt-CtCt 17879.1'warm.64 17536.29 78.43 14122.41 3508.37 MinPt-0-EOU 17879.19 17650. •En= 78.43 14122.98 3508.35 MinPt-O-ADP 17879.24 17650.29 17536.31® 14126.39 3508.29 MinPt-0SF 17913.94 17683.01 17568.03 MECO 14294.82 3504.55 MinPt-O-SF 17903.82 17673.7.MR= 78 13 14363.33 3502.88 MinPt-0-ADP 17903.8.MERE 17559.14 7811 14365.02 3502.84 MinPt-0-EOU IMEMI 17673.71 17559.16 78.14 14367.29 3502.78 MinPt•CtCt MEM= 16122.88' 16008.37 MI= 14577.42 3497.24 MinPts 8102-6E6(P2)(Det Plan) Pee 17861.25 17857.65 17828.4 4957.36 300.59 300.59 MinPt-0-SF 17860.3 '17856.7 17827.52 4918.40 337.31 337.31 MinPts 17860.3 17856.7 17827.53 4910.05 339.75 339.75 MinPt-0-EOU 17860.01 17858.78 17827.20 14591.01 0.00 0.00 Surface 07860.01 17857.' 1111153111Z 6984.13 198.80 198.80 MinPts 17860.21 MIME17827.40 6011.66 238.80 238.80 MinPt-0-EOU MEM M 17602.32 17502.85 89.48 7925.06 3476.67 MinPt-CtCt 17803.8. 17600 821 17499.83 88.13 7952.95 3480.36 MinPt-0-EOU 17805.73 17601. • 17499.46 87.48 7966.90 3482.17 MinPt-O-ADP 17209.33 16974.97 16858.28® 13198.72 3542.23 MinPt-O-SF 17755.04 17524.81 17410.1• /1/0 10170.76 3516.80 MinPt-0SF 1 12501.461 12276.47 12164.47 55.80 14453.26 3500.58 MinPt-CtCt 12501.47 12276.46 12164.45 55.80 14453.32 3500.58 MinPt-0-EOU 12501.49 12276.47 12164.451 55.80 14453.39 3500.58 MinPt-0-ADP Drilling Office 2.0.960.0 Nikaitchuq\Oliktok Point\0124-08\0124-08\0124-08(P8) 9/13/2011 1:24 PM Page 10 of 13 1' Offset Trajectory Separation Allow Sep. Reference Trajectory Separation Factor Alert Status Ct-Ct(ft)I EOU(ft) Des.(ft) Fact. MD(ft) I TW(ft) Alert I Minor I Major 12521.93 12296.13 12183.74 55.70 14457.83 3500.46 MinPt-O-SF 15269.53 15038.29 14923.16 66.31 14659.65 3494.93 TD 17161.62 16925.62 16808.1.®i 13481.12 3529.35 MInPt-O-SF 16741.65 16513.23 16399.51 MEM 13821.33 3514.04 MInPt-O-SF 1 16675.681 16446.25 16332.02 72 99 14122.90 3508.36 MinPt-CtCt 16675.6 16448.2 16446.241 16332.02 72.99 14124.11 3508.33 MinPt-O-EOU 16675.69 16446.2'17 16332.01 72.99 14124.71 3508.32 MinPt-0-ADP 16722.96 16491.16 16375.76 72.45 14318.86 3503.97 MinPt-O-SF 16718.79 16487. 16372 41 72 60 14362.17 3502.91 MinPt-O-ADP 16718.76 16487.54 16372 42 7261 14363.97 3502.86 MinPt-O-EOU I 16718 7411 16487.56 16372.45 72.62 14366.98 3502.79 MinPt-CtCt 15273.9211 15042 681 14927.5511 66.33i1 14659.65 3494.93 MinPts SP12-SE3(P2)(Def Plan) Pass 17868.71 17864.13 17835 901 4552 691 300.59 300.59 MinPt-O-SF 17867.86 17864.23 17835.05 4933.42 336.97 336.97 MinPts 17867.86 178642 17835.05 4923.81 339.39 339.39 MinPt-O-EOU 17867.54 17866.32 17834.73 14597.16 0.00 0.00 Surface .123112 17864.9• 6990.49 198.80 198.80 MinPts 17867.78 17864.7 17834.97 5939.30 243.80 243.80 MInPt-O-EOU 14196.77 13993.96 13893.05 70.34 7919.51 3475.92 MinPt-CtCt 14197.96. 13890.67 69.52 7947.53 3479.66 MinP1-0-EOU 14199.44 13993.0: 13890.3' 6913 7961.56 3481.48 MinPt.O-ADP 14078.56 13855.49 13744.• MM 10169.27 3516.84 MinPt-OSF 13992.23 13770.44 13660..'MIMI 10601.06 3505.88 MinPt-OSF 12169.74 12056.95 54.95 14490.40 3499.60 MInPt-CtCt 12396.48 12169.70 12056.88 54.93 14491.52 3499.57 MinPt-O-EOU 12396.51 12169.711111 54.93 14491.90 3499.56 MinPt-O-ADP 12430.38 12201.91 12088. r MIZEZ 14531.32 3498.50 MinPt-OSF • 12434.26 12205.71 12092..r MZ1115E 14534.05 3498.43 MInPt-OSF 12766.82 12525.48 12405.53® 15141.06 3493.75 MinPt-O-SF 12815.20 12573.45 12453.28 53.31 15162.65 3493.99 TD 12829.22 12715.17 57.25 14126,87 3508.28 MinPt-CtCt • 13058.2•NE= 12715.17 57.24 14128.36 3508.24 MinPt.O-EOU ' 13058.31 12829. .MIME 57.24 14129.85 3508.21 MinPt-O-ADP 13089.61 12858.01 12742.70 Men 14508.21 3499.13 MinPt-O-SF 13087.85 12856.27 12740.9" 0 14519.37 3498.83 MinPt-OSF MEE MEM MIZEIER® 15162.65 3493.99 MinPts SP16-FN3(P2)(Def Plan) Pass 17872 67 17869 10 17839 86 5011.75 300.58 300,58 MinPt-OSF L 17871.9 17868.2 17839.0 495024 334.38 334.38 MinPts • 17871. 17868.2 17839.09 4940.70 336.79 336.79 MinPt.O-EOU 1787159 17870.37 17838.78 14600.47 0.00 0.00 Surface • 111 17871.59 17869. 17838.7 6993.93 198.80 198.80 MinPts 17671 81 17868.81 17839.00 5953.68 243.80 243.80 MinPt-0-EOU • 1 12320.47 12092.72 11979.47 54.39 14522.01 3498.75 MinPt-CtCt 12320.50 12092.691 11979.42 54.38 14523.45 3498.72 MinPt-O-EOU 12320.52 12092.69 11979.41 54.37 14523.93 3498.70 MinPt-O-ADP 12885.64 12609.84 12472.63 46.951 16856.31 3479.60 MinPt-OSF 5120-N4(P4)(Def Plan) Pass pj1112 :®r. MIMI 5402.29 300.58 300.58 MinPts 17875.21 17873.98 17842.40 14603.43 0.00 0.00 Surface I 11753.14 11525.66 11412.54 51.94 14397.48 3502.02 MinPts 11753.15 11525.67 11412.54 51.94 14397.50 3502.02 MinPt-O-ADP 11753.66 11528.16 11413.03 51.94 14397.65 3502.01 MinPt-O-SF 11785.86 11558.24 11445.05 52.05 14401.14 3501.92 MinPt-O-SF 12963.13 12689.01 12552.45 47.46 16856.31 3479.60 MinPt-O-SF S113-FN4(P2)(Def Plan) Pass 17870.55 17866.98 17837.7 5001.92 300.59 300.59 MinPt-OSF I 17869.74 17866.121 17836.9 4936.96 336.88 338.88 MinPts 17869.43 17868.21 17836.62 14598.70 0.00 0.00 Surface 17869.43 17866.8 17836.6 8992.14 198.80 198.80 MinPts 17869.66 17866.6 17836.85 5946.28 243.80 243.80 MinPt-O-EOU I 12355.84 12128.65 12015.65 54.67 14505,17 3499.21 MinPt.CtCt 12355.86 12128.62 12015.60 54.66 14506.41 3499.17 MinPt.O-EOU 1 12355.88 12128.62 12015.59 54.65 14506.83 3499.16 MinPt.O-ADP 12455.27 1222428 1210954 54.27 1461248 349626 MinPt-0SF 13287.94 13012.25 12875.00 4840 16856.31 347960 MinPt-0SF SP10-FN5(P2)(Def Plan) Pass 17867.29 17863.71 17834 49 4982.76 300.59 300.59 MinPt-0SF 17866. 17862.7 17833.59 4930.26 337.03 337.03 MinPts 17866. 17862.7 1783360 4920.98 339.46 339.46 MinPt-O-EOU 17866.08 17864.86 17833.27 14595.97 0.00 0.00 Surface 17866.0: 17863.5 6989.29 198.80 198.80 MinPts 17866.28 MEM 17833.47 6033.84 238.80 238.80 MinPt-O-EOU MIMI 12185.30 12072.63 55.07 14482.14 3499.82 MinPt-CtCt 12411.79 NEERM 12072.59 55 06 14482.75 3499.80 MinPt.O-EOU 12411.81 12185.291111=._ 55 06 14483.06 3499.80 MinPt-O-ADP 12446.22 12218.23 12104.:. 54.88 14515.81 3498.92 MinPt-O-SF 13852.13 13576.72 13439.50® 16856,31 3479.60 MinPt-O-SF SP18-N5(P3)(Def Plan) Pass 17871.73 17868.43 17838.92 5405.47 300.58 300.58 MinPts 11741.56 11514.98) 1140223 52.07 14349.64 3503.22 MinPts 11741.61 11515.02 11402.27 52061 14350.16 3503.21 MinPt-O-SF 17873.04 17871.81 17840.23 14601.65 0.00 0.00 Surface 14218.52 13938.00 13798.23 50.86 16856.31 3479.60 MinPt-O-SF Drilling Office 2.0.960.0 Nikaitchuq\Oliktok Point\0124-08\0124-08\0124-08(P8) 9/13/2011 1:24 PM Page 11 of 13 Offset Trajectory Separation Allow Sep. Reference Trajectory Separation Factor Alert Status Ct-Ct(ft)I EOU(ft) Dev.(ft) Fact. MD(ft) I TVD(ft) Alert I Minor 1 Major S108-FN6(P2)(Def Plan) Pass 17864.64 17861.0 17831.83 4960.921 300.58 300.58 MinPts 17864.64 17863.42 17831.83 14594.79 0.00 0.00 Surface I 12412.19 12185.91 12073.32 55.11 14473.27 3500.05 MinPt-CtCt 12412.2'^'11 12185.91 12073.30 55.11 14473.52 3500.05 MinPt-0-EOU 12412.22 12185.91 12073.29 55.10 14473.77 3500.04 MinPt-O-ADP 12443.32 12215.79 12102.61 54.9 14498.71 3499.38 MinPt-O-SF 14397.75 14121.91 13984 48 52 38 16856.31 3479.60 MinPt-O-SF SP05-F N7(P2)(Def Plan) Pass 17863.22 17859.62 17830 41 4962.15 300.59 300.59 MinPt-O-SF 17862 25 17858.62 17829.4 4922.35 337.21 337.21 MinPts 17862 25 17858 62 17829.44 4913.73 339.66 339.86 MinPt-O-EOU 17861.92 17860.70 17829.12 14592.57 0.00 0.00 Surface 17861.9 17859.3 .®' 6985.80 198.80 198.80 MinPts 17862.1 MUM 17829.32 6018.50 238.80 238.80 MinPt-O-EOU 12241.56 12129.28 55.51 14463.92 3500.30 MinPt-CtCt 12467.16 12129.24 55.51 14464.30 3500.29 MinPt-O-EOU 12467.19 12241.55 55.50 14464.49 3500.29 MinPt-O-ADP 12493.99 12267.21 12154.37,89 14480.65 3499.86 MinPt-O-SF 13237.38 13003.52 12887.22 56.90 14770.04 3491.83 MinPt-O-SF 14236.39 13981.03 13853.8•,1' 15885.64 3488.71 MinPt-O-SF 15109.71 14834.04 14696.69 16856.31 3479.60 MinPt-O-SF Nikeitchuq 3P81(Def Survey) Pass IIIIMEE 18563.37�1 9445.30 51.00 51.00 MinPts 18566.13 18562.39 18533.32 4964.18 250.80 250.80 MinPt-O-EOU 88566.36 18561.62 IMMIE 3911.70 411.24 411.23 MinPts 18566.37 18561.6. 18533.56 3905.38 413.57 413.55 MinPt-O-EOU .®i 18271.74 18250.98 440.99 3223.92 2417.59 MinPt-CtCt 18315.17=H1r' 18250.82 439.32 3233.55 2419.83 MinPt-O-EOU 18315.27 18271.6: 182 OS 80 438.49 3238.35 2420.95 MinPt-O-ADP 18936.35 18875 19 18845.,:MEE, 4357.19 2681.16 MinPt-O-SF 18762.81 18639.81 18579.19 154.75 7837.35 3431.88 MinPt-CtCt 18762.81 18639 81 18579.18 154.74 7637.56 3431.91 MinPts 18781.19 18657.86 18597.01 154.47 7653.52 3434.71 MinPt-O-SF 1 17746.381 17540.35 17438.15 86.81 13603.54 3522.89 MinPts 17748.39 17540.35 17438.15 86.81 13603.56 3522.89 MinPt-O-ADP 17751.91 17545.75 17443.47 86.781 13605.61 3522.79 MinPt-O-SF 18068.56 17864.34 17763.03 89.17 13619.32 3522.14 TD 19689.57 19571.35 19513.1. 169.0 7645.40 3433.29 MinPt-OSF Nikaochuq 3PB2(Dei Survey) Pass mum' 18563.3 wpm 9445.30 51.00 51.00 MinPts 18566.1 SEM 18533.32 4964.18 250.80 250.80 MinPt-O-EOU 18566.361_18561.6. 3911.70 411.24 411.23 MinPts 18566.37 18561.6. 18533.56 3905.38 413.57 413.55 MinPt-0-EOU 18271.74 1825098 440.99 3223.92 2417.59 MinPt-CtCt 18315.1 1j 18250.82 439.32 3233.55 2419.83 MinPt-O-EOU 18315.27 18271.8.IIIIMIE. 438.49 3238.35 2420.95 MinPt-O-ADP 18936.35 18875.19 18845.481®1 4357.19 2681.16 MinPt-O-SF 18762.81 18639.81 18579.19 154.75 7637.35 3431.88 MinPt-CtCt 18782.81 18639,811 1857918 154.74 7637.56 3431.91 MinPts 18781.19 18657.86 18597.0 154.47i1 7653.52 3434.71 MinPt-O-SF 13 17746.381 17540.35 17438.15 86.81 13603.54 3522.89 MinPts 17746.39 17540.35 17438.15 86.81 13603.56 3522.89 MinPt-O-ADP 17751.91 17545.75 17443.47 86.781 13605.61 3522.79 MinPt-O-SF 18068.56 17864.34 17763.03 3 89.17 13619.32 3522.14 TD 19761.35 19642.35 19503.73r 168.541 7668.98 3437.38 MinPt-O-SF 19863.19 19743.56 19684.631 168.511 7897.20 3442.17 MinPt-O-SF Nikeitchuq 3PB3(Def Survey) Pass imam 18563.37' 9445.30 51.00 51.00 MinPts 18566.1 18533.32 4964.18 250.80 250.80 ErEnE IrrEarg maim 3911.70 411.24 411.23 MinPts 18568.3 18561.6. 18533.56 3905.38 413.57 413.55 MinPt-O-EOU 18271.74 18250.98 440.99 3223.92 2417.59 MinPt-CtCt 18315.1 18271.66 18250 82 439.32 3233.55 2419.83 MinPt-O-EOU 18315.27 18271.6: 18250 80 438.49 3238.35 2420.95 MinPt-O-ADP 18859.07 18799.25 18770.22=Ellt 4263.17 2659.30 MinPt-O-SF 18762.81 18639.81 18579.19 154.75 7637.35 3431.88 MinPt-CtCt 18762.81 18639.811 18579.1 154.74 7637.56 3431.91 MinPts 18781.19 18657.86 18597.04 154.471 7653.52 3434.71 MinPt-O-SF 1 17746.381 17540.35 17438.15 86.81 13603.54 3522.89 MinPts 17746.39 17540.35 17438.15 86.81 13603.56 3522.89 MinPt-O-ADP 17751.91 17545.75 17443.47 86.781 13605.61 3522.79 MinPt-O-SF 18068.56 1786434 17763.03 89.17 13619.32 3522.14 TD 19876.92 19758.10 19699.581.-:y:1 7648.66 3433.86 MinPt-O-SF Nikaitchuq 3(Def Survey) Pass 88 18563.37 MEMO 9445.30 51.00 51.00 MinPts 18566.13 18562.39 18533.32 4964.18 250.80 250.80 MinPt-O-EOU 8566.36 1856 62 MIME 3911.70 411.24 411.23 MinPts 18566.37 18561.62 18533.56 3905.38 413.57 413.55 MinPt-O-EOU Mr= 18271 74 18250.98 440.99 3223.92 2417.59 MinPt-CtCt 1831517 18271.66 18250.82 439.32 3233.55 2419.83 MinPt-O-EOU 18315 27 18271 688250 80 438.49 3238.35 2420.95 MinPt-O-ADP 18859.07 18799.25 18770.22 MOE 4263.17 2659.30 MinPt-O-SF 11 18762.81 18639 81 18579 19 154.75 7637.35 3431.88 MinPt-CtCt 18762.81 18639.81 '-13571.211154.74 7637.56 3431.91 MinPts Drilling Office 2.0.960.0 Nikaitchuq\Oliktok Point\0124-08\0124-08\0124-08(P8) 9/13/2011 1:24 PM Page 12 of 13 Offset Trajectory Separation Allow Sep. Reference Trajectory Separation Factor Alert Status Ct-Ct(ft)I EOU(ft) Dev.(ft) Fact. MD(ft) I TVD(ft) Alert I Minor I Major 18781.19 18657.86 18597.08 154.47 7653.52 3434.71 MinP1-0SF I 17746.38 17540.35 17438.15 86.81 13603.54 3522.89 MinPts 17748.39 17540.35 17438.15 86.81 13603.56 3522.89 MinPt-O-ADP 17751.91 17545.75 17443.47 86.781 13605.61 3522.79 MinPt-O-SF 18068.56 17864.34 17763.03 89.17 13619.32 3522.14 TD 19582.90' 19532.2 19507.83 400.70 3105.10 2389.81 MinPt-O-ADP 19582.8. 19507.85 401.20 3106.44 2390.14 MinPt-O-EOU MIME 19532.33 19508.00 402.47 3109.79 2390.95 MinPt-CtCt Emma 19526.04 19501.70 402.01 3268.17 2427.89 MinPt-CtCt 19576.5 19526.0. 19501.6. 401.47 3277.86 2430.14 MinPts 19876.92 19758.10 19699. 169.8. 7648.66 3433.86 MinPt-O-SF 20769.25 20638.23 20573.6. 160.66 7991.80 3485.31 MinPt-O-SF Nikeitchuq 4PB1(Oaf Survey) Pass L 18606.46 18604. .NEEREn 9466.62 51.00 51.00 MinPts 18607.01 18604.16 18574.20 6526.30 165.92 165.92 MinPt-O-EOU E 18608.18' 18603.37'. 3873.15 434.84 434.80 MinPts 18608.20 18603.36 18575.39 3843.69 442.27 442.22 MinPt-O-EOU 18357.48 18316.79 18297.36 472.38 3058.54 2377.74 MinPt-CtCt 18357.49 18316.78 18297.34 472.07 3060.06 2378.15 MinPt-O-EOU 18357.51 18316.78®'. 471.92 3060.80 2378.35 MinPt-O-ADP 18889.4 18766.19 18705.46 155.49 7679.66 3439.21 MinPt-CtCt 18889.4 18766.191 18705.46 155.49 7679.74 3439.22 MinPts 18901.08 18777.65 18716.82 155.31 7689.28 3440.84 MinPt-O-SF I 17966.22 17761.30 17659.64 88.36 13576.09 3524.25 MinPt-CtCt 17966.22 17761.301 17659.64 88.36 13576.13 3524.25 MinPts 17969.15 17764.16 17662.47 88.35 13577.98 3524.15 MinPt-O-SF 17969.58 17764.58 17662.8 88. 13578.17 3524.15 MinPt-O-SF 18246.49 18043.05 17942.13 90.40 13599.77 3523.08 TD Nikeitchuq 1(Def Survey) Pees 18446.58 18408.15 18389.82 503.25 2932.12 2338.70 MinPl-CtCt 18446.60 18408 14 18389 81 503.05 2932.91 2338.98 MinPts 19048.86 18925 46 18864.64 156.5 7696.70 3442.09 MinPt-O-SF 19045.09 18921.74 18860.95 156.62 7701.21 3442.85 MinPts 18074.22 17868.93 17767.09 88.73 13613.03 3522.44 MinPt-CtCt 18074.23 17888.921 17767.07 88.72 13613.16 3522.43 MinPts 18153.34 17946.61 17844.06 88.50 13630.37 3521.62 MinPt-O-SF 20492.01 20275.43 20167. 95. 13938.04 3511.78 MinPt-O-SF 22561.86 22346.42 22239.50 105.51 14080.96 3509.19 TD Nlkaltchuq 4(Def Survey) Pass O 18604.50i�J 946662 51.00 51.00 MinPts 18607.01 18604.16 18574.20 6526.30 165.92 165.92 MinPt-O-EOU ME658!E 3873.15 434.84 434.80 MinPts 18808. • 18603.36 18575.39 3843.69 442.27 442.22 MinPt-O-EOU LIME 18316.79 18297.36 472.38 3058.54 2377.74 MinPt-CtCt 18357.4,EMU 18297.34 47207 3060.06 2378.15 MinPt-O-EOU 18357.51 18316.7,MIIMEE 471.92 3060.80 2378.35 MinPt-O-ADP 19196.01 19071.65 19010.3 ',® 7530.86 3412.34 MinPt-O-SF 19113.27 18889.41 18928.36® 7562.56 3418.32 MinPt-O-SF r 18890.6 MEI38BEE.. 18706.60 155.44 7681.50 3439.52 MinPts 18801.08 18777.65 18716.82,® 7689.28 3440.84 MinPt-O-SF 17969.15 17764.16 17662.47® 13577.98 3524.15 MinPt-O-SF 17969.58 17764.58 17662.89' 111 4, 13578.17 3524.15 MinPt-O-SF 1111723E1 88.32 13578.09 3524.15 MinPts 17691,54 17586.84 85.49 13702.44 3518.44 MinPt-CtCt 17902.64 17691.46 17586.67 85.42 13705.79 3518.30 MinPt-O-EOU 17902,75 17691,48 17586.68 85.38 13707.46 351823 MinPt-O-ADP 18836,40 18607.43 18493.75 82.84 14112.93 3508.56 MinPt-O-SF Nikeitchuq 2(Def Survey) Pass 3830.02 •. 23637.80® 9080.20 3552.72 MinPts MIN ® 188.02 9091.17 3552.68 MinPts 24598 75 24464.26 24397.83 IMIIM 9379.79 3550.88 MinPt-O-SF 19178.76 19174.61=IMO 4621.77 344.47 344.47 MinPts 19178.79 ECIMIZI 19145.98 4555.49 360.69 360.69 MinPt-O-EOU 19180.83 19176.28 19148 19148.03!MEEE. 448.74 448.69 MinPt-O-SF 20298.77 20276.27 20265 96 1279.44 1231.41 MinPt-O-SF 23996.39` . 23810.46 195.27 8700.43 3547.92 MinPts LIFE=LuIIRKEZ191.64 8788.64 3550.10 MinPts 23991.26 23862.06 237982 188.0 9091.34 3552.88 MinPt-O-SF �.,!,r 191.64 8788.68 3550.10 MinPts EMER MEM 19213 8772.55 3549.89 MinPts 23992.97 23863 77 23799.97 tut •T 9091.46 3552.68 MinPt-O-SF ErEffizE 23442.36' 190.14 8878.27 3551.04 MinPts 3. .,.moi Mg= 195.31 8699.68 3547.89 MinPts 26133.28 25987.41 2591528 ma= 10172.06 3516.76 MinPt-0-SF 26181.86 26035.79 25963.56 181.23 10193.33 3516.21 TD [ 23833 17123708 7911 23647 4111 194 1311 8724.61 3548.77 MinPts Drilling Office 2.0.960.0 Nikaitchuq\Oliktok Point\0124-08\0124-08\0124-08(P8) 9/13/2011 1:24 PM Page 13 of 13 Schlumberger TRAVELING CYLINDER PLOT Client: ENI NoGo Region EOU's based on: Well: 0124-08 Oriented EOU Dimension .7V Field: Nikaitchug Structure: Oliktok Point NoGo Region Anti-Collision rule A Date: September 13,2011 used:Minor Risk-Separation Factor �44 North 350 0 10 340fp( 20 330 0 30 320 140111111140 310 ,9,,,,• 50 ,. ia 300 411004.71 • �;�' ��%� ',I, 1, a nk,•9„ itir .�,�� ,.' ,,,, ��,�. ►. as .P16-03 290 •• • • ��\�l4,,,,,...,,,,\;.4,,,,,,,„..„ 0'�.f gill ,�1•Pit.'14 . , k�/.• 70 vr.,. . 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VM ilr$ .1' ,i' MAY 250 ♦ ♦111111111111110 , c„, 110-,46,41.1%ar0 "9- 10 At111110 I 1 cl 240 ■� i. v :: .�-. 4 0120-07(P12) 230 , • 1 iiii�- 30 220 ♦41111111110. -- 0 °140 210 1111 150 200 160 190 180 170 Well Ticks Type: MD on 0124-08(P8) 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: 0124-08 Oriented EOU Dimension - Field: Nikait chug Structure: Oliktok Point NoGo Region Anti-Collision rule Aili 111'' Date: September 13,2011 -- - used:Minor Risk-Separation -1111741/111 Factor 4 1 North i 0 350 10 11 330 340 gig( Di,Onto .,--ripiakir,S2... 20 ,e, 111,..-‘,•.,„,_ . liz Aii..• i ‘15,A.,,,..-0--pimakk t ,,, -033(p6) 1*I-''-----•','.I 4,1? ,4,,fiii Allilio. Milt 9;, Oltt 0... lliOt•iik4) 40 320 "opie , •-- — ,. 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Aip•4, -rip* Plf 11,41kb, cn (-4 c n..."' 240 , ,,, 0 I& 1,4,0.',WS&•4' , walk ' • W& 'i •-'"'-•=--..1P4, la _Ar • i,‘,,,,,:ar:.t.-ivi ....t'sw ....0".,....---- ,...k.41 1.4,'•• 0,, •':•_ ---m,' Nil OP17-02PB1 .k.... 130 OP22-VVVV01 (P2) qNliall 141 • 4..11 219////4110 yAii k ..-.....- „.,.0 s-........ li,•- 200 W-07 TP12) 190 170 Well Ticks Type: MD on 0124-08(P8) Calculation Method: Normal Plane Ring Interval: 20.00 ft Azimuth Interval: 10.0 deg Scale: 1 INCH= 100.00 ft Schlumberger •TRAVELING CYLINDER PLOT Client: EM NoGo Region EOU's based on: Well: 0124-08 Oriented EOU Dimension N Field: Nikaitchuq Structure: Oliktok Point NoGo Region Anti-Collision rule Date: September 13,2011 used:Minor Risk-Separation Factor 1 North 350 0 10 330 !"4:r1'I ,4• .i ‘`•Fj ' ,``, 30 7P 320 ,1• ••1, % -,'.: #„4.111•1.0/x/ ,1/,.4`•-7%a0 • 4,arl4i4,,\,1„ it ..7Ii1.•4..i'v"1" 40 i..-0,_.i.-4i.111.,1.41:1-,.'.,+.-..-.'-_ 310 t1� P4��..� ��'\.,f.;s.. , 4 to4- ,4,1)0 - -$6-02PB1 Vh 11-,.,10., v1�<j:.. �N1r/ 270 I,4 ��" t 300 \`► * , . 60 . `141l, 240 ; �lle. •�4 ,,' ,../.!,� — 210.. t �;;,`4`i �1 290 es0 , .i� 180 r 0:2A. 70 tee�.�� 150 r . \1i►��!41,110• „,i40�# AVV •Vi 120 • ``lon�%*-rflA�—s�j#i/i 280 �,0 / _ t 4' i 90 # ♦• � ,.. #'*, 80 ,� rii0lam' '.,,,,01!".41•ROKE2gist*, - ,_ -,40ligisimei \., •,.. ..___• .1, 270 I ,4r.. .. \\ Off" .11111111111111111; ■■11� :7'. 1%...r• _r 260 +`, �- AVM \ O Oyv �b” •� ,-.4,1.7„; -s _'. 100 I 250 !�i//.q� ,47% ♦,e 1•1,04*****:•'''‘N.\� .1��,•0. O 44 el } / 1 /1 / A'o `•• r • _,'OP17-02P61 240 , 1 / II,A.,''� I, W,,,f. j,�,,. , �:i •� O c :120 ��. 4 >' #01 I /op�''I'�ti��/i�ess,'0.,',.01 S y etai!, `�\��'' \ o� X11 �i ,i. ,, ip .�-i 1111 -' . � ,F,IJdli1I11 f li.1 I -,1'4'1 1110,''",`,W1 11 ,',`, 1,i' 4 •,/I� too, .�' 1X,210.1' I'll '.ii :�A.iiipIII ii Incl. . � 2300, .. r 1 i,4 'I 11I 11',.I� ,, !!'11.1i�I ',i 'f I 130 .1:4vhA,4itivAV�•rl+a'.' ,llil;n-;/,'...fJ 'r �-.� ;;.;1130,/,',,,j//// ,, ,1 40th,,',/I,/i,,,.;v�j,1vi,1..fai4, ,',, 220 4`''', v, V:1•S...7;*,/!/4,q;-:; •.1,4".,..i•:."..!i�i!..:,?,.�. ,.. 140 210 �,. • - "-•,•0j 150 200 ' —� -• ------- '•••' h. 160 190 0I?,10-07(P12)170 Well Ticks Type: MD on 0124-08(P8) Calculation Method: Normal Plane Ring Interval: 20.00 ft Azimuth Interval: 10.0 deg Scale: 1 INCH=150.00 ft Schlumberger TRAVELING CYLINDER PLOT • Client: ENI NoGo Region EOU's based on: Well: 0I24-08 YV Oriented EOU Dimension Field: Nikaitchug Structure: Oliktok Point WI' NoGo Region Anti-Collision rule AAL Date: September 13,2011 used:Minor Risk-Separation Factor 4 North 350 0 10 340 -4151111\ itAr r 20 330 ; _.- =aillilli '// 30 320'/,\OP,��.,amIipaVll _' .*.N1/.*..:,''"oz.i:. /--'"' Oo j// k11464i0 : - /i ‘:-*., 310 �,��.. ,�,�PI ', i5,.., ,.-\ //o/300 A l.l, 300 . /_ q'ri�� \%\`-_pm 270 \60 •.�likirk` \\"IIV 240 pisl�\�\��. ��AI 210 ' ' 290 11�:\�\ ;_�```�� 1!/ 180 �' 70 • i � M1f+, �-*! � i 1 150 ��. \Ia, \`\�� ,,%y\ \ ! 1207 • 01n 20" ♦ ' ,� 280 "l \ ` 4>;N ``i,,,i ,i\ ` � '� 80 / /10, libk 9° I liglidglitwaiiis 27o1114:-*ti�`1060.-.14r#:‘110� :�` �` I��#�1�, o�if 'iii7P imilk , 260 /.•\_\7i ,k � 0 $ $ ` ' 100 t. , -..4Mpk, .. --\,.41‘10/0 sidii . ,'''6, ,‘,,., , / / , g 250INlkftik_ . ►%r %# '#. 1 I ai11111i0a . sco 0 ! 110 NikiNipikl,,,./SIL _.,,vvek S IA,0,i ...,1114k 0 �� `� .}�}Il�,� �,, o c 120 irk vt,00.}/,/1,x, ��/�,, . '.�'0 W'IY 047/; �� 23 \ %%ØØ%'/ r 130 220 .440••00 g/111k,44:$0 , Iii air '*140 • 210 '1' `��iniallM 150 200 �60 190 1Rn 170 Well Ticks Type: MD on 0I24-08(P8) it Calculation Method: Normal Plane Ring Interval: 20.00 ft Azimuth Interval: 10.0 deg Scale: 1 INCH=150.00 ft Scher 0124-08(P8)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 14,2011-08:47 North Reference: True Analysis Machine: DEC-AKA-980 Client ENI Database\Project: localhost\drilling-nikaitchuq Version I 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 8530.00 ft s=MD 0=18857.00 ft,Ct-Ct separation<-1320.00 ft Anti-Collision Rules Used Rule Set Name DSM AntiCollision Standard S002 v5.1 Exemption Risk Level: Minor Rule Name Risk Level Rule"Noe 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=49.21(ft) • Drilling Office 2.0.960.0 Nikaitchuq\Oliktok Point\0124-08\0124-08\0124-08(P8) 9/14/2011 9:02 AM Page 1 of 39 Reference Trajectory Summary Field: Nikaitchuq Well: 0124-08 Structure: Oliktok Point Borehole: 0124-08 Slot: OP24 Trajectory: 0124-08(P8) Client: ENI Type: Del Plan Coordinate System: NAD27 Alaska State Plane,Zone 04,US Feet North Reference: True Grid Convergence Angle: 0.12782172" Grid Scale Factor: 0.999900312 Magnetic Declination: 20.614' Magnetic Declination Date: April 02,2012 Magnetic Model: BGGM 2011 Reference Point: Northing Easting Elevation Structure Unc.(lsd) Slot Unc.11sdl 6036479.380(ftUS) 516569.840(ftUS) 52.200(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(ft) Survey Tool Type Hole Diameter(in) Borehole I Survey 0.000 40.000 1/100.000 SLB_GYRO-MWD^^3-Depth Only-No Global 16.000 0124-08/0124-08(P8) 40.000 800.000 1/100.000 SLB_GVRO-MWD^^3-No Global 16.000 0124-08/0124-08(P8) 800.000 2558.559 1/100.000 SLB_MWD+GMAG-No Global 16.000 0124-08/0124-08(P8) 2558.559 8530.262 1/100.000 SLB_MWD+GMAG-No Global 12.250 0124-08/0124-08(P8) 8530.262 16856.315 1/100.000 SLB_MWD+GMAG-No Global 8.750 0124-08/0124-08(P8) Drilling Office 2.0.960.0 Nikaitchuq\Oliktok Point\0124-08\0124-08\0124-08(P8) 9/14/2011 9:02 AM Page 2 of 39 Offset Trajectory Summary Offset Selection Criteria: Wellhead distance scan:Restricted within 57866.81 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 Summar( Wells Selected:22 Boreholes Selected:35 Definitive Surveys Selected:29 Non-Def Surveys Selected:1 Definitive Plans Selected:6 Non-Def Plans Selected:0 Total Trajectories:36 None OSF filter in detailed report TrajectoryBorehole Well Type OP23-W W 02 OP23-W W02 OP23-W W02 Def Survey OP22-W W 01(P2) OP22-W W01 OP22-W W01 Def Plan OP18-08PB1 OP18-08PB1 OP18-08 Def Survey 0120-07(P12) 0120-07 0120-07 Def Plan 0115-S4(P5) 0115-S4 0115-S4 Def Plan OP18-08 OP18-08 OP18-08 Def Survey OP18-S8PB2 OP18-08PB2 OP 18-08 Def Survey OP16-03 OP16-03 OP16-03 Def Survey OP17-02PB1 OP17-02PB1 OP17-02 Def Survey OP17-02 OP 17-02 OP17-02 Def Survey OP14-S3 OP14-S3 OP14-S3 Def Survey OP26-DSP02 OP26-DSPO2 OP26-DSPO2 Def Survey OP12-01 OP12-01 OP12-01 Def Survey 0107-04 0107-04 0107-04 Def Survey OP10-09 OP10-09 OP10-09 De(Survey Oliktok Point I-2PB1 Oliktok Point I-2PB1 Oliktok Point 1-2 Def Survey Oliktok Point 1-2 Oliktok Point 1-2 Oliktok Point 1-2 Def Survey Oliktok Point 1-2PB2 Oliktok Point 1-2PB2 Oliktok Point 1-2 Def Survey 0106-05 current 0106-05 0106-05 Non-Def Survey OP08-04 OP08-04 OP08-04 Def Survey OP08-04PB1 OP08-04PB1 OP08-04 Def Survey OP05-06 OP05-06 OP05-06 Def Survey OP05-06PB1 OP05-06PB1 OP05-06 Def Survey OP05-06PB2 OP05-06PB2 OP05-06 Def Survey 0106-05(P9c) 0106-05 0106-05 Def Plan OPO4-07 OPO4-07 OPO4-07 Def Survey OPO4-07PB1 OPO4-07PB1 OPO4-07 Def Survey OP03-P05PB1 OP03-P05PB1 OP03-P05 Def Survey OP03-P05 OP03-P05 OP03-P05 Def Survey OP03-P05PB2 OP03-P05PB2 OP03-P05 Def Survey 0111-01 0111-01 0111-01 Def Survey 0111-01PB1 OP11-01PB1 0111-01 Def Survey Oliktok Point 1-1A-106(P5) Oliktok Point I-1A-106 Oliktok Point I-1 Def Plan Oliktok Point 1-1 Oliktok Point I-1 Oliktok Point I-1 Def Survey OP09-S1 OP09-S1 OP09-S1 Def Survey 0113-03(P6) 0113-03 0113-03 Def Plan Drilling Office 2.0.960.0 Nikaitchuq\Oliktok Point\0124-08\0124-08\0124-08(P8) 9/14/2011 9:02 AM Page 3 of 39 Field: Nikaitchuq Well: OPI6-08 Structure: Olikfok Point Borehole: OP18-08 Slot: OP18 Trajectory: OP18-08 Client: ENI Type: Del Survey Coordinate System: NAD27 Alaska State Plane,Zone 04,US Feet North Reference: True Grid Convergence Angle: 0.12820300° Grid Scale Factor: 0.999900314 Magnetic Declination: 20.962° Magnetic Declination Date: August 20,2011 Magnetic Model: BGGM 2011 Reference Point: Northing Easting Elevation Structure Unc.(lsd) Slot Unc.11sdl 6036505 ff30(ftUS) 516619.200(ftUS) 53.740(ft)MSL 0.000(ft) 0.000(ft) Trajectory Error Model:ISCWSAO 3-D 95.000%Confidence 2.7955 sigma Surveying Praia: Description MD From(ft) MD To(ft) EOU Freq Survey Tool Type Hole Diameter(in) Borehole/Survey 0.000 41.540 Act-Stns SLB_NSG+MSHOT-Depth Only-No Global 16.000 OP18-08PB1/OP18-08PB1 41.540 917.000 Act-Stns SLB_NSG+MSHOT-No Global 16.000 OP18-08PB1/OP18-08PB1 917.000 2885.990 Act-Stns SLB_MWD+GMAG-No Global 16.000 OP18-08PB2/OP18-08PB2 2685.990 13005.730 Act-Stns SLB_MWD+GMAG-No Global 12.250 OP18-08PB2/OP18-08PB2 13005.730 15974.820 Act-Stns SLB_MWD+GMAG-No Global 8.750 OP18-08PB2/OP18-08PB2 15974.620 18858.000 Act-Stns SLB MWD+GMAG-No Global 8.750 OP18-08/OP18-08 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 8530.00 ft<=MD<=16857.00 ft Results filtered:Ct-Ct separation<=1320.00 ft Results highlighted:Ct-Ct separation<=1320.00 fl 14300 00 3504.43 6440.60 -10403.37 13640.11 3494.65 5304.00 -10975.48 212.16 1272.51 053.2 3.90' 4.88 1 14850 54 3490.70 6681.53 -10897.57 14091.42 3488.60 5473.75 -11303.31 203.87 1305.5 074.8 3.06 3.10 1 14882 47 3490.88 6694.41 -10926.78 14116.41 3487.35 5483.24 -11416.39 203.96 1308.39 075.2 3.95 4.08 1 16856 31 3479.60 7491.30 -12732.46 16461.12 3439.10 6672.48 -13410.54 205.821 1063.911 685. 2.8 15.84 1 End of results • • • • Drilling Office 2.0.960.0 Nikaitchuq\Oliktok Point\0124-08\0124-08\0124-08(P8) 9/14/2011 9:02 AM Page 9 of 39 Field: Nikaitchuq Well: OP18-08 Structure: Oliktok Point Borehole: OP18-08PB2 Slot: OP18 Trajectory: OPt 8-08PB2 Client: ENI Type: Be!Survey Coordinate System: NAD27 Alaska State Plane,Zone 04,US Feet North Reference: True Grid Convergence Angle: 0.12820300° Grid Scale Factor: 0.999900314 Magnetic Declination: 21.001° Magnetic Declination Date: July25,2011 Magnetic Model: BGGM 2011 Reference Point: Northing Eaeting Elevation Structure Unc.(lsdl Slot Uno.(1adl 6036505.630(flUS) 516619.200(SUS) 53.740(ft)MSL 0.000(ft) 0.000(fl) Trajectory Error Model:ISCWSAO 3-D 95.000%Confidence 2.7955 sigma Surveying Prog: Description MD From(ft) MD To(It) EOU Freq Survey Tool Type Hole Diameter(in) Borehole/Survey 0.000 41.540 Act-Stns SLB_NSG+MSHOT-Depth Only-No Global 16.000 OPl8-08P81/OP18-08PB1 41.540 917.000 Act-Stns SLBNSG+MSHOT-No Global 16.000 OP18-08PB1/OP18-08PB1 917.000 2685.990 Act-Stns SLB__MWD+GMAG-No Global 16.000 OP18-08PB2/OP18-08PB2 2685.990 13005.730 Act-Stns SLB_MWD+GMAG-No Global 12.250 OP18-08PB2/OP18-08PB2 13005.730 17197.000 Act-Stns SLB MWD+GMAG-No Global 8.750 OP18-08PB2/OP18-08PB2 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 8530.00 ft<=MD<-16857.00 ft Results filtered:Ct-Ct separation<=1320.00 ft Results highlighted:Ct-Ct separation<-1320.00 fl - 14300.00 3504.43 6440.60 -10403.37 13640.11 3494.65 5304.00 -10975.48 212.16 1272.51 952 24 3.99/ 4.88 1 14850.54 349070 6681.53 -10897.57 14091.42 3488.60 5473.75 -11393.31 203.87 1305.56' 974.91 3.96 3.10 1 14882.47 3490.88 6694.41 -10926.78 14116.41 3487.35 5483.24 -11416.39 203.96 1306.39 975.24 3.95 4.08 1 16410.49 3486.59 7311.28 -12324.65 16042.11 3428.87 6414.71 -13080.72 206.68 1174.2 808.16 3.21 16.44 1 16856.31 3479.60 7491.30 -12732.46 16476.85 3420.62 6715.60 -13393.66 207.001 1020.9 644.87 2.72 16.66 1 End of results t I Drilling Office 2.0.960.0 Nikaitchuq\Oliktok Point\0124-08\0124-08\0124-08(P8) 9/14/2011 9:02 AM Page 10 of 39 Field: Nikaitchuq Well: OP17-02 " Structure: Oliktok Point Borehole: OP17-02PB1 Slot: OP17 Trajectory: OP17-02PBt Client: ENI Type: Del Survey Coordinate System: NAD27 Alaska State Plane,Zone 04,US Feet North Reference: True Grid Convergence Angle: 0.12825768° Grid Scale Factor: 0.999900314 Magnetic Declination: 21.398° Magnetic Declination Date: November 01,2010 Magnetic Model: BGGM 2010 Reference Point: Northing Eastjn9 Elevation Structure Unc.(lsd) Slot Unc.11adl 6036509.370(ftUS) 516626.280(ftUS) 53.250(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 41.050 Act-Stns SLB_GYRO-MWD-Depth Only-No Global 16.000 OP17-02PB1/OP17-02PB1 41050 1116.470 Ant-Stns SLB_GYRO-MWD-No Global 16.000 OP17-02PB1/OP17-02PB1 1116.470 2182.500 Act-Stns SLB_MWD+GMAG-No Global 16.000 OP17-02PB1/OPt7-02P81 2182.500 8441.650 Act-Stns SLB_MWD+GMAG-No Global 12.250 OP17-02PB1/OP17-02PB1 8441.650 18940.000 Act-Stns SLB MWD+GMAG-No Global 8.500 OP17-02PB1/OP17-02PB1 Reference Cylinder North EOU-EOU Intersection MD Reference TVD Reference NS Reference EW Offset MD Offset ND Offset NS Offset EW Azim Ct-Ct Distance Clearance OSFAngle Trace# (8) (fl) (fl) (fl) lfl) (ft) (ft) (ft) (°) (ft) (9) ( All local minima indicated. Results filtered:Depth 8530.00 ft<=MD<=16857.00 6 Results filtered:Cl-Ct separation<=1320.00 ft Results highlighted:Ct-Ct separation<=1320.00 8 9493.65 3550.17 2973.20 -7090.78 9653.30 3549.08 3613.81 -6384.30 47.64 953.5 770.31 5.23 1.60 1 5500.00 3550.12 2977.89 -7095.05 9658.72 3548.90 3617.62 -6387.93 4761 953.5 770.2E1 5.22 1.50 1 10082.98 3520.44 340547 -7490.18 10258.18 3539.33 4048.41 -6804.33 48.38 940.2 742.2'41 4.771 5.39 1 10100.00 3519.53 3417.94 -7501.70 10269.24 3539.74 4056.50 -6811.87 48.48' 940.2 742.37 4.77 5.01 1 i 10400.00 3510.85 3638.56 -7704.79 10514.96 3543.79 4242.92 -6971.82 49.29 950.57 751.2:112IINE 3.50 1 10600.00 3505.89 3785.70 -7840.17 10702.17 3548.36 4389.18 -7088.58 49.85 964.81 762.41 4.69 1 11174.17 3511.77 4207.96 -8229.17 11301.51 3535.55 4865.72 -7450.88 48.78 1019.28 800.99 4.69 6.15 1 11690.14 3515.40 4587.93 -8578.20 11838.32 3509.77 5275.34 -7796.22 47.14 1041.1. 808.81 4.50 1.53 1 11900.00 3523.93 4742.28 -8720.13 12061.18 3520.18 5441.60 -7944.21 47.22 1044.5:�- I 4.40 0.65 1 12300.00 3539.15 5036.41 -8990.78 12409.56 3520.19 5706.94 -8169.87 46.37 1060.12 816.4. 4.04 1 12900.00 3547.49 5479.76 -9394.80 12981.31 3534.44 6157.73 -8520.19 47.79 1106.68 8514 7.76 1 13198.47 3542.23 5703.39 -9592.40 13321.95 3556.89 6424.13 -8731.02 49.26 1123.2 ;:reiT'. 4.3 4.33 1 • 13700.00 3518.54 6072.02 -9931.32 13938.76 3561.22 6878.82 -9146.77 45.5,lnilinKlifi 840.0 3.95 1.89 1 13797.51 3514.80 6137.47 -10003.49 14018.53 3559.97 6934.79 -9203.60 43.15 11 '.30 842.': Klm 4.21 1 14500.00 349935 6537.81 -10578.01 15064.87 3522.15 7525.57 -10057.07 27.7" ZgL 3.8 1.49 1 14850.54 3490.70 8681.53 -10897.57 15417.23 3520.47 7689.57 -10368.90 25.28 1138.7-1138.:7- 81 .:'�� 4.04 1 15500.00 349465 6943.78 -11491.68 16147.48 3528.23 7973.45 -11041.07 25.52 1124. 786.82 3. ' 1.44 1 15700.00 3491.57 7024.51 -11674.64 16347.73 3531.99 8054.28 -11224.24 25.87) 1124.6 781.85 3.29 1.46 1 15903.42 3488.50 7106.62 -11880.72 16515.59 3528.99 8123.68 -11377.03 25.85 1126. 777.831 3.23 2.32 1 16200.00 3487.37 7226.33 -12132.07 16782.25 3510.82 8240.26 -11618.12 24.97 1137.90 780.23 3.19 4.95 1 16856.31 3479.60 7491.30 -12732.46 17510.15 3489.36 8534.16 -12279.79 24.32/ 1136.911 763.21 3.051 1.64 1 End of resWls Drilling Office 2.0.960.0 Nikaitchuq\Oliktok Point\0124-08\0124-08\0124-08(P8) 9/14/2011 9:02 AM Page 12 of 39 Field: Nikaitchuq Well: OP17-02 Structure: Oliktok Point Borehole: OP17-02 Slot: OP17 Trajectory: OP17-02 Client: ENI Type: Def Survey Coordinate System: NAD27 Alaska State Plane,Zone 04,US Feet North Reference: True Grid Convergence Angle: 0.12825768' Grid Scale Factor: 0.999900314 Magnetic Declination: 21.347° Magnetic Declination Date: December 07,2010 Magnetic Model: BGGM 2010 Reference Point: Northinu EastlnY Elevation Structure Unc.(tsd( Slot Unc.tlod3 6036509.370(ftUS) 516626.280(ftUS) 53.250(fl)MSL 0.000(ft) 0 000(ft) Trelectory Error Model:ISCWSAO 3-0 95.000%Confidence 2.7955 sigma Surveying Pratt: Description MD From(ft) MD To(ft) EOU Frog Survey Tool Type Hole Diameter(in) Borehole/Survey 106.880 147.931 Act-Stns SLB_GYRO-MWD-Depth Only-No Globe 16.000 OP17-02P61/OP17-02PB1 147.931 1116.470 Act-Stns SLB_GYRO-MWD-No Globe 16.000 OP17-02PB1/OP17-02PB1 1116.470 2182.500 Act-Stns SLB_MWD+GMAG-No Globe 16.000 OP17-02PB1/0P17-02PB1 2182.500 8441.650 Act-Stns SLB_MWD+GMAG-No Globe 12.250 OP17-02PB1/OP17-02PB1 8441.650 9433.930 Act-Stns SLB_MWD+GMAG-No Globe 8.500 OP17-02PB1 I OP17-02PB1 9433.930 18200.000 Act-Stns SLB_MWD+GMAG-No Globs 8.750 OP17-02/OP17-02 Reference Cylinder North EOU-EOU Intersection MD Reference TVD Reference NS Reference EW Offset MD Offset TVD Offset NS Offset EW Aim Ct-Ct Distance Clearance OSF Angle Trace# (ft) (ft) (ft) (ft) (ft) (ft) (ft) (If) (°) (ft) (ft) (°) All local minima indicated. Results filtered:Depth 8530.00 ft<=MD<=16857.00 ft Results filtered:Ct-Ct separation<=1320.00 ft Results highlighted:Ct-Cl separation<=1320.00 ft 5500.00 3550.12 2977.89 -7095.05 9672.07 3558.00 3625.43 -6399.10 48 1 950 6,-I ll 1.86 1 10500.00 3508.25 3712.13 -7772.48 10670.81 3544.19 4391.68 -7035.50 49.4 L 1003.10 1.28 1 10562.93 3506.62 3758.43 -7815.07 10723.13 3541.82 4430.34 -7070.66 49.3. 1003.4'91 1.13 1 10600.00 3505.89 3785.70 -7840.17 10753.94 3540.57 4453.29 -7091.18 49.34 1003.92 G 1.78 1 11300.00 3512.33 4300.63 -831429 11455.15 3521.90 5001.66 -7527.22 47.96 1054.041 1.35 1 11400.00 3512.78 4374.28 -8381.93 11546.80 3521.14 5070.34 -7587.90 47.89 1055.96 :.. 1.40 1 11500.00 3513.22 4447.93 -8449.58 11632.21 3521.62 5134.95 -7643.77 47.90 1058.96 832.1.0 2.19 1 11707.36 3516.05 4600.60 -8589.84 11789.58 3523.77 5257.48 -7742.45 48.01 1072.21 045 0,- 4.94 1 12400.00 3541.79 5109.89 -9058.56 12540.46 3540.25 5849.40 -8203.75 47.28 1130.3. 4.3i 2.67 1 12500.00 3544.43 5183.36 -9126.34 12637.38 3539.46 5922.74 -8267.09 47.11 1133.58 :33.01�1 2.83 1 12700.00 3549.45 5330.40 -9261.82 12810.03 3537.33 6055.32 -8377.66 47.10 1143.41 890.3' _ 3.24 1 13200.00 3542.20 5704.54 -9593.41 13308.22 3539.52 6446.88 -8685.51 48.34 1172.76 908.01 '44 2.59 1 13270.11 3540.35 5756.62 -9640.30 13371.37 3539.59 6495.84 -8725.40 47.34 1176.22 910.4:1�_ 4.03 1 13600.00 3523.06 6001.83 -9860.25 13835.11 3542.25 6839.23 -9036.35 46.8:ifilIVIII 891.6 4.16 5.77 1 14000.00 3510.70 6267.21 -10158.89 14353.36 3547.04 7180.24 -9425.54 40.8 Ij[_: Iliii] 3.94 0.60 1 14850.54 3490.70 6681.53 -10897.57 15515.00 3518.28 7749.60 -10429.74 25.1 1 10x:.-- 845.4. 3.64 1.63 1 15000.00 3492.18 6741.88 -11034.30 15630.76 3514.93 7797.98 -10534.89 24.9 1168.'- fiMISffil 3.80 2.83 1 15884.32 3488.73 7098.91 -11843.25 16541.81 3503.89 8148.98 -11375.12 24.1. FrO=iiniffi 801.73.31 1.09 1 16000.00 3488.11 7145.60 -11949.09 16627.53 3504.68 8185.08 -11452.86 24.0. 1151.91 3.28 1.81 1 16100.00 3487.74 7185.96 -12040.58 16704.64 3505.06 8218.93 -11522.14 24.5 1155.90 :01.1:, 26 2.92 1 16400.00 3486.63 7307.05 -12315.06 16942.69 3509.33 8329.05 -1173312 24.90 1176.28 813.3:® 5.86 1 1680000 3480.51 7468.56 -12680.94 17357.55 3505.69 8531.33 -12095.20 24.93 1213.75 840541-1 5.14 1 End of results Drilling Office 2.0.960.0 Nikaitchuq\Oliktok Point\0124-08\0l24-08\0124-08(P8) 9/14/2011 9:02 AM Page 13 of 39 Droing Hazards Sum ary 16" Open Hole / 13-3/8" Casing Interval Hazard Risk Level Mitigation Strategy _ Broach of Conductor Low Monitor continuously during interval. Gas Hydrates Moderate Control drill, Reduced pump rates, Reduced drilling fluid temperatures, Additions of / Lecithin. Running Sands and Low Maintain planned mud parameters, Increase Gravels mud weight,use weighted sweeps. Hole swabbing on trips Moderate Trip speeds,proper hole filling (use of trip sheets),pumping out 12-1/4" Open Hole / 9-5/8" Casing Interval Hazard Risk Level Mitigation Strategy Running Sands and Low Maintain planned mud parameters, Increase Gravels mud weight,use weighted sweeps. Gas Hydrates Low Control drill,reduced pump rates, reduced drilling fluid temperatures, additions of Lecithin. Stuck Pipe Low Good hole cleaning,pre-treatment with lost circulation material, stabilized BHA, decreased mud weight Abnormal Reservoir Low BOP training and drills, increased mud weight. Pressure Lost circulation Low Reduced pump rates, mud rheology, LCM Hole swabbing on trips Moderate Trip speeds,proper hole filling(use of trip sheets),pumping out 8-3/4" 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 8:56.00 AM a app yyypi g g- � gQ J W e _ !Ii3P jIIIIIH gii it li ' V 3,.au !E ii 1 I Ill i 001 CC 0 •_n .', 'ii w H d V oma 1. plqi turovol, 7—I I 2 — '' g P, ,I ®..m.._=________... _ •,.. tl 0 m"cvi . o e m% • s § a3�n h b yyg •• vi 2 hWCW QyQI2 pp Ito- t,%h the p, ggk - R § 8 g -, INN 2 b I to..... x iio ■ ■ A : ■ NLu ■V a� x$ O ' Z O _, Q K cp -_ IY1111 PM OAi4$iji:: a illibilYm , U TT( A\ ■ ' x .t/l Y-,9 a m Y, o z 1 l gR 1 Yp U� k--1::: -J�-� -x�� a �� x �3=U J \J O J Q_z J �J 8 J N d � IzMWN uI m"� CD\.- �i'z"v <a Ji �QUZ\ in..., J`i' W "?(nom ry� �. e1P [ 1 c� L ct v- CC-CP C�Zin z z �oLr) z eF n) N i P B 3J X30 33i o 0o a>J O= ? i a u-s• to o i-,.,_ J �CD n U n 1 U I a0 n� 1 — I T I WLa Z etO i \ __A I U I J L I L- 0CC - - - 0 - 0 + t MI °` M y � In I �---� 1--j i E_ 40 CO O / aNv 4a � � ICO-49:_< 1 - 4 03a. 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Schlumberger CemCAD E*well cementing recommendation for 13.37511 Surface Casing Operator : Eni Petroleum Well : 0124-08 Country : USA Field : Nikaitchuq State : Alaska Prepared for : Mr.Luca Borri Location : North Slope-Alaska Proposal No. : Draft v1 (P8) Service Point : Prudhoe Bay,Alaska Date Prepared : 09-15-2011 Business Phone : 907-659-2434 FAX No. : 907-659-2538 Prepared by : Mark Roos Phone : 907-748-7555 E-Mail Address : mroos@slb.com C, • FL 41(VATE 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 : 0124-08 Schlumberger String : 13.375 District : Prudhoe Bay,Alaska Country : USA Loadcase : Surface Section 1 : well description Configuration : Casing Stage : Single Rig Type : Land Mud Line : 0.0 ft Total MD : 2558.0 ft BHST : 37 degF Bit Size : 16 in (x 1000) psi • ft 0 0.3 0.6 0.9 1.2 1.5 — — — — — — — — — — — - — — — — Frac -Siltstone— poe —- — 0 0_ — , 0 . . .• ." , . . .. . . . . . . . . . . . . -• • • • -• • • • - • — . . . . . . . . . .. 0 0_ 0 CNA Coal . Sandstone*.'. MNIIMM 0 ! Well Lithology Formation Press. Page 2 0124-08 VI P£1,cfw,09-15-2011, LoadCase Surface,Version wcs-cem462_12 Client : Eni Petroleum Well : 0124-08 Schlumberger String : 13.375 District : Prudhoe Bay,Alaska Country : USA Loadcase : Surface Previous String MD OD Weight ID (ft) _ (in) (lb/ft) (n) 160.0 20 178.9 18.250 Landing Collar MD : 2478.0 ft Casing/liner Shoe MD : 2558.0 ft Casing/Liner MD OD Joint Weight ID Grade Collapse Burst Thread (ft) (in) (ft) (Ib/ft) (in) (psi) (psi) 2558.0 13 3/8 40.0 68.0 12.415 L-80 2270 5020 BTC Mean OH Diameter : 16.000 in Mean Annular Excess : 205.2 Mean OH Equivalent Diameter: 20.352 in Total OH Volume : 964.9 bbl (including excess) Caliper and Hole Size Data MD Caliper Excess Equiv. Diam. (ft) (in) (%) (in) 2058.0 16.000 250.0 21.184 2558.0 16.000 35.0 16.822 Page 3 0124-08 01 P8 cfw,09-15-2011: LoadCase Surface,Version wcs-cem482 12 Client : Eni Petroleum Well : 0124-08 Schlumberger String : 13.375 District : Prudhoe Bay,Alaska Country : USA Loadcase : Surface Max. Deviation Angle : 57 deg Max. DLS : 3.537 deg/100ft Directional Survey Data MD TVD Deviation Azimuth Dogleg Sev. (ft) (ft) (deg) (deg) (deg/100ft) 0.0 0.0 0.0 295.0 0.000 100.0 100.0 0.0 295.0 0.000 200.0 200.0 0.0 295.0 0.000 300.0 300.0 0.0 295.0 0.000 400.0 400.0 1.5 295.0 1.500 500.0 499.8 5.0 295.0 3.500 600.0 599.1 8.5 295.0 3.500 700.0 697.5 12.0 295.0 3.500 800.0 794.6 15.5 295.0 3.500 900.0 890.1 19.0 295.0 3.500 1000.0 983.6 22.5 295.0 3.500 1066.9 1044.9 24.8 295.0 3.496 1100.0 1074.8 26.0 295.0 3.509 1200.0 1163.2 29.5 295.0 3.500 1257.6 1212.9 31.5 295.0 3.505 1300.0 1248.7 33.0 295.0 3.494 1400.0 1330.9 36.5 295.0 3.500 1426.7 1352.2 37.4 295.0 3.484 1500.0 1410.3 37.8 295.0 0.505 1600.0 1489.0 38.3 295.0 0.500 1700.0 1567.2 38.8 295.0 0.500 1800.0 1644.9 39.3 295.0 0.500 1867.8 1697.2 39.6 295.0 0.502 1900.0 1722.0 39.8 295.0 0.497 2000.0 1798.5 40.3 295.0 0.500 2070.6 1852.2 40.7 295.0 0.496 2100.0 1874.4 41.6 294.5 3.529 2200.0 1947.1 45.0 293.0 3.491 2300.0 2015.8 48.3 291.7 3.506 2302.8 2017.6 48.4 291.7 3.324 2400.0 2080.0 51.7 290.5 3.506 2500.0 2139.5 55.1 289.4 3.499 2558.0 2171.9 57.1 288.8 3.537 Formation Data MD Frac. Pore Name Lithology (ft) (lb/gal) (lb/gal) 714.0 11.30 8.43 SV-4 Siltstone 973.0 11.40 8.43 SV-3 Sandstone 1259.0 11.50 8.43 SV-2 Siltstone 1873.0 11.80 8.43 SV-1 Sandstone 1900.0 12.00 8.43 Permafrost Base Shale 2275.0 12.30 8.43 Ugnu Top(UG4) Coal 2558.0 12.50 8.43 Surface Casing Sandstone Shoe Page 4 0124-08 V1 P8 cfw,09-15-2011: LoadCase Surface:Version wcs-cem462_12 Client : Eni Petroleum Well : 0124-08 Schlumberger String : 13.375 District : Prudhoe Bay,Alaska Country : USA Loadcase : Surface Geothermal Temperature Profile MD TVD Temperature Gradient (ft) (ft) (degF) (degF/100ft) 0.0 0.0 60 0.0 1900.0 1722.0 32 -1.6 2558.6 2172.2 37 -1.1 Section 2: fluid sequence Job Objectives: Cement to Surface in Permafrost and a competent shoe for drilling ahead. Original fluid Mud 9.50 lb/gal k : 8.28E-2 Ibf.s^n/ft2 n : 0.262 Ty:0.48 lbf/100ft2 Displacement Volume 371.0 bbl Total Volume 1055.1 bbl TOC 0.0 ft Fluid Sequence Name Volume Ann. Len Top Density Rheology (bbl) (ft) (ft) (lb/gal) MUDPUSH II 100.0 0.0 10.10 k:2.54E-2 lbf.s^n/ft2 n:0.420 Ty:13.04 lbf/100ft2 ASL Lead Slurry 521.6 2058.0 0.0 10.70 k:2.03E-1 Ibf.s^n/ft2 n:0.198 Ty:8.75 lbf/100ft2 LiteCRETE Tail Slurry 62.5 500.0 2058.0 12.50 k:7.96E-3 Ibf.s^n/ft2 n:0.895 Ty:14.59 lbf/100ft2 Mud 371.0 0.0 9.50 k:8.28E-2 lbf.s^n/ft2 n:0.262 Ty:0.48 lbf/100ft2 Static Security Checks: Frac 5 psi at 160.0 ft Pore 19 psi at 160.0 ft Collapse 2036 psi at 2478.0 ft Burst 5020 psi at 0.0 ft Csg.Pump out 52 ton Check Valve Diff Press 159 psi Page 5 0124-08 V1 P8 cfw,09-15-2011; LoadCase Surface;Version wcs-cem462_12 Client : Eni Petroleum Well : 0124-08 Schlumberger String : 13.375 District : Prudhoe Bay,Alaska Country : USA Loadcase : Surface CemCADE Client : Eni Petroleum Well :0124-08 String : 13.375"Surface Casing District :Prudhoe Bay,Alaska Country :USA ft lb/gal 8 9 10 11 12 13 _ -Hydrostatic -Mn.Hydrostatic Max.Dynanic Mn.Dynamic' -Frac -Pore O Cff 0 N I E E O u O O is 0 O - P> Fluid Sequence Dynamic Well Security 0 ■MUDPUSH II 100.0 bbl 10.10 b/gal Herschel:k=2.54E-2 Ibf.s"n/ft2 n=0.420 Ty=13.04 Ibf/100ft2 3 ASL Lead Slurry 521.6 bbl 10.70 b/gal Herschel:k=2.03E-1 bf.s^n/ft2 n=0.198 Ty=8.75 bf/100f12 ■LiteCRETE Tail Slurry 62.5 bbl 12.50 b/gal Herschel:k=7.96E-3 bf.s"n/ft2 n=0.895 Ty=14.59 bf/100ft2 ■Mid 371.0 bbl 9.50 b/gal Herschel:k=8.28E-2 bf.s^n/ft2 n=0.262 Ty=0.48 bf/100ft2 Total Depth = 2558.0 ft Top of Cement= 0.0 ft *Mark of Schlumberger Sehlimberger Page 6 0124-08 V1 PB.cfw:09-15-2011; LoadCase Surface;Version wcs-cem462_12 Client : Eni Petroleum Well : 0124-08 Schiemherger String : 13.375 District : Prudhoe Bay,Alaska Country : USA Loadcase : Surface Section 3: pumping schedule Pumping Schedule Name Flow Rate Volume Stage Time Cum.Vol Inj. Comments (bbl/min) (bbl) (min) (bbl). Temp. (degF) MUDPUSH II 6.0 100.0 16.7 100.0 80 Start Pumping Spacer Pause 0.0 0.0 3.0 0.0 80 Drop Bottom Plug Pause 0.0 0.0 3.0 0.0 80 Start Mixing Lead Slurry ASL Lead 6.0 521.6 86.9 521.6 80 Mixing and Pumping Lead Slurry Slurry(3 to 7 BPM) LiteCRETE Tail 6.0 62.5 10.4 62.5 80 Start Mixing and Pumping Slurry Tail Slurry(3 to 7 BPM) Pause 0.0 0.0 5.0 0.0 80 Drop Top Plug Mud 8.0 310.0 38.8 310.0 80 Rig Pumps To Displace Mud 6.0 30.0 5.0 340.0 80 Slow Down Mud 4.0 21.0 5.3 361.0 80 Slow Down Mud 2.0 10.0 5.0 371.0 80 Slow Down Until Plug Lands Shut-In 0.0 0.0 5.0 0.0 80 Static period after Placement Total 02:59 1055.1 bbl hr:mn Dynamic Security Checks : Frac 0 psi at 160.0 ft Pore 9 psi at 160.0 ft Collapse 2036 psi at 2478.0 ft Burst 4803 psi at 0.0 ft Temperature Results BHCT 58 degF Simulated Max HCT 76 degF Simulated BHCT 76 degF Max HCT Depth 2505.8 ft 1 CT at TOC 71 degF Max HCT Time 02:59:01 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 37 degF Page 7 0124-08 VI P8.cfw.09-15-2011: LoadCase Surface,Version wcs-cem462 12 Client : Eni Petroleum Well : 0124-08 ScIolerger String : 13.375 District : Prudhoe Bay,Alaska Country : USA Loadcase : Surface ECD at the shoe: O Dpth= 2558 ft M O N 1 O Frac Fbre Hydrostatic Dynamic O C d 4iO d 01 OS— N c0— Ow W 0 20 40 60 80 100 120 140 160 180 200 Time (min) ECD at the Conductor Shoe: Depth= 160 ft Fluids at 2558 ft 0 r Frac Fore Hydrostatic d- Dynamic l(l_ 0 as- u) od- o t T T 0 20 40 60 80 100 120 140 160 180 200 Time(min) Page 8 0124-08 V1 P8.cfw;09-15-2011: LoadCase Surface;Version wcs-cem462_12 Client : Eni Petroleum Well : 0124-08 Schlumherger String : 13.375 District : Prudhoe Bay,Alaska Country : USA Loadcase : Surface BHCT Model: RI f o Last Sack Depth First Sack Depth Last Sack Terre. I-M � First Sack Terre. 8 0 mm -o M1 -0) F ` k to k N I -N RT--T- -T-- N O 20 40 60 80 100 120 140 160 180 200 Time (min) Surface Pressure: Calc.CemHP - . .Calc.Pump Press. P 1 . N 3 ./1 8_r„........... 8 0 I I - --T 0 20 40 60 80 100 120 140 160 180 200 Time (min) Page 9 0124-08 V1 P8.cfw,09-15-2011: LoadCase Surface.Version wcs-cem462_12 Client : Eni Petroleum Well : 0124-08 Mihail!' String : 13.375 District : Prudhoe Bay,Alaska Country : USA Loadcase : Surface Returns Rate: Fluids at 2558 ft co 0 Out 00_ ah 'Es J g g M- N- O — , —T T — T T--_-- T 0 20 40 60 80 100 120 140 160 180 200 Time (min) Anullar Velocity: Depth= 2558 ft_— p_ Annular Velocity O R- S- r f - "E' \--/—li X05_ 0 20 40 60 80 100 120 140 160 180 200 Time (min) Page 10 0124-08 V1 P8 cfw;09-15-2011; LoadCase Surface.Version wcs-cem462_12 • Client : Eni Petroleum Well : 0124-08 Scblmierger String : 13.375 District : Prudhoe Bay,Alaska Country : USA Loadcase : Surface Section 4: fluid description Mud DESIGN Fluid No: 1 Density :9.50 lb/gal Rheo. Model : HERSCHEL_B. k :8.28E-2 Ibf.s^n/ft2 At temp. : 65 degF n :0.262 Ty :0.481bf/100ft2 Gel Strength :6.40 Ibf/100ft2 MUD Mud Type :WBM Job volume : 371.0 bbl Water Type : Fresh VOLUME FRACTION Solids :4.0% Oil :0.0% Water :96.0% MUDPUSH II DESIGN Fluid No:2 Density : 10.10 lb/gal Rheo. Model : HERSCHEL_B. k :2.54E-2 Ibf.s^n/ft2 At temp. : 65 degF n :0.420 Ty : 13.04 lbf/100ft2 Gel Strength :(lbf/100ft2) Job volume : 100.0 bbl ASL Lead Slurry DESIGN Fluid No:3 Density : 10.70 lb/gal Rheo. Model : HERSCHEL_B. k :2.03E-1 Ibf.s^n/ft2 At temp. :69 degF n :0.198 Ty :8.75 lbf/100ft2 Gel Strength : 14.25 Ibf/100ft2 DESIGN BLEND SLURRY Name : B809 Mix Fluid : 10.610 gal/sk Job volume :521.6 bbl Dry Density : 107.08 lb/ft3 Yield :2.35 ft3/sk Quantity : 1244.94 sk Sack Weight : 100 lb Solid Fraction : 39.7% BASE FLUID Type : Fresh water Density :8.32 lb/gal Base Fluid : 10.610 gal/sk Page 11 0124-08 V1 P8.cfw;09-15-2011; LoadCase Surface;Version wcs-cem462_12 Client : Eni Petroleum Well : 0124-08 Schlumberger String : 13.375 District : Prudhoe Bay,Alaska Country : USA Loadcase : Surface LiteCRETE Tail Slurry 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 :46.96 lbf/100ft2 DESIGN BLEND SLURRY Name : D972 Mix Fluid : 5.461 gal/sk Job volume :62.5 bbl Dry Density : 121.24 lb/ft3 Yield : 1.56 ft3/sk Quantity :224.69 sk Sack Weight : 100 lb Solid Fraction : 53.3% BASE FLUID Type : Fresh water Density : 8.32 lb/gal Base Fluid : 5.461 gal/sk Additives Code Conc. Function D046 0.200%BWOB Antifoam D065 0.250%BWOB Dispersant D167 0.250%BWOB Fluid loss Annulus ID : 13.375 in-OD : 19.500 in C M T N- N ASL Lead Slurry MUDPUSHII p N - Mud LiteCRETETailSlurry U N U U PI' C O U 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 0124-08 V1 P8.cfw.09-15-2011: LoadCase Surface,Version wcs-cem462_12 Client : Eni Petroleum Well : 0124-08 Schlumberger String : 13.375 District : Prudhoe Bay,Alaska Country : USA Loadcase : Surface Section 5: centralizer placement Top of centralization :0.0 ft Bottom Cent. MD :2538.0 ft Casing Shoe :2558.0 ft NB of Cent. Used :40 NB of Floating Cent. :40 Centralizer Placement Bottom MD Nbr. Cent./ Cent. Name Code Min. STO @ Depth (ft) Joint (%) (ft) 1918.0 24 1/2 NW-TR-13 3/8-8-TR 3 W304 6.4 498.0 2558.0 16 1/1 NW-TR-13 3/8-8-TR 3 W304 18.1 2078.0 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 N/A N/A (1)-Centralizer performance data is based on tests by WEATHERFORD as per the current API 10D specifications ft % 400 20 60 80 100 o I -+ I , Between Cent. • •At Cent. Well Pipe Standoff Page 13 0124-08 Vt P8.cfw;09-15-2011; LoadCase Surface;Version wcs-cem462_12 Client : Eni Petroleum Well : 0124-08 Schlumberger String : 13.375 District : Prudhoe Bay,Alaska Country : USA Loadcase : Surface Section 6: WELLCLEAN II Simulator cyo ft % 0 50 100 0 25 50 75 100 0 i i --1 ri - Std Betw.Cent. Mud Contamination - Cement Coverage - Uncontaminated Slurry Fluid Sequence Cement Coverage Uncontaminated Slurry Fluids Concentrations Risk Mud on the Wall z 3 2 0-1 r -0 0 0 500- -500 500 500 - 1000- -1000 ; E 1000 , 1000 r - f r � f a a a a c 1500- 1500 0 o 1500 1500 0 2000- -2000 2000 2000 2500-I -2500 2500 2500 O Mud EJ High = Low I I LiteCRETE Tail Slurry = Medium EJ None I I ASL Lead Slurry I MUDPUSH II Page 14 0124-08 V1 P8.cfw;09-15-2011; LoadCase Surface;Version wcs-cem462_12 Client : Eni Petroleum Well : 0124-08 Schlumkergcr String : 13.375 District : Prudhoe Bay,Alaska Country : USA Loadcase : Surface Section 7: operator summary TOTAL MATERIAL REQUIREMENTS Additives Total Item Pack. Packaging Comments Quantity Quantity Name B809 124494 lb 1245 sack 100 lb D972 22467 lb 225 Sack 100 lb D182 552 lb 23 sack 25 lb D047 20.0 gal 5 can 5.0 gal D031 9537 lb 87 sack 110 lb D046 45 lb 9 sack 50 lb D065 57 lb 9 sack 50 lb D167 57lb 3 sack 251b Mix Water Requirements : Fresh water 18302 gal MIXING PREPARATION MUDPUSH II Volume : 100.0 bbl Density: 10.10 lb/gal Code Quantity Design Fresh water 92.046 bbl D182 552.278 lb 6.000 Ib/bbl of base fluid D047 20.000 gal 0.200 gal/bbl of spacer D031 9536.741 lb 95.37 lb/bbl of spacer ASL Lead Slurry Volume :521.6 bbl Density : 10.70 lb/gal Yield :2.35 ft3/sk Dry Phase Liquid Phase Blend: 124494 lb Design Mix Water 314.5 bbl 10.0 bbl LAS Design B809 124493.641 Fresh water 314.492 bbl 10.001 bbl lb LiteCRETE Tail Slurry Volume :62.5 bbl Density : 12.50 lb/gal Yield : 1.56 ft3/sk Dry Phase Liquid Phase Blend: 22624 lb Design Mix Water 29.2 bbl 10.0 bbl LAS Design D972 22466.709 lb Fresh water 29.216 bbl 10.001 bbl D046 44.933 lb 0.200%BWOB D065 56.167 lb 0.250%BWOB D167 56.167 lb 0.250%BWOB Page 15 0124-08 V1 P8.cfw.09-15-2011. LoadCase Surface,Version wcs-cem462_12 Schlumberger CemCAD Ewell cementing recommendation for 9-5/8" Intermediate Casing Operator : Eni Petroleum Well : 0124-08 Country : USA Field : Nikaitchuq State : Alaska Prepared for : Mr.Luca Borri Location : North Slope-Alaska Proposal No. : Draft v2(P8) Service Point : Prudhoe Bay,Alaska Date Prepared : 09-19-2011 Business Phone : 907-659-2434 FAX No. : 907-659-2538 Prepared by : Mark Roos Phone : 907-748-7555 E-Mail Address : mroos©slb.com 01. C NAT E Disclaimer Notice: Schlumberger submits this document with the benefit of its judgment,experience,and good oilfield practices. This information is provided in accordance with generally accepted industry practice.relying on facts or information provided by others,limitations,computer models,measurements,assumptions and inferences that are not infallible. Calculations are estimates based on provided information.All proposals.recommendations,or predictions are opinions only. ND 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 : 0124-08 Schlumberger String : 9-5/8 District : Prudhoe Bay,Alaska Country : USA Loadcase : Intermediate Section 1 : well description Configuration : Casing Stage : Single Rig Type : Land Mud Line : 0.0 ft Total MD : 8530.0 ft BHST : 63 degF Bit Size : 12 1/4 in ft (x 1000) psi 0 0.5 1.0 1.5 2.0 2.5 o — -SI ltstone--. — Frac Fore o I =M=M=EM 0 • •'Sandstone- Coal o M Coal 111 ...*:,Sandstone':: o o 0 co Shale Co- -- 11111 o - 8- Well Lithology Formation Press. Page 2 oi24-08 v2 p8.cfw;09-19-2011, LoadCase Intermediate:Version wcs-cem462_12 Client : Eni Petroleum Well : 0124-08 Schhookrger String : 9-5/8 District : Prudhoe Bay,Alaska Country : USA Loadcase : Intermediate Previous String MD OD Weight ID (ft) (in) (Ib/ft) (in) 2558.0 13 3/8 68.0 12.415 Landing Collar MD : 8450.0 ft Casing/liner Shoe MD : 8530.0 ft Casing/Liner MD OD Joint Weight ID Grade Collapse Burst Thread (ft) (in) (ft) (Ib/ft) (in) (psi) (psi) 8530.0 9 5/8 40.0 40.0 8.835 L-80 2780 4920 Hydril 563 Page 3 oi24-08 v2 p8.cfw:09-19-2011: LoadCase Intermediate;Version wcs-cem462_12 Client : Eni Petroleum Well : 0124-08 Schlimlfirgcr String : 9-5/8 District : Prudhoe Bay,Alaska Country : USA Loadcase : Intermediate Mean OH Diameter : 12.250 in Mean Annular Excess : 50.0 Mean OH Equivalent Diameter: 13.371 in Total OH Volume : 1037.1 bbl (including excess) Max. Deviation Angle : 85 deg Max. DLS : 3.509 deg/100ft Directional Survey Data MD TVD Deviation Azimuth Dogleg Sev. (ft) (ft) (deg) (deg) (deg/100ft) 0.0 0.0 0.0 0.0 0.000 100.0 100.0 0.0 0.0 0.000 200.0 200.0 0.0 0.0 0.000 300.0 300.0 0.0 0.0 0.000 400.0 400.0 1.5 0.0 1.500 500.0 499.8 5.0 0.0 3.500 600.0 599.1 8.5 0.0 3.500 700.0 697.5 12.0 0.0 3.500 800.0 794.6 15.5 0.0 3.500 900.0 890.1 19.0 0.0 3.500 1000.0 983.6 22.5 0.0 3.500 1066.9 1044.9 24.8 0.0 3.496 1100.0 1074.8 26.0 0.0 3.509 1200.0 1163.2 29.5 0.0 3.500 1257.6 1212.9 31.5 0.0 3.505 1300.0 1248.7 33.0 0.0 3.494 1400.0 1330.9 36.5 0.0 3.500 1426.7 1352.2 37.4 0.0 3.484 1500.0 1410.3 37.8 0.0 0.505 1600.0 1489.0 38.3 0.0 0.500 1700.0 1567.2 38.8 0.0 0.500 1800.0 1644.9 39.3 0.0 0.500 1867.8 1697.2 39.6 0.0 0.502 1900.0 1722.0 39.8 0.0 0.497 2000.0 1798.5 40.3 0.0 0.500 2070.6 1852.2 40.7 0.0 0.496 2100.0 1874.4 41.6 0.0 3.362 2200.0 1947.1 45.0 0.0 3.340 2300.0 2015.8 48.3 0.0 3.370 2302.8 2017.6 48.4 0.0 3.226 2400.0 2080.0 51.7 0.0 3.384 2500.0 2139.5 55.1 0.0 3.390 • 2558.6 2172.2 57.1 0.0 3.398 2600.0 2194.3 58.5 0.0 3.403 2700.0 2243.9 61.9 0.0 3.400 2800.0 2288.3 65.3 0.0 3.410 2900.0 2327.4 68.8 0.0 3.420 3000.0 2360.8 72.2 0.0 3.420 3100.0 2388.6 75.6 0.0 3.420 3127.9 2395.3 76.6 0.0 3.437 3200.0 2412.0 76.6 0.0 0.000 3300.0 2435.3 76.6 0.0 0.000 3372.3 2452.1 76.6 0.0 0.000 3400.0 2458.6 76.6 0.0 0.000 3500.0 2481.8 76.6 0.0 0.000 3600.0 2505.1 76.6 0.0 0.000 3700.0 2528.3 76.6 0.0 0.000 3800.0 2551.6 76.6 0.0 0.000 Page 4 oi24-08 v2 p8.cfw,09-19-2011, LoadCase Intermediate;Version wcs-cem462_12 Client : Eni Petroleum Well : 0124-08 Schlbrger String : 9-5/8 District : Prudhoe Bay,Alaska Country : USA Loadcase : Intermediate Directional Survey Data MD TVD Deviation Azimuth Dogleg Sev. (ft) (ft) (deg) (deg) (deg/100ft) 3900.0 2574.9 76.6 0.0 0.000 4000.0 2598.1 76.6 0.0 0.000 4100.0 2621.4 76.6 0.0 0.000 4200.0 2644.6 . 76.6 0.0 0.000 4300.0 2667.9 76.6 0.0 0.000 4400.0 2691.2 76.6 0.0 0.000 4500.0 2714.4 76.6 0.0 0.000 4600.0 2737.7 76.6 0.0 0.000 4700.0 2760.9 76.6 0.0 0.000 4800.0 2784.2 76.6 0.0 0.000 4900.0 2807.5 76.6 0.0 0.000 5000.0 2830.7 76.6 0.0 0.000 5100.0 2854.0 76.6 0.0 0.000 5200.0 2877.2 76.6 0.0 0.000 5300.0 2900.5 76.6 0.0 0.000 5400.0 2923.8 76.6 0.0 0.000 5500.0 2947.0 76.6 0.0 0.000 5600.0 2970.3 76.6 0.0 0.000 5700.0 2993.5 76.6 0.0 0.000 5800.0 3016.8 76.6 0.0 0.000 5900.0 3040.1 76.6 0.0 0.000 6000.0 3063.3 76.6 0.0 0.000 6063.9 3078.2 76.6 0.0 0.000 6100.0 3086.6 76.6 0.0 0.000 6200.0 3109.8 76.6 0.0 0.000 6300.0 3133.1 76.6 0.0 0.000 6400.0 3156.3 76.6 0.0 0.000 6500.0 3179.6 76.6 0.0 0.000 6600.0 3202.9 76.6 0.0 0.000 6700.0 3226.1 76.6 0.0 0.000 6800.0 3249.4 76.6 0.0 0.000 6900.0 3272.6 76.6 0.0 0.000 7000.0 3295.9 76.6 0.0 0.000 7081.6 3314.9 76.6 0.0 0.000 7100.0 3319.2 76.6 0.0 0.000 7144.0 3329.4 76.6 0.0 0.000 7190.9 3340.3 76.6 0.0 0.000 7200.0 3342.4 76.6 0.0 0.659 7277.0 3359.9 77.1 0.0 0.689 7300.0 3365.0 77.3 0.0 0.694 7400.0 3386.4 78.0 0.0 0.720 7434.7 3393.5 78.3 0.0 0.749 7500.0 3406.5 78.8 0.0 0.750 . 7600.0 3425.3 79.6 0.0 0.780 7654.0 3434.9 80.0 0.0 0.814 7700.0 3442.7 80.4 0.0 0.805 7800.0 3458.8 81.2 0.0 0.830 7900.0 3473.3 82.1 0.0 0.860 8000.0 3486.4 82.9 0.0 0.870 8100.0 3498.0 83.8 0.0 0.900 8170.7 3505.2 84.5 0.0 0.905 8200.0 3507.9 84.7 0.0 0.887 8230.0 3510.6 85.0 0.0 0.932 8300.0 3516.7 85.0 0.0 0.000 8378.6 3523.6 85.0 0.0 0.000 8400.0 3525.4 85.0 0.0 0.000 8500.0 3534.2 85.0 0.0 0.000 Page 5 oi24-08 v2 p8.cfw;09-19-2011; LoadCase Intermediate;Version wcs-cem482_12 Client : Eni Petroleum Well : 0124-08 Schlumberger String : 9-5/8 District : Prudhoe Bay,Alaska Country : USA Loadcase : Intermediate Directional Survey Data MD TVD Deviation Azimuth Dogleg Sev. (ft) (ft) (deg) (deg) (deg/100ft) 8530.0 3536.8 85.0 0.0 0.000 Formation Data MD Frac. Pore Name Lithology (ft) 11b/gal) (lb/gal) 714.0 11.10 8.43 SV-4 Siltstone 973.0 11.20 8.43 SV-3 Sandstone 1259.0 11.50 8.43 SV-2 Siltstone 1873.0 11.80 8.43 SV-1 Sandstone 1900.0 12.00 8.43 Permafrost Base Shale 2275.0 12.30 8.43 Ugnu Top(UG4) Coal 2558.0 12.50 8.43 Surface Casing Shoe 3382.0 12.30 8.43 UG-2 Coal Bed Coal Marke 6083.0 12.50 8.43 Lower Ugnu Sandstone 7067.0 12.50 8.43 Schrader Bluff Shale 7130.0 12.50 8.43 N Seq Top Sandstone 7268.0 12.50 8.43 N Top Sandstone 7430.0 12.50 8.43 N Bottom Sandstone 7661.0 12.50 8.43 N Seq Base Sandstone 8059.0 12.50 8.43 Fault Shale 8394.0 12.50 8.43 OA Sand Top Sandstone 8530.3 12.50 8.43 9-5/8 Intermediate Sandstone Page 6 oi24-08 v2 p8.cfw,09-19-2011, LoadCase Intermediate,Version wcs-cem462_12 Client : Eni Petroleum Well : 0124-08 Schlumberger String : 9-5/8 District : Prudhoe Bay,Alaska Country : USA Loadcase : Intermediate Geothermal Temperature Profile MD TVD Temperature Gradient (ft) (ft) (degF) (degF/100ft) 0.0 0.0 60 0.0 1900.0 1722.0 32 -1.6 2558.0 2171.9 37 -1.0 8530.3 3536.8 63 0.1 deg F 30 35 40 45 50 55 60 65 70 75 80 85 - Annulus - Tubular Fluids - Geoth.Profile • Temp. Profile At 145 min Page 7 oi24-08 v2 p8.cfw;09-19-2011; LoadCase Intermediate;Version wcs-cem462_12 Client : Eni Petroleum Well : 0124-08 Schlumherger String : 9-5/8 District : Prudhoe Bay,Alaska Country : USA Loadcase : Intermediate Section 2: fluid sequence Original fluid Mud 9.40 lb/gal k : 5.97E-3 Ibf.s^n/ft2 n : 0.616 Ty: 8.86 lbf/100ft2 Displacement Volume 640.7 bbl Total Volume 906.1 bbl TOC 6268.0 ft Fluid Sequence Name Volume Ann. Len Top Density Rheology (bbl) (ft) (ft) (lb/gal) MUDPUSH II 70.0 836.6 5431.4 10.50 k:5.23E-2 lbf.s^n/ft2 n:0.324 Ty:12.92 lbf/100ft2 LiteCRETE Tail Slurry 195.3 2262.0 6268.0 12.50 k:3.15E-3 Ibf.s^n/ft2 n:1.000 Ty:20.17 lbf/100ft2 Mud 640.7 0.0 9.40 k:5.97E-3 lbf.s^n/ft2 n:0.616 Ty:8.86 lbf/100ft2 Static Security Checks: Frac 350 psi at 2558.0 ft Pore 109 psi at 2558.0 ft Collapse 2562 psi at 8450.0 ft Burst 4920 psi at 0.0 ft Csg.Pump out 58 ton Check Valve Diff Press 76 psi Page 8 oi24-08 v2 p8 cfw,09-19-2011; LoadCase Intermediate;Version wcs-cem462_12 Client : Eni Petroleum Well : 0124-08 Schlumberger String : 9-5/8 District : Prudhoe Bay,Alaska Country : USA Loadcase : Intermediate CemCADE Client : Eni Petroleum Well :0124-08 String :9-5/8"Intermediate Casing District : Prudhoe Bay,Alaska Country : USA lb/gal ft 8 9 10 11 12 13 -Hydrostatic -Mn.Hydrostatic -Mex.Dynamic O Mn.Dynamic Frac � Pore S M e d O O_ Lf) 3 � .4 C $ O- € O m U B 8_ s _ O - O O)— Fluid Sequence Dynamic Well Security ■MUDFUSH II 70.0 bbl 10.50 b/gal Herschel:k=5.23E-2 bf.s^n/ft2 n=0.324 Ty=12.92 bf/100ft2 ■LtieCFtETE Tail Slurry 195.3 bbl 12.50 lb/gal Herschel:k=3.15E-3 Ibf.s^n/ft2 n=1.000 Ty=20.17 Ibf/100ft2 ■Mud 640.7 bbl 9.40 lb/gal Herschel:k=5.97E-3 lbf.s^n/ft2 n=0.616 Ty=8.86 bf/100ft2 Total Depth = 8530.0 ft Top of Cement= 6268.0 ft *Mark of Schlumberger Page 9 oi24-08 v2 p8.cfw;09-19-2011; LoadCase Intermediate;Version wcs-cem462_12 1 Client : Eni Petroleum Well : 0124-08 Schlumberger String : 9-5/8 District : Prudhoe Bay,Alaska Country : USA Loadcase : Intermediate Section 3: pumping schedule Start Job: Circulate Two Hole Volumes, 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 6.0 70.0 11.7 70.0 80 Start Pumping Spacer Pause 0.0 0.0 3.0 0.0 80 Drop Bottom Plug • Pause 0.0 0.0 3.0 0.0 80 Start Mixing Slurry LiteCRETE Tail 6.0 195.3 32.6 195.3 80 Mixing and Pumping Tail Slurry Slurry(3 to 7 BPM) Pause 0.0 0.0 5.0 0.0 80 Drop Top Plug Mud 8.0 620.7 77.6 620.7 80 Rig Pumps To Displace Mud 6.0 5.0 0.8 625.7 80 Slow Down Mud 4.0 5.0 1.3 630.7 80 Slow Down Mud 2.0 10.0 5.0 640.7 80 Slow Down Until Plug Lands Shut-In 0.0 0.0 5.0 0.0 80 Static period after Placement Total 02:19 906.1 bbl hr:mn End Job: Bump Top Plug, Bleed-off PSI, Check floats Dynamic Security Checks : Frac 257 psi at 8530.0 ft Pore 109 psi at 2558.0 ft Collapse 2453 psi at 227.7 ft Burst 4563 psi at 0.0 ft Temperature Results BHCT 71 degF Simulated Max HCT 69 degF Simulated BHCT 57 degF Max HCT Depth 0.0 ft CT at TOC 57 degF Max HCT Time 02:12:48 hr:mn:sc Static temperatures : At Time (hr:mn) 00:05 hr:mn Geo.Temp. Top of Cement (degF) 57 degF 56 degF Bottom Hole (degF) 57 degF 63 degF Page 10 oi24-08 v2 p8.cfw;09-19-2011; LoadCase Intermediate;Version wcs-cem462_12 • Client : Eni Petroleum Well : 0124-08 Whole" String : 9-5/8 District : Prudhoe Bay,Alaska Country : USA Loadcase : Intermediate ECD simulation at casing shoe: Depth= 8530 ft o to ' N� Frac -Pore Hydrostatic -Dynamic 433) u7 I O� OI oi O_ Lo III ao I 0 25 50 75 100 125 150 Time (min) ECD simulation at previous casing shoe: O Depth= 2558 ft Fluids at 8530 ft N� �I Frac Pore r.� Hydrostatic •' Dynamic OH c � to oor as- I 0 25 50 75 100 125 150 Time (min) Page 11 oi24-08 v2 p8.cfw;09-19-2011; LoadCase Intermediate;Version wcs-cem462_12 Client : Eni Petroleum Well : 0124-08 Srhhmlierger String : 9-5/8 District : Prudhoe Bay,Alaska Country : USA Loadcase : Intermediate Temperature model: E -o P- Last Sack Depth _ I� First Sack Depth Last Sack Temp. First Sack Terrp. - -N 1 P- H g Tg O _Lo i I to :_.- 111161L, x -to \\,... Nib.— , 0 20 40 60 80 100 120 140 160 Time (min) Surface pressure: § .Calc.Cerrrl-IP iii .Calc.Purrp Press. §- \ .0/ n N \ —/ 8- — ( ...../- -\ 0 — i , 0 25 50 75 100 125 150 Time (min) Page 12 oi24-08 v2 p8.cfw;09-19-2011; LoadCase Intermediate;Version wcs-cem462_12 Client : Eni Petroleum Well : 0124-08 Scbhmberger String : 9-5/8 District : Prudhoe Bay,Alaska Country : USA Loadcase : Intermediate Returns rate: Fluids at 8530 ft 13) Q Out Q In r`- f000- - 10_ IL CO- N- - 0 25 50 75 100 125 150 Time (min) Anullar velocity: 8 Depth= 8530 ft Annular Velocity 8- 1 8- C E 8- O- NO 0 T 0 25 50 75 100 125 150 Time (min) Page 13 oi24-0B v2 p8.cfw;09-19-2011; LoadCase Intermediate;Version wcs-cem462_12 Client : Eni Petroleum Well : 0124-08 Schlumberger String : 9-5/8 District : Prudhoe Bay,Alaska Country : USA Loadcase : Intermediate Section 4: fluid description Mud DESIGN Fluid No: 1 Density : 9.40 lb/gal Rheo. Model : HERSCHEL_B. k : 5.97E-3 Ibf.s^n/ft2 At temp. : 80 degF n :0.616 Ty : 8.861bf/100ft2 Gel Strength : 32.02 lbf/100ft2 MUD Mud Type :WBM Job volume :640.7 bbl Water Type : Fresh VOLUME FRACTION Solids :6.0 Oil : 1.0% Water :93.0% MUDPUSH II DESIGN Fluid No: 2 Density : 10.50 lb/gal Rheo. Model : HERSCHEL_B. k : 5.23E-2 lbf.s^n/ft2 At temp. : 65 degF n :0.324 Ty : 12.92 lbf/100ft2 Gel Strength :40.56 lbf/100ft2 Job volume : 70.0 bbl LiteCRETE Tail Slurry DESIGN Fluid No: 3 Density : 12.50 lb/gal Rheo. Model : HERSCHEL_B. k : 3.15E-3 lbf.s^n/ft2 At temp. : 80 degF n : 1.000 Ty : 20.17 lbf/100ft2 Gel Strength :46.96 lbf/100ft2 DESIGN BLEND SLURRY Name : D972 Mix Fluid : 5.473 gal/sk Job volume : 195.3 bbl Dry Density : 121.24 lb/ft3 Yield : 1.56 ft3/sk Quantity : 701.15 sk Sack Weight : 100 lb Solid Fraction : 53.2% BASE FLUID Type : Fresh water Density : 8.32 lb/gal Base Fluid : 5.463 gal/sk Additives Code Conc. Function D046 0.129%BWOB Antifoam D065 0.250%BWOB Dispersant D167 0.250%BWOB Fluid loss D153 0.100%BWOB Antisettling D177 0.010 gal/sk blend Retarder Page 14 oi24-08 v2 pB.cfw:09-19-2011; LoadCase Intermediate,Version wcs-cem462_12 Client : Eni Petroleum Well : 0124-08 Schlumberger String : 9-5/8 District : Prudhoe Bay,Alaska Country : USA Loadcase : Intermediate Section 5: centralizer placement Top of centralization :3000.0 ft Bottom Cent. MD :8510.0 ft Casing Shoe :8530.0 ft NB of Cent. Used :38 NB of Floating Cent. :0 Centralizer Placement Bottom MD Nbr. Cent./ Cent. Name Code Min.STO @ Depth (ft) Joint (%) (ft) 6770.0 0 0/0 0.0 6788.7 7770.0 25 1/1 HYDROFORM HFD 0.0 7753.5 8010.0 0 0/0 0.0 7770.0 8530.0 13 1/1 HYDROFORM HFD 0.0 8026.5 Centralizer Description Centralizer Tests Cent. Name Code Casing Max. Min.OD Rigid Origin Hole Size Running Restoring OD OD (in) (in) Force Force (in) (in) (lbf) (lbf) HYDROFORM HFD 9 5/8 14.583 10.882 YES Weatherford(t) 12.625 N/A N/A (1)-Centralizer performance data is based on tests by WEATHERFORD as per the current API 10D specifications 0/0 ft 6 < > 0 20 40 BO Ben Cent. 80 100 • •At Cent. 0— i . SII —� ...._ - _ I i 1 1 — Well Pipe Standoff Page 15 oi24-08 v2 p8.cfw,09-19-2011, LoadCase Intermediate-Version wcs-cem462_12 Client : Eni Petroleum Well : 0124-08 Schlemherger String : 9-5/8 District : Prudhoe Bay,Alaska Country : USA Loadcase : Intermediate Section 6: WELLCLEAN II Simulator 0,0 ft % 0 50 100 0 25 50 75 100 FI �� Std Betw.Cent. Mud Contarrination - Cement Coverage Uncontaminated Slurry i W Ilkdill • Fluid Sequence Cement Coverage Uncontaminated Slurry Fluids Concentrations Risk Mud on the Wall z° 4' g z5 4500 I 4500 4500 4500 5000 5000 5000 5000 5500- 5500 5500 5500 6000- 6000 — --- 6000 _ 6000 S 6500- 6500 -c s 6500 6500 -c na n a 0 7000-07000 a o 7000 7000 0` 7500- 7500 7500 7500 €000 8000 8000 8000 55001 8500 5500 8500 a 3 a 9 .4 a z z = Mud En High = Low LiteCRETE Tail Slurry ( I Medium = None = MUDPUSHII Page 16 oi24-08 v2 p8.cfw,09-19-2011; LoadCase Intermediate;Version wcs-cem462_12 Client : Eni Petroleum Well : 0124-08 UMberger String : 9-5/8 District : Prudhoe Bay,Alaska Country : USA Loadcase : Intermediate Section 7: operator summary TOTAL MATERIAL REQUIREMENTS Additives Total Item Pack. Packaging Comments Quantity Quantity Name D972 70108 lb 701 sack 100 lb D182 381 lb 16 sack 25 lb D047 14.0 gal 3 can 5.0 gal D031 8205 lb 75 sack 110 lb D046 90 lb 2 sack 50 lb D065 175 lb 4 sack 50 lb D167 175 lb 8 sack 25lb D153 70 lb 3 sack 25 lb D177 7.0 gal 1 drum 55.0 gal Mix Water Requirements : Fresh water 6494 gal MIXING PREPARATION MUDPUSH II Volume :70.0 bbl Density: 10.50 lb/gal Code Quantity Design Fresh water 63.438 bbl D182 380.625 lb 6.000 lb/bbl of base fluid D047 14.000 gal 0.200 gal/bbl of spacer D031 8205.415 lb 117.22 lb/bbl of spacer LiteCRETE Tail Slurry Volume : 195.3 bbl Density : 12.50 lb/gal Yield : 1.56 ft3/sk Dry Phase Liquid Phase Blend: 70619 lb Design Mix Water 91.4 bbl 10.0 bbl LAS Design D972 70107.641 lb Fresh water 91.193 bbl 9.983 bbl D046 90.439 lb 0.129%BWOB D177 7.011 gal 0.768 gal 0.010 gal/sk blend D065 175.269 lb 0.250%BWOB D167 175.269 lb 0.250%BWOB D153 70.108 lb 0.100%BWOB Page 17 oi24-08 v2 p8.cfw,09-19-2011; LoadCase Intermediate;Version wcs-cem462_12 ENI S.p.A. SPEO IDENTIFICATION CODE PAG 206 OF 338 Eni E&P Division REVISION STAP-P-1-M-6140 0 1 15. LEAK OFF TEST PROCEDURE A Leak-Off Test (LOT) will be performed On Wild-Cat wells at each casing shoe after setting the surface casing. LOTs are also recommended to be carried out on both appraisal and development wells. Leak Off Test and Formation Integrity Test (FIT), also termed the Limit Test, are for formation strength pressure tests made just below the casing seat prior to drilling ahead. These tests are carried out to: • Investigate the cement seal around the casing shoe which should be at least as high as the predicted fracture pressure for the area. • Investigate the wellbore capability to withstand pressures below the casing shoe in order to allow proper well planning with regard to the setting depth of the next casing, mud weights and alternatives during well control operations. • Collect regional information on formation strengths and stress magnitude for different applications including optimisation of future well planning, hole stability analysis and modelling, reservoir application. Prior to a test, a decision should be made to either increase the pressure until leak off occurs (as in the LOT) or to stop at a predetermined pressure for a (FIT). It should be noted that: • FIT does not obtain information on stress magnitude. • A LOT is designed and should be performed to determine, in a better way, the desired data without breaking down the formation. When a Formation Integrity Test is required, the maximum pumping pressure is often expressed in terms of'Equivalent Mud Weight' (EMW): Imperial units EMW= +MW 0.052 x TVD where: P = Pumping Pressure (psi) TVD = True Vertical Depth (ft) MW = Actual Mud Weight (PPG) Metric units EMW — Px10 + MW TVD where: P = Pumping Pressure (kg/cm2) TVD = True Vertical Depth (m) MW = Actual Mud Weight (kg/I). 1101* ENI S.p.A. SPEO IDENTIFICATION CODE PAG 207 OF 338 Enn 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 1/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. 111* ENI S.p.A. SPEO IDENTIFICATION CODE PAG 208 OF 338 Ertl 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. ENI S.p.A. SPEO IDENTIFICATION CODE PAG 209 OF 338 End E&P Division REVISION STAP-P-1-M-6140 0 1 ifiAl 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 t}pe: J.UPs Hole Dlameter(in): 12"114 Weight(KgA): 1.3 R.K.B.ele ie6 on(m): 26 Last Csg.Shoe(m): 797 "Mar 1Ascositp(sec/Ot): 44 Water Depth(m): 24 Csg.diameter(in): 13'3/8 P.V(cps): 19 Pumps: 12-P-160 Grade: .155 Y.P.i b1100 f): 5 liners(in): 6.5" Weight(161t): 61 GeIs0b1100 tI: 2/8 Flow Rate(bpl): 0.25 Max.Burst pres(psi): 3103 UU.L(cc/30 min): 10.5 Utholog y Shale Expected EMW 1.68 Kg/cm2/10 m Time Volume Pressure Time Volume Pressure Time Vdume Pressure (min) (bbl) (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 1D0 300 105 2 463 5 125 400 11 2 455 6 150 500 11.5 2 450 7 1.75 570 12 2 445 8 200 800 13 2 440 8 200 550 14 2 437 — 8.5 200 505 15 2 435 — Ncte: Pumped with a constant low rate of(bbl): Vblume pumped(bbl): '8lume retuned(bbl): (psi) 1000 - --•---. 900 800 stop pump F 700 ` - e 600 �" shut in curve S 500 / _.--,•.� - —•—•—•— • • • • U 400 .- - r 8 minutes e 300 - 200 100 0 0 0,25 0,5 0,75 1 1,25 1,5 1,75 Z 1 2 3 4 5 6 7 8 9 10 11 12 Cumulative Volume(bbf) II Time mins RESULTS:(Press..+Press.LO.)x101Depth=((1.3 x797 110)+(430 x0.07)]x10/797=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 CK 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 Ol iktok OLIKTOK Ots Cli Point INTAKE MODULE DOCK ik\ OPP + , THIS P� 6 • P SURVEY 0 TANKN ! Q DEW LINE s I SITE STP TANK 31K POINT MODULES I NDC STAGING AREA'• Sioj T13N, R9E 18 DS-3Q _ „- ),'11 ° i O ,5 �J SCALE: :;)_ / i 1” = 150' \'7, ( DS."—,30 u 19 ) ( 29NA2,9 STP PAD VICINITY MAP 0 \'� SCALE: 1" = 1 Mile 0 O-0zO.O 0.0 0-0�� 000 . '0 '.7< -oaio\\\:\ ,O �0� o� Z Cps;'''. \ . ' OLIKTOK \ � '� 0POINT PAD \ C• 0a as S\ '\ ) C 1134\ \ / \ SEE SHEET 3 FOR NOTES / '\ O Existing Conductor7\� LOUNSBURY & AS• Conductor Asbuilt this survey / s S ENOCIATESGINEERS INC., RS / AREA: MODULE: UNIT: -- '- Enli PP11roIIklulm OLIKTOK POINT PAD CMI WELL CONDUCTOR ASBUILT LOCATIONS CAD LK680D1 10/9/08 DRAWING NO: NSK 6.80-d1 I PART: 1 OF 3 I REV: 2 REV DATE BY CK APP DESCRIPTION ,REV DATE BY CK 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 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 OP03-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: Chill P tiroo IIktiinr'�1 WELLOK CONDUCTOR PAD CMPOINT I ASBUILT LOCATIONS CADD FILE NO. DRAWING NO: PART: REV: LK680D1 10/9/08 NSK 6.80-d1 2 OF 3 2 REV DATE BY CK APP _ DESCRIP110N REV DATE BY CK APP DESCRIPTION 1 12/16/08 MRT AJR Add New Well Conductos 4-24 2 12/23/08 JFC 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. 9f. 44 4411 SURVEYOR'S CERTIFICATE .•� _111 ; ♦j♦ • h ' ' I HEREBY CERTIFY THAT I AM PROPERLY • 019. / REGISTERED AND LICENSED TO PRACTICE 0 ., , 0 LAND SURVEYING IN THE STATE OF I0, LS-803 r Icy ': ALASKA AND THAT THIS PLAT REPRESENTS 1 J. ROOKUS '�� ♦ °. ,`Q� A SURVEY DONE BY ME OR UNDER MY ♦♦ TF, •., /e-� DIRECT SUPERVISION AND THAT ALL o ftp le.. �� CORDIMENSIONS RECT ASA OF DECEMBER 23, 2008.OTHER DETAILS ARE ,1, �••• LOUNSBURY & ASSOCIATES, INC. SURVEYORS ENGINEERS PLANNERS f r AREA: MODULE: UNIT�=�� 'r LirOIIum OLIKTOK POINT D WELLOUORll ASBUILT LOCATIONS CADD FILE NO. DRAWING NO: PART: REV: LK680D1 10/9/08 NSK 6.80-d1 3 OF 3 2 CD 0 Co 0 0 CO M � o N • 00 O o ti ti Tle re LLJ • Q LL 1 0 o —r J O 1 c� 0 r 0 I N (0 O N }+ w CC i.f.. Q ^ Co U o 0 GD 0 0 X 0 W L c:9 CD LO 4.1 Cr Q • IL O W o O O O O O 0 0 O 0 O O 0 V. O 0 O O O O 0 d) d) 00 CO CO LC) LO LO 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 LETTERTCHECKLIST WELL NAME A'(/G'C / T C i") .2.(7-- 2.5g PTD# /2-0 l Development /Service Exploratory Stratigraphic Test Non-Conventional Well • FIELD: / / LQ! ke POOL: ✓ l kg Aid cc � �Z v � Circle Appropriat• Letter/ Paragraphs to be Included in Trans- ittal 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 subs- -. -, compliance with 20 AAC EXCEPTION 25.055. Approval to .rodfice/in'ect is c•ntingent upon issuance of a conserv4ion order ap. • ga spacing exception. 1;-74/.11:(4 (a4t ►a i a f-as Ines the liability of any protest to the4/pacing exc tion 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: 1/11/2008 m ccn D 0 D COV) D -i <K.'. C1 0 13� o crn � 3' O v 3 oo r o CD r .< 3 0 < 3 0 co 10 CO v m N.in co C 1 o C7 �° ccoo a 0 C) ` O n N O N O N w 7 O g O fD O fD 0 m - - J ^ W W Co.) CG) w C.) Co) Co) C.) N N N W N N TJ N N N j CO CO V O) CT A w N -. -. \0' _ CO CO V 0) 01 A G) NJ 0 CO 0) V 0) 01 A C.) 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