Department of Commerce, Community, and Economic Development
Alaska Oil and Gas Conservation
Commission
HOME
EVENTS
DATA
Data List
Drilling
Production
Orders
Data Miner
Document Search
REPORTS
Reports and Charts
Pool Statistics
FORMS
LINKS
Links
Test Notification
Data Requests
Regulations
Industry Guidance Bulletins
How to Apply
ABOUT US
History
Staff
HELP
Loading...
The URL can be used to link to this page
Your browser does not support the video tag.
Home
My WebLink
About
208-137
New Plugback Esets 6/27/2024 Well Name API Number PTD Number ESet Number Date 1J-118 PB1 50-029-23337-70-00 206-176 T39063 2-4-2009 1J-118 PB2 50-029-23337-71-00 206-176 T39064 2-4-2009 1J-136L1 PB1 50-029-23331-71-00 206-155 T39065 2-21-2007 1J-136L1 PB2 50-029-23331-72-00 206-155 T39066 2-21-2007 CD2-76 PB1 50-103-20603-70-00 209-098 T39067 1-13-2010 CD2-76 PB2 50-103-20603-71-00 209-098 T39068 1-13-2010 CD4-24 PB1 50-103-20602-70-00 209-097 T39069 3-24-2010 CD4-24 PB2 50-103-20602-71-00 209-097 T39070 3-24-2010 L-203L3 PB1 50-029-23416-70-00 209-112 T39071 9-24-2010 L-203L3 PB2 50-029-23416-71-00 209-112 T39072 9-24-2010 OP03-P05 PB1 50-029-23396-70-00 208-137 T39073 2-23-2009 OP03-P05 PB2 50-029-23396-71-00 208-137 T39074 2-23-2009 OP03-P05 PB1 50-029-23396-70-00 208-137 T39073 2-23-2009 OP03-P05 PB2 50-029-23396-71-00 208-137 T39074 2-23-2009 1. Operations Susp Well Insp Plug Perforations Fracture Stimulate Pull Tubing Operations shutdown Performed: Install Whipstock Perforate Other Stimulate Alter Casing Change Approved Program Mod Artificial Lift Perforate New Pool Repair Well Coiled Tubing Ops Other: _ESP Changeout___ Development Exploratory Stratigraphic Service 6. API Number: 7. Property Designation (Lease Number):8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071):10. Field/Pool(s): 11. Present Well Condition Summary: Total Depth measured 12,391 feet N/A feet true vertical 3,933 feet N/A feet Effective Depth measured 12,368 feet 5,382 feet true vertical 3,934 feet 3,523 feet Perforation depth Measured depth 5,960-12,368 feet True Vertical depth 3,686-3,934 feet Tubing (size, grade, measured and true vertical depth)2-7/8"L-80 5,260' 3,477' Packers and SSSV (type, measured and true vertical depth)HES PHL 5,382' 3,523' 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:Schrader Bluff Oil Pool 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 4/12/2024 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 Liner 5960 6614 Casing Structural 3686 5.5" 5960 12368 3934 2350 2158 20" 13.375" Size 5020 6870 measured TVD Production Plugs Junk measured 47909.625" STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 208-137 50-029-23396-00-00 3700 Centerpoint Dr. Ste 500, Anchorage, AK, 99503 3. Address: OP03-P05 MD Burst Collapse measured true vertical Packer N/A 5. Permit to Drill Number:2. Operator Name 4. Well Class Before Work: ADL 391283, 388583, 388574, 388572, 388671 Nikaitchuq/Schrader Bluff Oil Pool Eni US Operating Co. Inc. Representative Daily Average Production or Injection Data Casing Pressure Tubing Pressure 308 300519 N/A Length 160 2350' 160Conductor Surface Intermediate 2270 160 324-018 Sr Pet Eng: Slotted Sr Pet Geo:Sr Res Eng: WINJ WAG 32 Water-BblOil-Bbl 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Gas-Mcf 917 15675 205 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 637 192 Slotted p k ft t Fra O s 208 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 o Iannucci 4/ By Samantha Coldiron at 8:45 am, Apr 15, 2024 DSR-4/23/24 RBDMS JSB 041824 2-7/8" 6.4# L80 W563 Production TubingHAL 5-½” Oil Swell PackerOP03-P05Dual Lateral Producer with ESP LiftNikaitchuq Field- Oliktok Point5-½” Silver Bullet Ecc. Nose Guide ShoeAs BuiltMarch 2024 Interm. Casing 9-5/8", 47#5,960' MD, 3,686' TVD82º Inc.Slotted Liner,5-½” 17 ppf12,368' MD, 3,934' TVD90º Inc.5,735' MD – 3,644' TVD, Baker SLXP Liner Hanger/PackerSurf. Casing13-3/8", 68 # 2,351' MD, 2,158' TVD48º Inc.XO 1 jt of 4-½” tubing, XN nipple XO to 2-7/8” tubing 5,473' MD / 3,558' TVD Bottom of 2-7/8" 7.9# L-80 IBT-M Velocity String5,460' MD, 3,553' TVDL1 - Baker SLXP Liner Hanger/Packer5-½” Silver Bullet Ecc. Nose Guide Shoe with Bent Joint12,385' MDHAL 5-½” Oil Swell Packer5,626-5,643' MD, Casing Exit WindowTD of 8 ½” OH12,391' MD, 3,933' TVD 89º Inc.Item (Upper Lateral) MD (ft)5 1/2" Oil Swell Pck #1 5,661'5 1/2" Oil Swell Pck #2 6,053'5 1/2" Oil Swell Pck #3 7,409'5 1/2" Oil Swell Pck #4 7,738'5 1/2" Oil Swell Pck #5 8,107'5 1/2" Oil Swell Pck #6 9,509'5 1/2" Oil Swell Pck #7 10,199'5-½” 15.5 ppf Slotted LinerWellhead: Vault MB-247 5K5,382' MD / 3,523' TVD 9-5/8" 47-53.5# HES Packer5264' MD / 3477' TVD Discharge Gauge5268' MD / 3479' TVD Pump 2 Flex 275286' MD / 3486' TVD Pump 15296' MD / 3489' TVD Gas Separator 538GS5301' MD / 3491' TVD Intake5302' MD / 3492' TVD Upper Seal5309' MD / 3494' TVD Lower Seal5316' MD / 3497' TVD Motor 562XP5341' MD / 3507' TVD Bottom of Shroud5355' MD Top of Middle Completionx-cplg cable clamps, for ESP Power Cable, (2ea) 3/8" Chem Inj Line with 2500 psi check valve at bottom Well Name: OP03-P05 OR Wellbore Name: Original Hole Well Code: 22827 Job: WORKOVER WCEI Level: N/A Daily Report Date: 3/10/2024 Report #: 1 Page: 1 of 1 Well Header Permit/Concession N° ADL-388583 Operator ENI PETROLEUM Subsidiary ENI Petroleum Co. Inc. Initial Lahee Code DEVELOPMENT WELL Rotary Table Elevation (ft) 41.00 Ground Level (ft) 40.00 First Flange (ft) 31.57 RKB - Base Flange (ft) 9.43 RKB - Tubing Spool (ft) 8.85 Rig Information Rig Name RIG 4 Contractor NORDIC CALISTA Rig Type LAND RIG Rig Num 0981 Daily Information Weather Clear Temperature (°F) -42.0 Wind SW @ 13 MPH Days LTI (days) 2,376.00 Days RI (days) POB 41.0 Daily Summary Operations 24h Forecast Prepare to move rig to OP03-P05 when ambient temperature is above -35°F cold weather restriction. Loader operations to scrap / level location and lay rig mats on containment for rig move. 24h Summary Prepare to move rig to OP03-P05. Unable to perform loader operations due to ambient temperature below -35°F cold weather restriction. Offload fluid from mud pits. Disconnect high line power and put rig on generator power. Cleanout cuttings box with super sucker. Perform rig maintenance. Operation at 07.00 Cold weather stand down. Time Log Start Time End Time Dur (hr) Cum Dur (hr)Phase Opr. Act. Plan Oper. Descr. 00:00 00:00 24.00 24.00 MOB A 2 TW01 Prepare to move rig to OP03-P05. Unable to perform loader operations due to ambient temperature below -35°F cold weather restriction. Perform non-critical operations. Offload fluid from mud pits. Perform rig equipment and shop inventory list. Service catwalk. Inspect top drive saver sub and replace. Disconnect high line power and put rig on generator power. Cleanout cuttings box with super sucker. Daily Contacts Position Contact Name Company Title Email Office Mobile Company Representative Tim Ashley ASRC Energy Services Company Man OPPdiilling@eni.com 907-685-0710 Company Representative Paul Dillon ASRC Energy Services Company Man paul.dillon@external.eni.com 907-685-0710 Company Representative Adam Groendyke ASRC Energy Services Clerk AkRigClerksDoyon15@eni.com 907-685-0722 Safety Representative Lonnie Kalar ASRC Energy Services HSE lonnie.karlar@external.eni.com 812-968-4595 Tool Push John Kelly Nordic Toolpusher rigmanager.rig4@nordic-calista.com 907-685-1470 Tool Push Nathan Woods Nordic Toolpusher rigmanager.rig4@nordic-calista.com 907-685-1470 Safety Representative David Fleming Nordic HSE David.Fleming@nordic-calista.com 907-685-8603 Safety Representative Derek Sutherland Nordic HSE 907-685-8603 Last Casing Seat Cas. Type OD (in) ID (in) Grade Top (ftKB) Bottom (ftKB) TVD Bot. (ftKB) Landing Date LINER 5 1/2 4.89 L-80 908.4 12,368.0 3,971.9 12/25/2008 Well Name: OP03-P05 OR Wellbore Name: Original Hole Well Code: 22827 Job: WORKOVER WCEI Level: N/A Daily Report Date: 3/11/2024 Report #: 2 Page: 1 of 1 Well Header Permit/Concession N° ADL-388583 Operator ENI PETROLEUM Subsidiary ENI Petroleum Co. Inc. Initial Lahee Code DEVELOPMENT WELL Rotary Table Elevation (ft) 41.00 Ground Level (ft) 40.00 First Flange (ft) 31.57 RKB - Base Flange (ft) 9.43 RKB - Tubing Spool (ft) 8.85 Rig Information Rig Name RIG 4 Contractor NORDIC CALISTA Rig Type LAND RIG Rig Num 0981 Daily Information Weather Clear Temperature (°F) -36.0 Wind W @ 7 MPH Days LTI (days) 2,377.00 Days RI (days) POB 39.0 Daily Summary Operations 24h Forecast Continue preparing to move rig to OP03-P05. Loader operations to scrap / level location and lay rig mats on containment for rig move. 24h Summary Prepare to move rig to OP03-P05. Unable to perform loader operations due to ambient temperature below -35°F cold weather restriction. Resume rig operations. Scratch and prepare pad for rig mats / rig move. Move 243 joints of 4.5” used tubing from location. Spot in crane to remove ESP spool from rig floor. Operation at 07.00 Moving rig to OP03-P05. Time Log Start Time End Time Dur (hr) Cum Dur (hr)Phase Opr. Act. Plan Oper. Descr. 00:00 14:00 14.00 14.00 MOB A 22 TW01 Prepare to move rig to OP03-P05. Unable to perform loader operations due to ambient temperature below -35°F cold weather restriction. Housekeeping. Repair service loop protection sheath. 14:00 00:00 10.00 24.00 MOB A 2 P Prepare to move rig to OP03-P05. Coordinated with logistics to scratch the pad and move 243 joints of used 4.5” tubing over to Airforce Pad that was blocking access to rig mats. Spot in Worley crane and prepare to pick ESP spool from rig floor. Daily Contacts Position Contact Name Company Title Email Office Mobile Company Representative Tim Ashley ASRC Energy Services Company Man OPPdiilling@eni.com 907-685-0710 Company Representative Paul Dillon ASRC Energy Services Company Man paul.dillon@external.eni.com 907-685-0710 Company Representative Jody Cornell ASRC Energy Services Company Man OPPdiilling@eni.com 907-685-0710 Company Representative Yelyzaveta Saprykina ASRC Energy Services Clerk AkRigClerksDoyon15@eni.com 907-685-0722 Safety Representative Lonnie Kalar ASRC Energy Services HSE lonnie.karlar@external.eni.com 812-968-4595 Tool Push John Kelly Nordic Toolpusher rigmanager.rig4@nordic-calista.com 907-685-1470 Tool Push Nathan Woods Nordic Toolpusher rigmanager.rig4@nordic-calista.com 907-685-1470 Safety Representative David Fleming Nordic HSE David.Fleming@nordic-calista.com 907-685-8603 Safety Representative Derek Sutherland Nordic HSE 907-685-8603 Last Casing Seat Cas. Type OD (in) ID (in) Grade Top (ftKB) Bottom (ftKB) TVD Bot. (ftKB) Landing Date LINER 5 1/2 4.89 L-80 908.4 12,368.0 3,971.9 12/25/2008 Well Name: OP03-P05 OR Wellbore Name: Original Hole Well Code: 22827 Job: WORKOVER WCEI Level: N/A Daily Report Date: 3/12/2024 Report #: 3 Page: 1 of 1 Well Header Permit/Concession N° ADL-388583 Operator ENI PETROLEUM Subsidiary ENI Petroleum Co. Inc. Initial Lahee Code DEVELOPMENT WELL Rotary Table Elevation (ft) 41.00 Ground Level (ft) 40.00 First Flange (ft) 31.57 RKB - Base Flange (ft) 9.43 RKB - Tubing Spool (ft) 8.85 Rig Information Rig Name RIG 4 Contractor NORDIC CALISTA Rig Type LAND RIG Rig Num 0981 Daily Information Weather Clear Temperature (°F) -30.5 Wind SW @ 7 MPH Days LTI (days) 2,378.00 Days RI (days) POB 39.0 Daily Summary Operations 24h Forecast Continue to install liner and rig mats. Move the rig to OP03-PO5. 24h Summary Prepare to move rig to OP03-P05. Unable to perform loader operations due to ambient temperature below -35°F cold weather restriction. Resume rig operations. Scratch and prepare pad for rig mats / rig. Spot in crane to remove ESP spool from rig floor. Move the rig from the well bay. Install bear gate. Scratch pad, lay down liner and start setting rig mats. Operation at 07.00 Continue to move rig. 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 MOB A 1 P Review lift plan and swap ESP reels on the rig floor. 02:00 07:30 5.50 7.50 MOB A 20 P PJSM. Prep for the rig move. Remove berming from around the rig. Clear snow and ice. Lay mats behind the rig. Scope up BOP enclosure. Install well bay hatch cover. Move rig mats to the off-driller’s side. 07:30 12:00 4.50 12.00 MOB A 22 TW01 Stand by due to ambient temperature below -35°F cold weather restriction. 12:00 13:30 1.50 13.50 MOB A 1 P PJSM for moving the rig. Clean out the walker feet. Pick up stairs on the outside of the rig. Make a complete walk around to check all equipment before moving the rig. 13:30 18:00 4.50 18.00 MOB A 2 P Move the rig away from the well bay. Clean up around well bay and install the bear cage. 18:00 20:45 2.75 20.75 MOB A 1 P Scratch pad in the area for the rig move. Install liner and begin setting rig mats. 20:45 00:00 3.25 24.00 MOB A 22 TW01 Stand by due to ambient temperature below -35°F cold weather restriction. Daily Contacts Position Contact Name Company Title Email Office Mobile Company Representative Tim Ashley ASRC Energy Services Company Man OPPdiilling@eni.com 907-685-0710 Company Representative Jody Cornell ASRC Energy Services Company Man OPPdiilling@eni.com 907-685-0710 Company Representative Yelyzaveta Saprykina ASRC Energy Services Clerk AkRigClerksDoyon15@eni.com 907-685-0722 Safety Representative Rebecca Adams ASRC Energy Services HSE rebecca.adams@external.eni.com 812-968-4595 Tool Push John Kelly Nordic Toolpusher rigmanager.rig4@nordic-calista.com 907-685-1470 Tool Push Nathan Woods Nordic Toolpusher rigmanager.rig4@nordic-calista.com 907-685-1470 Safety Representative David Fleming Nordic HSE David.Fleming@nordic-calista.com 907-685-8603 Safety Representative Derek Sutherland Nordic HSE 907-685-8603 Last Casing Seat Cas. Type OD (in) ID (in) Grade Top (ftKB) Bottom (ftKB) TVD Bot. (ftKB) Landing Date LINER 5 1/2 4.89 L-80 908.4 12,368.0 3,971.9 12/25/2008 Well Name: OP03-P05 OR Wellbore Name: OP03-PO5 Well Code: 22827 Job: WORKOVER WCEI Level: N/A Daily Report Date: 3/13/2024 Report #: 4 Page: 1 of 1 Well Header Permit/Concession N° ADL-388583 Operator ENI PETROLEUM Subsidiary ENI Petroleum Co. Inc. Initial Lahee Code DEVELOPMENT WELL Rotary Table Elevation (ft) 41.00 Ground Level (ft) 40.00 First Flange (ft) 31.57 RKB - Base Flange (ft) 9.43 RKB - Tubing Spool (ft) 8.85 Rig Information Rig Name RIG 4 Contractor NORDIC CALISTA Rig Type LAND RIG Rig Num 0981 Daily Information Weather Overcast Temperature (°F) -27.9 Wind SW @ 16 MPH Days LTI (days) 2,379.00 Days RI (days) POB 40.0 Daily Summary Operations 24h Forecast Bull head and kill well. Set BPV in hanger. Nipple down wellhead and nipple up BOP equipment. Prepare for BOP test. 24h Summary Prepare to move rig to OP03-P05. Unable to perform operations due to ambient temperature below -35°F cold weather restriction. Move the rig to OP03-P05. Berm up around the rig. Spot the cuttings tank and High line electrical shack. Take on brine into the pits. Fluid pack and pressure test surface lines to 3500 psi. Operation at 07.00 Bullhead well. Time Log Start Time End Time Dur (hr) Cum Dur (hr)Phase Opr. Act. Plan Oper. Descr. 00:00 06:00 6.00 6.00 MOB A 22 TW01 Unable to perform operations due to ambient temperature below -35°F cold weather restriction. 06:00 11:00 5.00 11.00 MOB A 2 P Continue with laying out liner and laying matting boards. Move rig to OP03-P05. 11:00 20:30 9.50 20.50 MOB A 20 P Remove old rig mats. Clean up areas after rig move. Berm up around the rig. Taking on brine in the mud pits. Prepare wellhead for bull heading operations. 20:30 22:30 2.00 22.50 MOB A 2 P Worley winch truck arrived on location from SID. Spot the cuttings tank and High line electrical shack. Build berm around cuttings tank. 22:30 00:00 1.50 24.00 MOB M 1 P Fluid pack all surface lines. Prepare to pressure test surface lines to 3500 psi. Daily Contacts Position Contact Name Company Title Email Office Mobile Company Representative Tim Ashley ASRC Energy Services Company Man OPPdiilling@eni.com 907-685-0710 Company Representative Jody Cornell ASRC Energy Services Company Man OPPdiilling@eni.com 907-685-0710 Company Representative Yelyzaveta Saprykina ASRC Energy Services Clerk AkRigClerksDoyon15@eni.com 907-685-0722 Safety Representative Rebecca Adams ASRC Energy Services HSE rebecca.adams@external.eni.com 812-968-4595 Tool Push John Kelly Nordic Toolpusher rigmanager.rig4@nordic-calista.com 907-685-1470 Tool Push Nathan Woods Nordic Toolpusher rigmanager.rig4@nordic-calista.com 907-685-1470 Safety Representative David Fleming Nordic HSE David.Fleming@nordic-calista.com 907-685-8603 Safety Representative Derek Sutherland Nordic HSE 907-685-8603 Last Casing Seat Cas. Type OD (in) ID (in) Grade Top (ftKB) Bottom (ftKB) TVD Bot. (ftKB) Landing Date LINER 5 1/2 4.89 L-80 908.4 12,368.0 3,971.9 12/25/2008 Well Name: OP03-P05 OR Wellbore Name: OP03-PO5 Well Code: 22827 Job: WORKOVER WCEI Level: N/A Daily Report Date: 3/14/2024 Report #: 5 Page: 1 of 1 Well Header Permit/Concession N° ADL-388583 Operator ENI PETROLEUM Subsidiary ENI Petroleum Co. Inc. Initial Lahee Code DEVELOPMENT WELL Rotary Table Elevation (ft) 41.00 Ground Level (ft) 40.00 First Flange (ft) 31.57 RKB - Base Flange (ft) 9.43 RKB - Tubing Spool (ft) 8.85 Rig Information Rig Name RIG 4 Contractor NORDIC CALISTA Rig Type LAND RIG Rig Num 0981 Daily Information Weather Clear Temperature (°F) -38.4 Wind SW @ 12 MPH Days LTI (days) 2,380.00 Days RI (days) POB 42.0 Daily Summary Operations 24h Forecast Nipple up BOPE. Test BOPE as per AOGCC requirements and program. Prepare to pull production pipe. 24h Summary Pressure test surface lines. Bull head and kill well. Monitor pressure build up on the annulus. Bleed off pressure to the bleed tank. Monitor build up. Prepare for 2nd bullhead. Bullhead the IA. Monitor well. Install BPV in hanger. Nipple down tree. Install riser. NU BOPE. Operation at 07.00 Making up test assembly for BOP test. Time Log Start Time End Time Dur (hr) Cum Dur (hr)Phase Opr. Act. Plan Oper. Descr. 00:00 01:30 1.50 1.50 W.O. M 12 P Pressure test surface lines to 250 psi for 5 minutes. Good test. Increase pressure to 3500 psi and had a O-ring on a check valve leak. Made repairs. Pressure test surface lines to 3500 psi for 5 minutes. Good test. Release pressure. 01:30 12:00 10.50 12.00 W.O. M 9 P Current well pressures are as follow: Tubing – 230 psi, Annular A – 364 psi and Annulus B – 125 psi. Begin bull head operations to kill well. Pump 38 bbls 8.6 ppg brine down tubing @ 1.5 BPM and 390 psi average. Tubing pressure @ 14 psi after pump shut off. Swap over and pump 460 bbls 8.6 ppg brine down Annulus A @ 3 BPM and 430 psi average. Shut down pump. IA pressure @ 305, OA @ 140 psi. Monitor well for one hour. IA was 188 psi. Connected to bleed off trailer. Bled off pressure to 15 psi in one hour. Shut in and monitor for 15 minutes. Pressure build up was 22 psi. Tubing pressure is -6 psi. 12:00 14:00 2.00 14.00 W.O. M 8 P Prepare and load brine into the mud pits and prepare to pump 2nd kill on the annulus. 14:00 17:00 3.00 17.00 W.O. M 9 P Start the Bullhead on the annulus with 460 bbls 8.6 ppg brine. Pumping 4 BPM with 100 psi. Initial tubing pressure - 0.2 psi, IA pressure - 43 psi, OA pressure - 140 psi. 17:00 18:00 1.00 18.00 W.O. M 1 P Monitor well pressure for 1 hour with no flow. Tubing pressure @ -1.9 psi. Annulus A @ -13 psi. 18:00 18:30 0.50 18.50 W.O. M 5 P Installed BPV inside hanger with Vault Rep. 18:30 21:30 3.00 21.50 W.O. C 5 P Nipple down production tree. Clean and inspect tubing hanger. Install riser and Vault representative torqued riser Greylock to wellhead. 21:30 00:00 2.50 24.00 W.O. C 5 P Start to nipple up 13-5/8” 5M single ram BOP with 2-7/8” x 5-1/2” variable rams installed. Note: 24 Hour Loss of 8.6 ppg Brine = 751 bbls. Total Loss of 8.6 ppg Brine = 751 bbls. Daily Contacts Position Contact Name Company Title Email Office Mobile Company Representative Tim Ashley ASRC Energy Services Company Man OPPdiilling@eni.com 907-685-0710 Company Representative Jody Cornell ASRC Energy Services Company Man OPPdiilling@eni.com 907-685-0710 Company Representative Yelyzaveta Saprykina ASRC Energy Services Clerk AkRigClerksDoyon15@eni.com 907-685-0722 Safety Representative Rebecca Adams ASRC Energy Services HSE rebecca.adams@external.eni.com 812-968-4595 Tool Push John Kelly Nordic Toolpusher rigmanager.rig4@nordic-calista.com 907-685-1470 Tool Push Nathan Woods Nordic Toolpusher rigmanager.rig4@nordic-calista.com 907-685-1470 Safety Representative David Fleming Nordic HSE David.Fleming@nordic-calista.com 907-685-8603 Safety Representative Derek Sutherland Nordic HSE 907-685-8603 Last Casing Seat Cas. Type OD (in) ID (in) Grade Top (ftKB) Bottom (ftKB) TVD Bot. (ftKB) Landing Date LINER 5 1/2 4.89 L-80 908.4 12,368.0 3,971.9 12/25/2008 Well Name: OP03-P05 OR Wellbore Name: OP03-PO5 Well Code: 22827 Job: WORKOVER WCEI Level: N/A Daily Report Date: 3/15/2024 Report #: 6 Page: 1 of 1 Well Header Permit/Concession N° ADL-388583 Operator ENI PETROLEUM Subsidiary ENI Petroleum Co. Inc. Initial Lahee Code DEVELOPMENT WELL Rotary Table Elevation (ft) 41.00 Ground Level (ft) 40.00 First Flange (ft) 31.57 RKB - Base Flange (ft) 9.43 RKB - Tubing Spool (ft) 8.85 Rig Information Rig Name RIG 4 Contractor NORDIC CALISTA Rig Type LAND RIG Rig Num 0981 Daily Information Weather Clear Temperature (°F) -34.4 Wind SW @ 9 MPH Days LTI (days) 2,381.00 Days RI (days) POB 44.0 Daily Summary Operations 24h Forecast Pull hanger. Pull out of the hole with production tubing and ESP assembly. 24h Summary Nipple up BOPE. Test BOPE as per AOGCC requirements. Rig down test assembly. Cut and slip drill line. Trouble shoot and repair PECO operating system. Operation at 07.00 Terminate ESP cable from hanger. Time Log Start Time End Time Dur (hr) Cum Dur (hr)Phase Opr. Act. Plan Oper. Descr. 00:00 02:30 2.50 2.50 W.O. C 1 P Lift rig with hydraulic walking feet to allow clearance to install 13-5/8” 5M double ram BOP and annular with bridge crane. 02:30 06:00 3.50 6.00 W.O. C 5 P Torque 13-5/8” 5M double ram and single ram BOP bolts. Make up primary and secondary choke and kill lines. Torque all connections to spec. Center stack with rotary table. Fill pits with 8.6 ppg brine. Rig up test pump. 06:00 08:30 2.50 8.50 W.O. C 1 P Rig up BOP test assembly. Fluid pack all lines and fill BOP. 08:30 17:00 8.50 17.00 W.O. C 12 P Perform shell test to 3500 psi. Test BOPE as per AOGCC requirements with 2-7/8” and 4” test joints to 250 psi low, 3500 psi high. Test all components to 250 PSI low and 3,500 PSI high for 5 charted minutes. Good test. Witness waived by AOGCC rep Austin McCloud. 17:00 19:00 2.00 19.00 W.O. C 1 P Rig down test equipment and blow down testing lines. Clean up rig floor. 19:00 21:30 2.50 21.50 W.O. M 1 P Cut and slip 90’ of drilling line and slip on same. During the process, the PECO computer system completed an update and disabled the operating system. 21:30 23:30 2.00 23.50 W.O. M 20 U Trouble shoot PECO operating system with rig electrician. PECO system updated and disabled operating controls. Electrician logged into system and enabled operating parameters. 23:30 00:00 0.50 24.00 W.O. M 1 P Spool up drill line and calibrate top drive. Note: 24 Hour Loss of 8.6 ppg Brine = 18 bbls. Total Loss of 8.6 ppg Brine = 769 bbls. Daily Contacts Position Contact Name Company Title Email Office Mobile Company Representative Justin Hays ASRC Energy Services Company Man OPPdiilling@eni.com 907-685-0710 Company Representative Jody Cornell ASRC Energy Services Company Man OPPdiilling@eni.com 907-685-0710 Company Representative Yelyzaveta Saprykina ASRC Energy Services Clerk AkRigClerksDoyon15@eni.com 907-685-0722 Safety Representative Rebecca Adams ASRC Energy Services HSE rebecca.adams@external.eni.com 812-968-4595 Tool Push John Kelly Nordic Toolpusher rigmanager.rig4@nordic-calista.com 907-685-1470 Tool Push Nathan Woods Nordic Toolpusher rigmanager.rig4@nordic-calista.com 907-685-1470 Safety Representative David Fleming Nordic HSE David.Fleming@nordic-calista.com 907-685-8603 Safety Representative Derek Sutherland Nordic HSE 907-685-8603 Last Casing Seat Cas. Type OD (in) ID (in) Grade Top (ftKB) Bottom (ftKB) TVD Bot. (ftKB) Landing Date LINER 5 1/2 4.89 L-80 908.4 12,368.0 3,971.9 12/25/2008 Well Name: OP03-P05 OR Wellbore Name: OP03-PO5 Well Code: 22827 Job: WORKOVER WCEI Level: N/A Daily Report Date: 3/16/2024 Report #: 7 Page: 1 of 1 Well Header Permit/Concession N° ADL-388583 Operator ENI PETROLEUM Subsidiary ENI Petroleum Co. Inc. Initial Lahee Code DEVELOPMENT WELL Rotary Table Elevation (ft) 41.00 Ground Level (ft) 40.00 First Flange (ft) 31.57 RKB - Base Flange (ft) 9.43 RKB - Tubing Spool (ft) 8.85 Rig Information Rig Name RIG 4 Contractor NORDIC CALISTA Rig Type LAND RIG Rig Num 0981 Daily Information Weather Clear Temperature (°F) -33.0 Wind NW @ 3 MPH Days LTI (days) 2,382.00 Days RI (days) POB 42.0 Daily Summary Operations 24h Forecast Inspect and disassemble ESP assembly. Remove pipe from pipe shed. Clean up rig floor and prepare for possible cleanout run. 24h Summary MIRU GBR, Vault and Baker Centrilift equipment. Remove BPV from tubing hanger and back out lock down pins with Vault representative. Pull out of the hole laying down 2 7/8” tubing. Operation at 07.00 Cleaning the rig and pipe shed from ESP equipment. Time Log Start Time End Time Dur (hr) Cum Dur (hr)Phase Opr. Act. Plan Oper. Descr. 00:00 02:30 2.50 2.50 W.O. L 1 P PJSM. MIRU GBR, Vault and Baker Centrilift equipment. 02:30 04:00 1.50 4.00 W.O. L 9 P Pull out of the hole with blanking plug. Attempted to remove BPV from hanger with Vault representative. Seen fluid movement in pipe when releasing BPV. RU and pump 35 bbls 8.6 ppg Brine down tubing to ensure well is dead. Remove BPV from hanger. Back out pins from hanger. 04:00 06:00 2.00 6.00 W.O. L 20 P Hold "Kick while tripping" drill. Pull tubing hanger with 87K without block and top drive, 130K total hook load. Pick up tubing hanger to rig floor. Monitor well for 1 hour. Terminate control line and ESP cable from hanger while filling the hole with 10 BBLS/hour of 8.6 ppg 3% KCL brine. 06:00 12:00 6.00 12.00 W.O. L 4 P Pull out of the hole laying down 2 7/8” BTS-6 13CR 7.9PPF production tubing from 5,382’ MD to 4,970’ MD. Pick up weight 80K. Fill the hole with 10 BBLS / hour of 8.6 ppg 3% KCL brine. 12:00 21:00 9.00 21.00 W.O. L 4 P Continue pulling out of the hole laying down 2 7/8” BTS-6 13CR 7.9PPF production tubing from 4,970’ MD to 1,500’ MD. Pick up weight 63K. Fill the hole with 10 BBLS / hour of 8.6 ppg 3% KCL brine. 21:00 00:00 3.00 24.00 W.O. L 4 P Continue pulling out of the hole laying down 2 7/8” BTS-6 13CR 7.9PPF production tubing from 1,500’ MD to 100’ MD. Fill the hole with 10 BBLS / hour of 8.6 ppg 3% KCL brine. Note: 24 Hour Loss of 8.6 ppg Brine = 135 bbls. Total Loss of 8.6 ppg Brine = 904 bbls. Daily Contacts Position Contact Name Company Title Email Office Mobile Company Representative Justin Hays ASRC Energy Services Company Man OPPdiilling@eni.com 907-685-0710 Company Representative Jody Cornell ASRC Energy Services Company Man OPPdiilling@eni.com 907-685-0710 Company Representative Yelyzaveta Saprykina ASRC Energy Services Clerk AkRigClerksDoyon15@eni.com 907-685-0722 Safety Representative Rebecca Adams ASRC Energy Services HSE rebecca.adams@external.eni.com 812-968-4595 Tool Push John Kelly Nordic Toolpusher rigmanager.rig4@nordic-calista.com 907-685-1470 Tool Push Nathan Woods Nordic Toolpusher rigmanager.rig4@nordic-calista.com 907-685-1470 Safety Representative David Fleming Nordic HSE David.Fleming@nordic-calista.com 907-685-8603 Safety Representative Derek Sutherland Nordic HSE 907-685-8603 Last Casing Seat Cas. Type OD (in) ID (in) Grade Top (ftKB) Bottom (ftKB) TVD Bot. (ftKB) Landing Date LINER 5 1/2 4.89 L-80 908.4 12,368.0 3,971.9 12/25/2008 Well Name: OP03-P05 OR Wellbore Name: OP03-PO5 Well Code: 22827 Job: WORKOVER WCEI Level: N/A Daily Report Date: 3/17/2024 Report #: 8 Page: 1 of 1 Well Header Permit/Concession N° ADL-388583 Operator ENI PETROLEUM Subsidiary ENI Petroleum Co. Inc. Initial Lahee Code DEVELOPMENT WELL Rotary Table Elevation (ft) 41.00 Ground Level (ft) 40.00 First Flange (ft) 31.57 RKB - Base Flange (ft) 9.43 RKB - Tubing Spool (ft) 8.85 Rig Information Rig Name RIG 4 Contractor NORDIC CALISTA Rig Type LAND RIG Rig Num 0981 Daily Information Weather Clear Temperature (°F) -22.2 Wind NE @ 25 MPH Days LTI (days) 2,383.00 Days RI (days) POB 45.0 Daily Summary Operations 24h Forecast Load and process 2 7/8” tubing for upper completion. Pick up ESP assembly. Pick up and run in the hole with upper completion. 24h Summary Pull out of the hole, inspect, and lay down ESP assembly. Box up and remove ESP assemblies. Remove pipe from pipe shed. Clean, clear, and prep rig floor and pipe shed to run upper completion. Expedite 2 7/8” 563 from Air Force pad to location. Start loading the pipe shed and processing 2-7/8” 563 tubing. Operation at 07.00 Processing 2-7/8” 563 tubing. Time Log Start Time End Time Dur (hr) Cum Dur (hr)Phase Opr. Act. Plan Oper. Descr. 00:00 04:00 4.00 4.00 W.O. L 4 P Continue to pull out of the hole from 100’ to ESP assembly. Inspect and lay down ESP assembly. 167 cable clamps recovered. 04:00 12:00 8.00 12.00 W.O. L 1 P Box up and remove ESP assemblies. Remove pipe from pipe shed. Clean and clear rig floor and pipe shed. 12:00 00:00 12.00 24.00 W.O. M 1 P Continue removing pipe from pipe shed. Continue Cleaning and clearing the rig floor and pipe shed. Expedite 2 7/8” 563 tubing from Air Force pad to location. Start loading pipe shed and process 2-7/8” 563 tubing. Daily Contacts Position Contact Name Company Title Email Office Mobile Company Representative Justin Hays ASRC Energy Services Company Man OPPdiilling@eni.com 907-685-0710 Company Representative Jody Cornell ASRC Energy Services Company Man OPPdiilling@eni.com 907-685-0710 Company Representative Yelyzaveta Saprykina ASRC Energy Services Clerk AkRigClerksDoyon15@eni.com 907-685-0722 Safety Representative Rebecca Adams ASRC Energy Services HSE rebecca.adams@external.eni.com 812-968-4595 Tool Push John Kelly Nordic Toolpusher rigmanager.rig4@nordic-calista.com 907-685-1470 Tool Push Nathan Woods Nordic Toolpusher rigmanager.rig4@nordic-calista.com 907-685-1470 Safety Representative David Fleming Nordic HSE David.Fleming@nordic-calista.com 907-685-8603 Safety Representative Derek Sutherland Nordic HSE 907-685-8603 Last Casing Seat Cas. Type OD (in) ID (in) Grade Top (ftKB) Bottom (ftKB) TVD Bot. (ftKB) Landing Date LINER 5 1/2 4.89 L-80 908.4 12,368.0 3,971.9 12/25/2008 Well Name: OP03-P05 OR Wellbore Name: OP03-PO5 Well Code: 22827 Job: WORKOVER WCEI Level: N/A Daily Report Date: 3/18/2024 Report #: 9 Page: 1 of 1 Well Header Permit/Concession N° ADL-388583 Operator ENI PETROLEUM Subsidiary ENI Petroleum Co. Inc. Initial Lahee Code DEVELOPMENT WELL Rotary Table Elevation (ft) 41.00 Ground Level (ft) 40.00 First Flange (ft) 31.57 RKB - Base Flange (ft) 9.43 RKB - Tubing Spool (ft) 8.85 Rig Information Rig Name RIG 4 Contractor NORDIC CALISTA Rig Type LAND RIG Rig Num 0981 Daily Information Weather Clear Temperature (°F) -10.5 Wind NE @ 29 MPH Days LTI (days) 2,384.00 Days RI (days) POB 46.0 Daily Summary Operations 24h Forecast Pick up and run in the hole with upper completion. ND BOPE. NU wellhead. Perform passport test. 24h Summary MIRU Worley crane. Swap out old spools and replace them with new spools. Load and process 2 7/8” 563 tubing in pipe shed for upper completion. PU and assemble ESP pump and motor assembly. Perform control line splice to ESP pump. Pressure test control line and check valve. Operation at 07.00 Run in hole with 2 7/8" completion. Time Log Start Time End Time Dur (hr) Cum Dur (hr)Phase Opr. Act. Plan Oper. Descr. 00:00 06:00 6.00 6.00 W.O. K 1 P Held lift plan meeting. MIRU Worley crane. Swap out old ESP and CT spools and replace with new spools. RDMO Worley crane. 06:00 12:00 6.00 12.00 W.O. K 1 P Continue to load and process 2 7/8” 563 tubing in pipe shed for upper completion. RU Baker Centrilift floor equipment. 12:00 17:30 5.50 17.50 W.O. K 5 P PJSM. Bring remaining ESP equipment into the pipe shed. Pick up and assemble ESP pump and motor assembly. 17:30 22:00 4.50 22.00 W.O. K 12 P Perform Baker splice for control line to ESP pump. Fill control line and pressure test control line as follows: 500 psi for 10 minutes, 1000 psi for 10 minutes and 4200 psi and test check valve. Release pressure. Good test. RD testing equipment. 22:00 00:00 2.00 24.00 W.O. K 1 P Remove sand guard and make corrections to the tubing tally. Prepare to perform electrical splice on ESP cable. Daily Contacts Position Contact Name Company Title Email Office Mobile Company Representative Justin Hays ASRC Energy Services Company Man OPPdiilling@eni.com 907-685-0710 Company Representative Jody Cornell ASRC Energy Services Company Man OPPdiilling@eni.com 907-685-0710 Company Representative Yelyzaveta Saprykina ASRC Energy Services Clerk AkRigClerksDoyon15@eni.com 907-685-0722 Safety Representative Rebecca Adams ASRC Energy Services HSE rebecca.adams@external.eni.com 812-968-4595 Tool Push John Kelly Nordic Toolpusher rigmanager.rig4@nordic-calista.com 907-685-1470 Tool Push Nathan Woods Nordic Toolpusher rigmanager.rig4@nordic-calista.com 907-685-1470 Safety Representative David Fleming Nordic HSE David.Fleming@nordic-calista.com 907-685-8603 Safety Representative Derek Sutherland Nordic HSE 907-685-8603 Last Casing Seat Cas. Type OD (in) ID (in) Grade Top (ftKB) Bottom (ftKB) TVD Bot. (ftKB) Landing Date LINER 5 1/2 4.89 L-80 908.4 12,368.0 3,971.9 12/25/2008 Well Name: OP03-P05 OR Wellbore Name: OP03-PO5 Well Code: 22827 Job: WORKOVER WCEI Level: N/A Daily Report Date: 3/19/2024 Report #: 10 Page: 1 of 1 Well Header Permit/Concession N° ADL-388583 Operator ENI PETROLEUM Subsidiary ENI Petroleum Co. Inc. Initial Lahee Code DEVELOPMENT WELL Rotary Table Elevation (ft) 41.00 Ground Level (ft) 40.00 First Flange (ft) 31.57 RKB - Base Flange (ft) 9.43 RKB - Tubing Spool (ft) 8.85 Rig Information Rig Name RIG 4 Contractor NORDIC CALISTA Rig Type LAND RIG Rig Num 0981 Daily Information Weather Clear Temperature (°F) -11.4 Wind NE @ 12 MPH Days LTI (days) 2,385.00 Days RI (days) POB 44.0 Daily Summary Operations 24h Forecast Pick up hanger and install penetrator. Test ESP and chemical injection line. Land hanger, run in lock down screws and test hanger void. Nipple down BOPE. Nipple up tree. Perform passport test. 24h Summary Splice ESP cable to Motor lead and test. Rig up 2 7/8” handling equipment. Pick up and run in the hole with 2 7/8” upper completion. Circulate tubing volume. Operation at 07.00 Test ESP and chemical injection line. Time Log Start Time End Time Dur (hr) Cum Dur (hr)Phase Opr. Act. Plan Oper. Descr. 00:00 05:00 5.00 5.00 W.O. K 1 P Perform electrical splice and test ESP assembly at 74’ MD. Rig up GBR tubing handling equipment and hydraulic power tongs. Fill hole at 10 BBL/hour with 8.6 ppg 3% KCL brine. 05:00 12:00 7.00 12.00 W.O. K 4 P Run in the hole with 2-7/8” W563 ESP upper completion from 74’ MD to 2,715’ MD. Perform electrical test of ESP every 1,000’. Fill hole at 10 BBL/hour with 8.6 ppg 3% KCL brine. 12:00 15:00 3.00 15.00 W.O. K 4 P Continue running in the hole with 2-7/8” W563 ESP upper completion from 2,715’ MD to 3,211’MD. Perform electrical test of ESP every 1,000’. Pump a tubing volume at 1 BPM with 100 PSI. Pumped 15 total BBLS. 15:00 22:00 7.00 22.00 W.O. K 4 P Continue running in the hole with 2-7/8” W563 ESP upper completion from 3211’ MD to 5,284’ MD. Perform electrical test of ESP every 1,000’. Pump a tubing volume at 1 BPM with 100 PSI. Pumped 15 total BBLS. Fill hole at 10 BBL/hour with 8.6 ppg 3% KCL brine. 22:00 00:00 2.00 24.00 W.O. K 5 P Make up 4.5” x 2-7/8” X-over, 4.5” swivel jt and MB-247 13-1/2” x 4-1/2” tubing hanger. Fill hole at 10 BBL/hour with 8.6 ppg 3% KCL brine. Note: 24 Hour Loss of 8.6 ppg Brine = 302 bbls. Total Loss of 8.6 ppg Brine = 1820 bbls. Daily Contacts Position Contact Name Company Title Email Office Mobile Company Representative Justin Hays ASRC Energy Services Company Man OPPdiilling@eni.com 907-685-0710 Company Representative Jody Cornell ASRC Energy Services Company Man OPPdiilling@eni.com 907-685-0710 Company Representative Yelyzaveta Saprykina ASRC Energy Services Clerk AkRigClerksDoyon15@eni.com 907-685-0722 Safety Representative Rebecca Adams ASRC Energy Services HSE rebecca.adams@external.eni.com 812-968-4595 Tool Push John Kelly Nordic Toolpusher rigmanager.rig4@nordic-calista.com 907-685-1470 Tool Push Sean Stuckart Nordic Toolpusher rigmanager.rig4@nordic-calista.com 907-685-1470 Safety Representative David Fleming Nordic HSE David.Fleming@nordic-calista.com 907-685-8603 Safety Representative Jon Castle Nordic HSE 907-685-8603 Last Casing Seat Cas. Type OD (in) ID (in) Grade Top (ftKB) Bottom (ftKB) TVD Bot. (ftKB) Landing Date LINER 5 1/2 4.89 L-80 908.4 12,368.0 3,971.9 12/25/2008 Well Name: OP03-P05 OR Wellbore Name: OP03-PO5 Well Code: 22827 Job: WORKOVER WCEI Level: N/A Daily Report Date: 3/20/2024 Report #: 11 Page: 1 of 1 Well Header Permit/Concession N° ADL-388583 Operator ENI PETROLEUM Subsidiary ENI Petroleum Co. Inc. Initial Lahee Code DEVELOPMENT WELL Rotary Table Elevation (ft) 41.00 Ground Level (ft) 40.00 First Flange (ft) 31.57 RKB - Base Flange (ft) 9.43 RKB - Tubing Spool (ft) 8.85 Rig Information Rig Name RIG 4 Contractor NORDIC CALISTA Rig Type LAND RIG Rig Num 0981 Daily Information Weather Clear Temperature (°F) 1.9 Wind NE 18 MPH Days LTI (days) 2,386.00 Days RI (days) POB 46.0 Daily Summary Operations 24h Forecast Rig down, prepare and move rig to OP18-08. 24h Summary Pick up hanger and install penetrator. Test ESP and chemical injection line. Land hanger, run in lock down screws, and test hanger void. Set 2-way check, nipple down BOPE. Nipple up tree. Perform passport test. Perform final ESP cable electrical integrity test with Baker Centrilift, good test. Hand well over to Production group. Rig released at 2400 HRS on 3/20/2024. No further reports. Operation at 07.00 Final report. No further operation. 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 W.O. K 12 P Pick up the tubing hanger and make up swivel. Perform pressure test on capillary line to 1,000 psi for 10 minutes (good test). Splice ESP cable to pigtail on penetrator. Cut 3/8” control line and cross over to ¼” control line and feed thru hanger. Perform chemical injection valve function test (good test). Test ESP and cap the chemical injection line. Land hanger, run in lock down screws and test upper and lower seals on tubing hanger to 5,000 psi for 10 minutes (good test). 08:30 12:00 3.50 12.00 W.O. K 20 P Pull landing joint and monitor well for 30 min. Rig down GBR casing handling equipment. Set 2-way check valve in hanger. 12:00 14:30 2.50 14.50 W.O. C 5 P Nipple down BOPE. Rig off hi-line power at 13:30 hours. 14:30 15:30 1.00 15.50 W.O. C 5 P Nipple up tree, terminate capillary line and feed ESP cable/penetrator through the tree. 15:30 22:30 7.00 22.50 W.O. C 12 P Perform passport test with Vault representative as procedure. Test swab valve, pressure bleed off, grease valve and retest to 3500 psi for 30 minutes. Good test. Test master valve, pressure bleeding off, grease valve and retest to 3500 psi for 30 minutes. Good test. Remove tree cap pull 2 way check valve, put tree cap back on test cap conection for 10 minutes at 3500 psi. Good test. Rig down test equipment. 22:30 00:00 1.50 24.00 W.O. K 1 P Perform final ESP cable electrical integrity test with Baker Centrilift, good test. Prepare to move rig to OP18-08. Hand well over to Production group. Rig released at 2400 HRS on 3/20/2024. Final report. No further operations. Note: 24 Hour Loss of 8.6 ppg Brine = 69 bbls. Total Loss of 8.6 ppg Brine = 1889 bbls. Daily Contacts Position Contact Name Company Title Email Office Mobile Company Representative Justin Hays ASRC Energy Services Company Man OPPdiilling@eni.com 907-685-0710 Company Representative Jody Cornell ASRC Energy Services Company Man OPPdiilling@eni.com 907-685-0710 Company Representative Yelyzaveta Saprykina ASRC Energy Services Clerk AkRigClerksDoyon15@eni.com 907-685-0722 Safety Representative Jack Potter ASRC Energy Services HSE jack.potter@external.eni.com Tool Push John Kelly Nordic Toolpusher rigmanager.rig4@nordic-calista.com 907-685-1470 Tool Push Sean Stuckart Nordic Toolpusher rigmanager.rig4@nordic-calista.com 907-685-1470 Safety Representative David Fleming Nordic HSE David.Fleming@nordic-calista.com 907-685-8603 Safety Representative Jon Castle Nordic HSE 907-685-8603 Last Casing Seat Cas. Type OD (in) ID (in) Grade Top (ftKB) Bottom (ftKB) TVD Bot. (ftKB) Landing Date LINER 5 1/2 4.89 L-80 908.4 12,368.0 3,971.9 12/25/2008 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:Kyle Karsten To:Regg, James B (OGC); DOA AOGCC Prudhoe Bay; Brooks, Phoebe L (OGC); Enipetroleum OPPDrilling Subject:Rig 4 Revised Bop test Date:Sunday, March 17, 2024 6:22:09 AM Attachments:BOP Test Form 3-15-2024.xlsx Some people who received this message don't often get email from kyle.karsten@nordic-calista.com. Learn why this is important John Kelly Nordic Calista Rig Manager (907)201-1244(cell) (907)670-1407 (Office) This information is intended only for the use of the individual (s) or entity (ies) named above and may contain confidential or privileged information. Any unauthorized disclosure, copying, distribution or the taking of any action in reliance on the contents of this transmitted information is strictly prohibited. If you are not the intended recipient or have received this transmission in error, please immediately delete it and any attachments from your system and send me an email confirming that you have not disclosed, copied, or distributed this message and that you have deleted this message and any attachments from your system. 1LNDLWFKXT233 37' STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION *All BOPE reports are due to the agency within 5 days of testing* SSu bmit to :jim.regg@alaska.gov; AOGCC.Inspectors@alaska.gov; phoebe.brooks@alaska.gov Rig Owner: Rig No.:4 DATE: 3/15/24 Rig Rep.: Rig Email: Operator: Operator Rep.: Op. Rep Email: Well Name:PTD #2081370 Sundry #324-018 Operation: Drilling: Workover: x Explor.: Test: Initial: x Weekly: Bi-Weekly: Other: Rams:250/3500 Annular:250/2500 Valves:250/3500 MASP:1239 MISC. INSPECTIONS: TEST DATA FLOOR SAFETY VALVES: Test Result/Type Test Result Quantity Test Result Housekeeping P Well Sign P Upper Kelly 1P Permit On Location P Hazard Sec.P Lower Kelly 1P Standing Order Posted P Misc.NA Ball Type 2P Test Fluid Water Inside BOP 2P FSV Misc 0NA BOP STACK:Quantity Size/Type Test Result MUD SYSTEM:Visual Alarm Stripper 0NATrip Tank PP Annular Preventer 1 13 5/8'' Hydril P Pit Level Indicators PP #1 Rams 1 BSR P Flow Indicator PP #2 Rams 1 2 7/8''x5 1/2'' VBR P Meth Gas Detector PP #3 Rams 1 2 7/8''x5 1/2'' VBR P H2S Gas Detector PP #4 Rams 0NAMS Misc 0NA #5 Rams 0NA #6 Rams 0NAACCUMULATOR SYSTEM: Choke Ln. Valves 1 3 1/8''P Time/Pressure Test Result HCR Valves 2 3 1/8''P System Pressure (psi)3020 P Kill Line Valves 1 3 1/8''P Pressure After Closure (psi)2050 p Check Valve 0NA200 psi Attained (sec)27 P BOP Misc 0NAFull Pressure Attained (sec)82 P Blind Switch Covers: All stations Yes CHOKE MANIFOLD:Bottle Precharge:P Quantity Test Result Nitgn. Bottles # & psi (Avg.): 4@2,815 P No. Valves 14 P ACC Misc 0NA Manual Chokes 1P Hydraulic Chokes 1P Control System Response Time:Time (sec) Test Result CH Misc 0NA Annular Preventer 13 P #1 Rams 9 P Coiled Tubing Only:#2 Rams 6 P Inside Reel valves 0NA #3 Rams 7 P #4 Rams 0 NA Test Results #5 Rams 0 NA #6 Rams 0 NA Number of Failures:0 Test Time:7.0 HCR Choke 1 P Repair or replacement of equipment will be made within 0 days. HCR Kill 1 P Remarks: AOGCC Inspection 24 hr Notice Yes Date/Time 3/13/24 06:37 am Waived By Test Start Date/Time:3/15/2024 8:30 (date) (time)Witness Test Finish Date/Time:3/15/2024 17:00 BOPE Test Report Notify the AOGCC of repairs with written confirmation to: AOGCC.Inspectors@alaska.gov Austin McLeod Nordic Tested with 2-7/8'' & 4" test joints. Tested gas alarms for all stations. Tested PVT's and flow paddle. Kelly/Stuckart ENI Hays/Cornell Nikaitchuq OP03-P05 Test Pressure (psi): igmanager.rig4@nordic-calista.co OPPdrilling@eni.com Form 10-424 (Revised 08/2022) 2024-0315_BOP_Nordic4_Nikaitchuq_OP03-P5 9 9 9 999 9 9 9 9 9 -5HJJ 1. Type of Request:Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown Suspend Perforate Other Stimulate Pull Tubing Change Approved Program Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing Other:ESP Changeout 2. Operator Name:4. Current Well Class: 5. Permit to Drill Number: Exploratory Development 3. Address:Stratigraphic Service 6. API Number: 7. If perforating:8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Yes No OP03-P05 9. Property Designation (Lease Number):10. Field: 11. Total Depth MD (ft):Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD): 12391 3933 12385 3934 1239 N/A N/A Casing Collapse Structural Conductor Surface 2,270 Intermediate 4,760 Production Liner Slotted Packers and SSSV Type:Packers and SSSV MD (ft) and TVD (ft): 12. Attachments:Proposal Summary Wellbore schematic 13. Well Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations:OIL WINJ WDSPL Suspended 16. Verbal Approval:Date: GAS WAG GSTOR SPLUG AOGCC Representative: GINJ Op Shutdown Abandoned Contact Name: Giorgio Iannucci Contact Email: Contact Phone: Authorized Title: Conditions of approval: Notify AOGCC so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other Conditions of Approval: Post Initial Injection MIT Req'd? Yes No APPROVED BY Approved by: COMMISSIONER THE AOGCC Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng Schrader Bluff Well Operations Project Manager Amjad Chaudhry amjad.chaudhry@eni.com 907-865-3300 N/A Schrader BluffNikaitchuq Subsequent Form Required: Suspension Expiration Date: Will perfs require a spacing exception due to property boundaries? Current Pools: 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name and Digital Signature with Date: Tubing Size: PRESENT WELL CONDITION SUMMARY Length Size AOGCC USE ONLY Slotted Tubing Grade:Tubing MD (ft): 5382' MD , 3523' TVD Perforation Depth TVD (ft): STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL337701, ADL355024, ADL355023, ADL390615 208-137 3700 Centerpoint Drive, Ste. 500, Anchorage, AK 99503 50-029-23396-00-00 Eni US Operating Co. Inc. Proposed Pools: TVD Burst 5224 MD 6,870 5,020 115' 2158' 3686' 115' 2350' 20" 13-3/8" 115' 9-5/8"5960' 2350' 5960' 5960-12368 5-1/2" 3686-3934 1/16/2023 February 2nd, 2024 123686614 4-1/2" 3934 HES, PHL Perforation Depth MD (ft): L-80 m n P s 2 66 t geoueoeouoooooooooooot N Form 10-403 Revised 06/2023 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov ucci ue and the procedure ap By Grace Christianson at 10:02 am, Jan 17, 2024 324-018 ADL373301 SFD VTL 01/24/2024 SFD 1/29/2024 X BOP test to 3500 psig Annular preventer test to 2500 psig X 10-404X DSR-1/26/24*&:JLC 1/31/2024 1/31/24Brett W. Huber, Sr.Digitally signed by Brett W. Huber, Sr. Date: 2024.01.31 15:20:13 -09'00' RBDMS JSB 020124 3700 Centerpoint Drive Suite 500 Anchorage, Alaska 99503 Phone (907) 865-3300 January 16th, 2024 Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Application for Sundry Approval for OP03-P05 Rig Workover Dear Commissioners, ENI US Operating Co. Inc. hereby applies for a Workover Sundry for well OP03-P05. OP03-P05 was completed on Oliktok Point on March 16th, 2014, with an electric submersible pump set at a depth of 5,310’ MD. This ESP producer was completed without a packer. The well was started up for production in March 2014. On July 7th, 2017, an ESP failure occurred and in December 2017 another WO was conducted and ESP was installed. In 2022 the ESP was working but with 50% fluid lift due to excessive sand in the heel area. It was decided to perform a workover and run a middle completion below the ESP setting depth. The WO was conducted in January 2023 and ESP installed. In September 2023 the ESP stopped working because of excessive sand. The plan is to pull the failed ESP out and run a new conventional ESP. We estimate that we can begin this work at the beginning of February 2024. If you have any questions or require further information, please contact Amjad Chaudhry at 907- 865-3300. Sincerely, Giorgio Iannucci Well Operations Project Manager ncerely, OP03-P05 Workover – Summary Page PTD#:208-137 Current Status Well OP03-P05 is currently shut in. Scope of Work The scope of this workover is changing out failed ESP pump. General Well info Reservoir Pressure/TVD: This well is expected to have a static max bottom hole pressure of approximately 1600 psi (3,607’ TVD) during the time of workover. OP03-P05 MASP Shut-in BHP (Max) 1,600 psi, 8.5 ppge Depth 3,607 ft (TVD) Gradient 0.1 psi/ft MASP 1,239 psi Wellhead type/pressure rating: Vault PC, MB-247/5000 psi BOP configuration: Annular/blind/2-7/8” x 5” vbr/4-1/2” pipe rams TIFL/MIT-IA/MIT-OA: Intermediate csg 9 5/8” was tested to 2000 psi on March 26th, 2023. Well type: Producer Estimated start date: February 2nd, 2024. Drilling rig: Nordic 4 Sr. Drilling Engineer: Amjad Chaudhry: amjad.chaudhry@eni.com Well Operations Project Manager: Giorgio Iannucci: Giorgio.Iannucci@eni.com Procedure: 1. MIRU Nordic 4. 2. Circulate 8.6 ppg 3% NaCl/KCl brine through tree. 3. Set BPV. ND tree and NU BOP and test to 3500 psi. 4. POOH and lay down ESP assembly. 5. (Contingent if middle completion to be removed. PU work string and RIH to clean out inside of 5-1/2” liner. POOH and LD the BHA. PU new middle completion and RIH and set at +/- 5,380’ MD). 6. MU new ESP assembly and RIH to setting depth. 7. Land hanger and test it. 8. Install BPV and nipple down BOP. 9. NU tubing adapter and tree. 10. Pull BPV, install test plug and test tree. (5000 psi test) 11. Circulate Freeze protect through tree down IA. 12. Shut in well. 13. RDMO Below the current schematic of the well: Proposed Schematic will be the same with ESP setting depth can be +/- 100’ Up d a t e d : 2 / 2 8 / 1 8 Re v i s i o n : 7 Up d a t e d B y : B W Ri g # 4 F l o w p a t h D i a g r a m PI P E R A M S BL I N D / S H E A R R A M S VB R R A M S BU F F E R T A N K M M 7 MM 8 M M 9 MM 6 MM 5 M M 2 M M 4 MU D G A S SE P E R A T O R SH A K E R #2 SH A K E R #1 AN N U L A R MM 1 MM 1 0 MM 3 MM 1 4 PL U G V A L V E CU T T I N G S B O X MM 1 1 MM 1 2 SP A R E CI R C LI N E MM 1 3 FI L L U P LI N E FV - 1 2" ST A N D P I P E 2" B L E E D E R TO P I T S TO P DR I V E GA U G E T R E E CA P P E D A T E N D 3" 5 , 0 0 0 P S I W P K I L L LI N E CM 1 CM 2 CM 3 CM 4 CM 5 CM 6 CM 7 CM 8 CM 9 CM 1 0 CM 1 1 CM 1 2 CM 1 3 CM 1 4 CM 1 5 MA N U A L CH O K E CM 1 6 RE M O T E A C T U A T E D MP 2 MM 1 5 MA N U A L CH O K E MM G A 1 MM G A 2 MM SN 1 MM SN 2 SN 1 SN 2 CM G A 1 FL O W B A C K T A N K UK C ( A C T U A T E D ) LK C ( M A N U A L ) TO MGS TO S H A K E R MP 1 OP E N P O R T CA P P E D 3-1/ 8 " 5 , 0 0 0 P S I W P C H O K E M A N I F O L D Dr i l l i n g Ri s e r : 1 3 - 5M Fl a n g e x H u b KI L L HC R IN S I D E KI L L CH O K E HC R MA N U A L CH O K E 3" 5 , 0 0 0 P S I W P C H O K E LI N E DV - 1 SP - 1 CV - 1 FB - 1 12 " F l o w l i n e 8" v e n t l i n e 20 ' l o n g PR V 1 Pi t 4 PR V 2 Pi t 4 Sp a c e r Sp o o l : 1 3 - 5M F l a n g e x Fl a n g e Ri g N o r d i c # 4 S t a c k m e a s u r e m e n t s No t e : T o b e c o n f i r m e d w h e n r i g g e d u p To p F l a n g e Up p e r L o c k D o w n S c r e w s Ro t a r y T a b l e 8’ 5 ” 13 ’ 2 ” 14 ’ 3 ” 34 ’ t o GL (N o r d i c Ri g 4 RK B 33 . 5 ’ + 6” m a t s ) 24 ’ 9 ” 25 ’ 3 ” 29 . 5 ” 85 ” RI S E R 16 ’ 4 ” P r o j e c t e d KI L L L I N E CH O K E L I N E TO P O F W E L L H O U S E 13 ’ 1 0 ” t o G L 4- 1 / 2 ” p i p e r a m s 2- 7 / 8 ” x 5 ” V B R r a m s STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION BOPE Test Report for: Reviewed By: P.I. Suprv Comm ________NIKAITCHUQ OP03-P05 JBR 04/27/2023 MISC. INSPECTIONS: FLOOR SAFTY VALVES:CHOKE MANIFOLD:BOP STACK: ACCUMULATOR SYSTEM:MUD SYSTEM: P/F P/F P/FP/FP/F Visual Alarm QuantityQuantity Time/Pressure SizeQuantity Number of Failures:5 During initial walk down of Nordic 4 BOPE test found IA shut in with a 2000-pound analog gauge reading 0 psi. Opened to digital gauge and found 0.76 psi on IA. Contacted ENI Production and Nordic to bleed well pressure and put a crystal digital gauge on IA. Bled for several hours to outside bleed trailer until on vac, then winged in IA for 5 min and watched for buildup - no build up on pressure. Open wing and give go ahead to continue testing. Between tests 2 and 3 while changing test joint to 2 7/8 the IA started to pressure up again. Stop test, re-rig bleed set up with 2” hose to bleed tank - no fluid was witnessed. Bled IA until went on Vac. Winged in IA for 5 min buildup test (no gain in pressure). Open wing and give go ahead to continue testing and never had any more issues with IA pressuring up during the rest of the test. Continued test. Upper VBR door seals both leaking. Nordic supervisor elected to change out all door seals, retest and pass. Fail on Annular, change-out bag for good test on new bag. HCR Choke failed; change out HCR Choke and retest (pass). Bad test on MCV and MKV; found door seal leaking on lower VBR; change-out seal, retest and pass . Upper VBR not holding pressure, exercised, and pass. Lower VBR door seal leaking change out found bits of flat pack clamp in lower rams; change element out of precaution retest for pass No other Test Results TEST DATA Rig Rep:Kyle Karsten/Richard TOperator:Eni US Operating Co. Inc.Operator Rep:Jody Cornell/Russ Wimmer Rig Owner/Rig No.:Nordic 4 PTD#:2081370 DATE:3/21/2023 Type Operation:WRKOV Annular: 250/3500Type Test:INIT Valves: 250/3500 Rams: 250/3500 Test Pressures:Inspection No:bopSTS230318064945 Inspector Sully Sullivan Inspector Insp Source Related Insp No: INSIDE REEL VALVES: Quantity P/F (Valid for Coil Rigs Only) Remarks: Test Time 47.5 MASP: 939 Sundry No: 323-025 Control System Response Time (sec) Time P/F Housekeeping:P PTD On Location P Standing Order Posted P Well Sign P Hazard Sec.P Test Fluid W Misc NA Upper Kelly 1 P Lower Kelly 1 P Ball Type 1 P Inside BOP 1 P FSV Misc 0 NA 14 PNo. Valves 1 PManual Chokes 1 PHydraulic Chokes 0 NACH Misc Stripper 0 NA Annular Preventer 1 13 5/8 FP #1 Rams 1 blind /shear P #2 Rams 1 2 7/8 x 5 1/2 v FP #3 Rams 1 2 7/8 x 5 1/2 v P #4 Rams 0 NA #5 Rams 0 NA #6 Rams 0 NA Choke Ln. Valves 1 3 1/8 P HCR Valves 2 3 1/8 FP Kill Line Valves 1 3 1/8 P Check Valve 0 NA BOP Misc 2 ram door seal FP System Pressure P3000 Pressure After Closure P2200 200 PSI Attained P24 Full Pressure Attained P68 Blind Switch Covers:Pall stations Bottle precharge P Nitgn Btls# &psi (avg)P4@2900 ACC Misc NA0 P PTrip Tank P PPit Level Indicators P PFlow Indicator P PMeth Gas Detector P PH2S Gas Detector NA NAMS Misc Inside Reel Valves 0 NA Annular Preventer P13 #1 Rams P5 #2 Rams P5 #3 Rams P5 #4 Rams NA0 #5 Rams NA0 #6 Rams NA0 HCR Choke P1 HCR Kill P1 9 9 9 9 9 9999 9 9 99 9 )XOO5HPDUNVDWWDFKHG FP FP FP FP BOPE Test – Nordic 4 Nikaitchuq OP03-P05 (PTD 2081370) AOGCC Inspection # bopsts230318064945 3/21/2023 REMARKS During initial walk down of Nordic 4 BOPE test found IA shut in with a 2000-pound analog gauge reading 0 psi. Opened to digital gauge and found 0.76 psi on IA. Contacted ENI Production and Nordic to bleed well pressure and put a crystal digital gauge on IA. Bled for several hours to outside bleed trailer until on vac, then winged in IA for 5 min and watched for buildup - no build up on pressure. Open wing and give go ahead to continue testing. Between tests 2 and 3 while changing test joint to 2 7/8 the IA started to pressure up again. Stop test, re-rig bleed set up with 2” hose to bleed tank - no fluid was witnessed. Bled IA until went on Vac. Winged in IA for 5 min buildup test (no gain in pressure). Open wing and give go ahead to continue testing and never had any more issues with IA pressuring up during the rest of the test. Continued test. Upper VBR door seals both leaking. Nordic supervisor elected to change out all door seals, retest for pass. Fail on Annular, change-out bag for good test on new bag. HCR Choke failed; change out HCR Choke and retest (pass). Bad test on MCV and MKV; found door seal leaking on lower VBR; change-out seal, retest for pass. Upper VBR not holding pressure, exercised, and pass. Lower VBR door seal leaking change out, found bits of flat pack clamp in lower rams; change element out of precaution, retest for pass. No other failures. Housekeeping was so good you could eat off the floor. 9 9 9 Uppery VBR door seals both leaking. Fail on Annular, g HCR Choke failed; g door seal leaking on lower VBR; Upper VBR not holding pressure, g Lower VBR door seal leaking 1. Operations Susp Well Insp Plug Perforations Fracture Stimulate Pull Tubing Operations shutdown Performed: Install Whipstock Perforate Other Stimulate Alter Casing Change Approved Program Mod Artificial Lift Perforate New Pool Repair Well Coiled Tubing Ops Other: _ESP Changeout___ Development Exploratory Stratigraphic Service 6. API Number: 7. Property Designation (Lease Number):8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071):10. Field/Pool(s): 11. Present Well Condition Summary: Total Depth measured 12,391 feet N/A feet true vertical 3,933 feet N/A feet Effective Depth measured 12,368 feet 5,382 feet true vertical 3,934 feet 3,523 feet Perforation depth Measured depth 5,960-12,368 feet True Vertical depth 3,686-3,934 feet Tubing (size, grade, measured and true vertical depth)4.5 L-80 5,224' 3,489' Packers and SSSV (type, measured and true vertical depth)HES PHL 5,382' 3,523' 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:Schrader Bluff Oil Pool 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 ,annucci 4/17/2023 Digital Signature with Date:Contact Name:Amjad Chaudhry Contact Email:amjad.chaudhry@eni.com Authorized Title:Well Operations Project Manager Contact Phone:907-865-3379 measured TVD Production Liner 5960 6614 Casing Structural 3686 5.5" 5960 12368 3934 Plugs Junk measured 2350 2158 20" 13.375" Size 160 9.625" Slotted 5020 6870 Burst Collapse 2270 4790 5. Permit to Drill Number:2. Operator Name 4. Well Class Before Work: ADL 391283, 388583, 388574, 388572, 388671 Nikaitchuq/Schrader Bluff Oil Pool Eni US Operating Co. Inc. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 208-137 50-029-23396-00-00 3700 Centerpoint Dr. Ste 500, Anchorage, AK, 99503 3. Address: OP03-P05 MD 191 measured true vertical Packer Representative Daily Average Production or Injection Data Casing Pressure Tubing Pressure 184 401309 N/A Length 160 2350' 160Conductor Surface Intermediate 323-025 Sr Pet Eng: Slotted Sr Pet Geo:Sr Res Eng: WINJ WAG 16 Water-BblOil-Bbl 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Gas-Mcf 390 15816 0 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 189 p k ft t Fra O s 208 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 orgio ,annucci By Kayla Junke at 4:06 pm, Apr 17, 2023 DSR-4/17/23 RBDMS JSB 042523 2-7/8" BTS-6 13CR 7.9# Production TubingHAL 5-½” Oil Swell PackerESP Power Cable, & 3/8" Chem Inj LineOP03-P05Dual Lateral Producer with ESP LiftNikaitchuq Field- Oliktok Point5-½” Silver Bullet Ecc. Nose Guide ShoeAs Run 03/29/2023 Interm. Casing 9-5/8", 47#5,960' MD, 3,686' TVD82º Inc.Slotted Liner,5-½” 17 ppf12,368' MD, 3,934' TVD90º Inc.5,735' MD – 3,644' TVD, Baker SLXP Liner Hanger/PackerSurf. Casing13-3/8", 68 # 2,351' MD, 2,158' TVD48º Inc.XO 1 jt of 4-½” tubing, XN nipple XO to 2-7/8” tubing 5,473' MD / 3,558' TVD Bottom of 2-7/8" 7.9# L-80 IBT-M Velocity String5,295' MD / 3,489' TVD, 67º Inc – Bottom of Conventional ESP562XP -250HP Motor; Tandem 513 GS3BBL Seals; 66stg Flex47 – 20stg Ginpsh; 538 GM2 Gas Sep5,224' MD / 3,462' TVD, 68º Discharge Gauge5,460' MD, 3,553' TVDL1 - Baker SLXP Liner Hanger/Packer5-½” Silver Bullet Ecc. Nose Guide Shoe with Bent Joint12,385' MDHAL 5-½” Oil Swell Packer5,626-5,643' MD, Planned Casing Exit WindowTD of 8 ½” OH12,391' MD, 3,933' TVD 89º Inc.Item (Upper Lateral) MD (ft)5 1/2" Oil Swell Pck #1 5,661'5 1/2" Oil Swell Pck #2 6,053'5 1/2" Oil Swell Pck #3 7,409'5 1/2" Oil Swell Pck #4 7,738'5 1/2" Oil Swell Pck #5 8,107'5 1/2" Oil Swell Pck #6 9,509'5 1/2" Oil Swell Pck #7 10,199'5-½” 15.5 ppf Slotted LinerWellhead: Vault MB-247 5K5,382' MD / 3,523' TVD 9-5/8" 47-53.5# HES Packer Well Name: OP03-P05 OR Wellbore Name: Original Hole Well Code: 22827 Job: WORKOVER WCEI: N/A Daily Report Date: 3/17/2023 Report #: 1 Page: 1 of 1 Well Header Permit/Concession N° ADL-388583 Operator ENI PETROLEUM Subsidiary ENI Petroleum Co. Inc. Initial Lahee Code DEVELOPMENT WELL Rotary Table Elevation (ft) 41.00 Ground Level (ft) 40.00 First Flange (ft) 31.57 RKB - Base Flange (ft) 9.43 RKB - Tubing Spool (ft) 8.85 Rig Information Rig Name RIG 4 Contractor NORDIC CALISTA Rig Type LAND RIG Rig Num 0981 Daily Information Weather Clear Temperature (°F) -28.3 Wind SW @ 10 MPH Days LTI (days) 2,018.00 Days RI (days) POB 37.0 Daily Summary Operations 24h Forecast Complete berming and bring 8.9 ppg brine to pits with fresh water and mix up to 8.6 ppg. Rig up and kill tubing and Annulus A as per program. Monitor well for 1 hour and set BPV. Nipple down tree and nipple up riser and BOPs. 24h Summary Move off well OI07-04 and set up over well OP03. Berming around rig. Spot cuttings box and berm. Set Hi-line building and Hi-line cable. Lift plan meeting and remove Schlumberger spoolers and install ESP, Cap line spooler and job box. Hang sheaves in derrick. Operation at 07.00 Well kill operations. Time Log Start Time End Time Dur (hr) Cum Dur (hr)Phase Opr. Act. Plan Oper. Descr. 00:00 04:00 4.00 4.00 MOB A 2 P PJSM, Complete rig move procedures. Warm up hydraulics for walker system. Lay matts, raise rig and walk back from well OI07-04 25'. Turn walker feet and walk 23' off rig matts to the west. 04:00 13:00 9.00 13.00 MOB A 5 P PJSM, Remove old herculite. Have Logistics level pad for move. Change out rubbers on suction. Check valves and seat in mud pumps. Lay herculite for OP03 pad set. Lay out rig matts. Remove ESP completion sheaves from derrick. 13:00 17:00 4.00 17.00 MOB A 2 P Lay rig matts and walk over well OP03. Center up over well and set down. 17:00 21:00 4.00 21.00 MOB A 5 P Clean up old pit liner. Berm around rig. Set new pit liner for cuttings box. Set clam shell for Hi-line cable and string out Hi-line cable. Set cuttings box and berm. Spot Hi-line building. Hang ESP sheave in derrick. 21:00 00:00 3.00 24.00 MOB A 20 P Hold lift plan meeting with all involved and open permit. Off load Schlumberger spoolers an bring in ESP job box, cap line spooler and ESP spooler. Hang cap line sheave in derrick. Daily Contacts Position Contact Name Company Title Email Office Mobile Eni representative Jody Cornell ASRC Energy Services Drilling Supv. ODSdrilling@eni.com 907-670-6606 Eni representative Russ Wimmer ASRC Energy Services Co. Man Russ.Wimmer@external.eni.com 907-685-0710 Eni representative Mitch Billington ASRC Energy Services Clerk AkRigClerksDoyon15@eni.com 907-685-0722 Eni representative Yelyzaveta Saprykina ASRC Energy Services Clerk AkRigClerksDoyon15@eni.com 907-685-0722 Safety Representative David Rush ASRC Energy Services HSE David.Rush@external.eni.com 970-685-6622 Safety Representative Greg Lomax ASRC Energy Services HSE Greg.Lomax@enternal.eni.com 970-685-6622 Tool Push Kyle Karsten Nordic Toolpusher rigmanager.rig4@nordic-calista.com 907-685-1470 Tool Push George Orloff Nordic Toolpusher rigmanager.rig4@nordic-calista.com 907-685-1470 Safety Representative Jim Beverage Nordic HSE Jim.beverage@nordic-calista.com 907-685-8603 Last Casing Seat Cas. Type OD (in) ID (in) Grade Top (ftKB) Bottom (ftKB) TVD Bot. (ftKB) Landing Date LINER 5 1/2 4.89 L-80 908.4 12,368.0 3,971.9 12/25/2008 Well Name: OP03-P05 OR Wellbore Name: Original Hole Well Code: 22827 Job: WORKOVER WCEI: N/A Daily Report Date: 3/18/2023 Report #: 2 Page: 1 of 1 Well Header Permit/Concession N° ADL-388583 Operator ENI PETROLEUM Subsidiary ENI Petroleum Co. Inc. Initial Lahee Code DEVELOPMENT WELL Rotary Table Elevation (ft) 41.00 Ground Level (ft) 40.00 First Flange (ft) 31.57 RKB - Base Flange (ft) 9.43 RKB - Tubing Spool (ft) 8.85 Rig Information Rig Name RIG 4 Contractor NORDIC CALISTA Rig Type LAND RIG Rig Num 0981 Daily Information Weather Clear Temperature (°F) -18.0 Wind WNW at 16 MPH Days LTI (days) 2,019.00 Days RI (days) POB 58.0 Daily Summary Operations 24h Forecast Complete nippling up and perform shell test. Test BOPE as per AOGCC specs with 4" and 4.5" test joints. Prep for pulling completion out of hole. 24h Summary Completed berming and loaded pits with 8.9 ppg brine with fresh water and mixed to a final brine weight of 8.6 ppg. Rig up kill lines to tubing and Annulus A and tested to 3000 psi. Bull head 105 bbls down tubing and 384 bbls down Annulus A. Annulus A was still holding pressure and bled it down to 0 psi. Monitor well for 1 hour-stable. Vault set BPV, nippled down tree, cleaned and inspected well head and GrayLoc flange. Nipple up BOPE. Operation at 07.00 Testing BOPs. Time Log Start Time End Time Dur (hr) Cum Dur (hr)Phase Opr. Act. Plan Oper. Descr. 00:00 01:30 1.50 1.50 MOB A 5 P PJSM Berm around rig and along well bay. Put fold up stair down and secure. 01:30 06:30 5.00 6.50 W.O. M 8 P PJSM All berming completed. Load 300 bbls of 8.9 ppg and 300 bbls of fresh water to pits and agitate. Brine weight is 8.6 ppg for kill weight. Obtain well bay permit and rig up kill lines to well. Seal off BOP enclosure. Prep for nipple up. Prime pumps. 06:30 07:00 0.50 7.00 W.O. M 12 P PJSM Pressure test kill lines to 3000 psi. Good test. 07:00 10:30 3.50 10.50 W.O. M 9 P PJSM Bull head 105 bbls of 8.6 ppg brine down tubing at 2 bpm, 475 psi. Swap to Annulus A and bull head 384 bbls at 3 bpm, ICP 290 psi, FCP 70 psi. 10:30 11:00 0.50 11.00 W.O. M 11 P PJSM Open Annulus A to bleed off pressure and seen an increase to 188 psi. Shut in Annulus A. Note: rig on High-line power at 11:00. 11:00 15:30 4.50 15.50 W.O. M 20 P PJSM rigged up bleed hose to OP10 Annulus A. Bleed pressure from188 psi. Continue to bleed down OP03 to OP10 until it equalized at 60 psi. Bleed off 60 psi from OP03 through rig mud gas separator to 0 psi. 15:30 16:30 1.00 16.50 W.O. M 1 P PJSM Monitor well for 1 hour- stable. 16:30 00:00 7.50 24.00 W.O. C 5 P PJSM Obtain well bay permit. Vault set BPV, nipple down tree, cleaned and inspected well head and GrayLoc flange. Install High-pressure riser and nipple up BOPE. Daily Contacts Position Contact Name Company Title Email Office Mobile Eni representative Jody Cornell ASRC Energy Services Drilling Supv. ODSdrilling@eni.com 907-670-6606 Eni representative Russ Wimmer ASRC Energy Services Co. Man Russ.Wimmer@external.eni.com 907-685-0710 Eni representative Mitch Billington ASRC Energy Services Clerk AkRigClerksDoyon15@eni.com 907-685-0722 Eni representative Yelyzaveta Saprykina ASRC Energy Services Clerk AkRigClerksDoyon15@eni.com 907-685-0722 Safety Representative David Rush ASRC Energy Services HSE David.Rush@external.eni.com 970-685-6622 Safety Representative Greg Lomax ASRC Energy Services HSE Greg.Lomax@enternal.eni.com 970-685-6622 Tool Push Kyle Karsten Nordic Toolpusher rigmanager.rig4@nordic-calista.com 907-685-1470 Tool Push George Orloff Nordic Toolpusher rigmanager.rig4@nordic-calista.com 907-685-1470 Safety Representative Jim Beverage Nordic HSE Jim.beverage@nordic-calista.com 907-685-8603 Last Casing Seat Cas. Type OD (in) ID (in) Grade Top (ftKB) Bottom (ftKB) TVD Bot. (ftKB) Landing Date LINER 5 1/2 4.89 L-80 908.4 12,368.0 3,971.9 12/25/2008 Well Name: OP03-P05 OR Wellbore Name: Original Hole Well Code: 22827 Job: WORKOVER WCEI: N/A Daily Report Date: 3/19/2023 Report #: 3 Page: 1 of 1 Well Header Permit/Concession N° ADL-388583 Operator ENI PETROLEUM Subsidiary ENI Petroleum Co. Inc. Initial Lahee Code DEVELOPMENT WELL Rotary Table Elevation (ft) 41.00 Ground Level (ft) 40.00 First Flange (ft) 31.57 RKB - Base Flange (ft) 9.43 RKB - Tubing Spool (ft) 8.85 Rig Information Rig Name RIG 4 Contractor NORDIC CALISTA Rig Type LAND RIG Rig Num 0981 Daily Information Weather Clear Temperature (°F) -5.0 Wind NE @ 20 MPH Days LTI (days) 2,020.00 Days RI (days) POB 60.0 Daily Summary Operations 24h Forecast Complete repairs and finish BOPE testing. Rig down all testing equipment and prep to pull completion. 24h Summary Testing BOPE as per AOGCC specs to 250/3500 psi with 4.5" and 2-7/8" test joints. Witnessed by Sully Sullivan. Door seals were leaking after 4.5" tests. Install 4 new seals. Attempt to test with 2-7/8" test jnt and annular was leaking. Begin changing out annular element. Operation at 07.00 Resume testing BOPs. Time Log Start Time End Time Dur (hr) Cum Dur (hr)Phase Opr. Act. Plan Oper. Descr. 00:00 01:30 1.50 1.50 W.O. C 5 P PJSM Vault make up test plug on 4.5" test joint and set. Rig up test equipment. 01:30 02:30 1.00 2.50 W.O. M 11 P PJSM Annulus A had pressured up to 188 psi. Bleed off pressure to bleed trailer. 02:30 05:30 3.00 5.50 W.O. C 12 P PJSM Fluid pack system. Begin testing as per AOGCC requirements with 4.5" test joint to 250/3500 psi, tests good. Test witnessed by AOGCC rep Sully Sullivan. 05:30 10:00 4.50 10.00 W.O. C 5 P PJSM Remove 4.5" test joint and install 2-7/8" test joint. Annulus A started to pressure up to 5.2 psi due to frozen bleed line. Thawed and blew out bleeder hose and bled pressure off Annulus A. 10:00 14:30 4.50 14.50 W.O. C 12 TR05 PJSM Testing with 2-7/8" test joint. Ram door seals leaking. Pump out stack and bleed pressure from Koomey. Lock out/ Tag out Koomey. PJSM Open up upper, lower and blind doors. Clean and inspect. Install new door seals on upper and lower ram doors. Electrician tested all gas alarms, good. 14:30 00:00 9.50 24.00 W.O. C 12 TR05 PJSM Fluid pack system. Attempt to test annular on 2-7/8" test joint. Annular was leaking. PJSM Blow down surface lines and pull test joint. Begin changing out annular element. Daily Contacts Position Contact Name Company Title Email Office Mobile Eni representative Jody Cornell ASRC Energy Services Drilling Supv. ODSdrilling@eni.com 907-670-6606 Eni representative Russ Wimmer ASRC Energy Services Co. Man Russ.Wimmer@external.eni.com 907-685-0710 Eni representative Mitch Billington ASRC Energy Services Clerk AkRigClerksDoyon15@eni.com 907-685-0722 Eni representative Yelyzaveta Saprykina ASRC Energy Services Clerk AkRigClerksDoyon15@eni.com 907-685-0722 Safety Representative David Rush ASRC Energy Services HSE David.Rush@external.eni.com 970-685-6622 Safety Representative Greg Lomax ASRC Energy Services HSE Greg.Lomax@enternal.eni.com 970-685-6622 Tool Push Kyle Karsten Nordic Toolpusher rigmanager.rig4@nordic-calista.com 907-685-1470 Tool Push George Orloff Nordic Toolpusher rigmanager.rig4@nordic-calista.com 907-685-1470 Safety Representative Jim Beverage Nordic HSE Jim.beverage@nordic-calista.com 907-685-8603 Last Casing Seat Cas. Type OD (in) ID (in) Grade Top (ftKB) Bottom (ftKB) TVD Bot. (ftKB) Landing Date LINER 5 1/2 4.89 L-80 908.4 12,368.0 3,971.9 12/25/2008 Well Name: OP03-P05 OR Wellbore Name: Original Hole Well Code: 22827 Job: WORKOVER WCEI: N/A Daily Report Date: 3/20/2023 Report #: 4 Page: 1 of 1 Well Header Permit/Concession N° ADL-388583 Operator ENI PETROLEUM Subsidiary ENI Petroleum Co. Inc. Initial Lahee Code DEVELOPMENT WELL Rotary Table Elevation (ft) 41.00 Ground Level (ft) 40.00 First Flange (ft) 31.57 RKB - Base Flange (ft) 9.43 RKB - Tubing Spool (ft) 8.85 Rig Information Rig Name RIG 4 Contractor NORDIC CALISTA Rig Type LAND RIG Rig Num 0981 Daily Information Weather Clear Temperature (°F) 21.2 Wind ES @ 5 MPH Days LTI (days) 2,021.00 Days RI (days) POB 62.0 Daily Summary Operations 24h Forecast Complete BOPE testing and break down testing equipment and test joint. Hold lift plan meeting with all personnel. Off load Doyon power tongs/equipment and Schlumberger work box. Load GBR power tongs and equipment to rig floor. Prep to pull completion. Pull completion out of hole as per plan. 24h Summary Continue changing annular element, function test new annular and re-test with 2-7/8" test jnt good. Call AOGCC rep to location to continue witnessing BOP testing, had failures. Change out choke HCR and new lower BOP door seals. Change out lower ram elements. Continue testing BOP with 2-7/8" & 4-1/2" test jnts. All test passed, pull test jnt. Operation at 07.00 Preparing to pull 4-1/2" ESP completion. Time Log Start Time End Time Dur (hr) Cum Dur (hr)Phase Opr. Act. Plan Oper. Descr. 00:00 06:30 6.50 6.50 W.O. C 5 TR05 PJSM Install new annular element and lid. Hook up hydraulic lines and pressure up Koomey and visibly check. Check and replace riser air boots, clean and silicone ring groove. Install riser to top of annular and torque up. Install riser from rotary. 06:30 09:30 3.00 9.50 W.O. C 12 P PJSM Vault set test plug. Rig up to continue BOPE testing. Function test new annular element. Test Annular on 2-7/8" test jnt. good. 09:30 12:00 2.50 12.00 W.O. M 1 P Call AOGCC rep Sully Sullivan back to location to witness the rest of the BOPE testing. Perform Derrick inspection. Clean BOP enclosure. 12:00 15:00 3.00 15.00 W.O. C 12 P PJSM Continue to test BOPE with 2 good tests, then pressure was bleeding off. Grease choke and still pressure bleeding off. 15:00 20:30 5.50 20.50 W.O. C 25 U PJSM Blow down lines. Remove Choke HCR valve and replace with new. Open lower ram doors and replace door seals. Blow down surface equipment. Clean cavities and inspect lower pipe rams. Change out lower ram elements. 20:30 00:00 3.50 24.00 W.O. C 12 P PJSM Test with 2-7/8" test jnt, lower rams, choke HCR and inside kill. Change out test joint to 4.5". Test PVT totalizers. Test annular, retest upper rams, FOSV, manual IBOP, choke valves #4,10 and #8, kill HCR, lower rams and inside choke, all test good. Pull test joint. Daily Contacts Position Contact Name Company Title Email Office Mobile Eni representative Jody Cornell ASRC Energy Services Drilling Supv. ODSdrilling@eni.com 907-670-6606 Eni representative Russ Wimmer ASRC Energy Services Co. Man Russ.Wimmer@external.eni.com 907-685-0710 Eni representative Mitch Billington ASRC Energy Services Clerk AkRigClerksDoyon15@eni.com 907-685-0722 Eni representative Yelyzaveta Saprykina ASRC Energy Services Clerk AkRigClerksDoyon15@eni.com 907-685-0722 Safety Representative David Rush ASRC Energy Services HSE David.Rush@external.eni.com 970-685-6622 Safety Representative Greg Lomax ASRC Energy Services HSE Greg.Lomax@enternal.eni.com 970-685-6622 Tool Push Kyle Karsten Nordic Toolpusher rigmanager.rig4@nordic-calista.com 907-685-1470 Tool Push George Orloff Nordic Toolpusher rigmanager.rig4@nordic-calista.com 907-685-1470 Safety Representative Jim Beverage Nordic HSE Jim.beverage@nordic-calista.com 907-685-8603 Last Casing Seat Cas. Type OD (in) ID (in) Grade Top (ftKB) Bottom (ftKB) TVD Bot. (ftKB) Landing Date LINER 5 1/2 4.89 L-80 908.4 12,368.0 3,971.9 12/25/2008 Well Name: OP03-P05 OR Wellbore Name: Original Hole Well Code: 22827 Job: WORKOVER WCEI: N/A Daily Report Date: 3/21/2023 Report #: 5 Page: 1 of 1 Well Header Permit/Concession N° ADL-388583 Operator ENI PETROLEUM Subsidiary ENI Petroleum Co. Inc. Initial Lahee Code DEVELOPMENT WELL Rotary Table Elevation (ft) 41.00 Ground Level (ft) 40.00 First Flange (ft) 31.57 RKB - Base Flange (ft) 9.43 RKB - Tubing Spool (ft) 8.85 Rig Information Rig Name RIG 4 Contractor NORDIC CALISTA Rig Type LAND RIG Rig Num 0981 Daily Information Weather Clear Temperature (°F) 3.0 Wind SE @ 10 MPH Days LTI (days) 2,022.00 Days RI (days) POB 48.0 Daily Summary Operations 24h Forecast Orientation with new crew to Nordic. Lift meeting and remove ESP and Cap line spoolers. Load 4" drill pipe to shed and tally. Ship out the remainder of old completion. Make up Baker BHA #1 and single in hole. 24h Summary Complete BOPE testing. Lift plan for taking Doyon casing off rig and installing GBR equipment. Prep and release tubing hanger at 198k. Lay down hanger and 4-1/2" old completion from well. Loading Baker fishing tools to pipe shed. Operation at 07.00 Loading 4" drill pipe into pipe shed. Time Log Start Time End Time Dur (hr) Cum Dur (hr)Phase Opr. Act. Plan Oper. Descr. 00:00 01:00 1.00 1.00 W.O. C 12 P PJSM Test blinds, Manual choke and super choke. Witnessed by AOGCC representative Sully Sullivan. 01:00 02:00 1.00 2.00 W.O. C 5 P Hold lift plan meeting with all involved and open permit. Blow down top drive and rig down test equipment. Clean and organize floor for lift. 02:00 06:30 4.50 6.50 W.O. M 5 P PJSM Crane off ESP spooler and all Doyon casing equipment. Early change out for Operations. Load GBR equipment to rig floor and spot ESP spooler. 06:30 08:30 2.00 8.50 W.O. C 5 P Organize rig floor. Vault obtained well bay permit. Pull test dart and BPV. Make crossover to landing joint and install on tubing hanger. Back out lock down screws. 08:30 10:00 1.50 10.00 W.O. M 5 P Rig up GBR equipment and Baker spooling units. Prep pipe shed for decompletion. 10:00 12:00 2.00 12.00 W.O. L 5 P Pull tubing hanger loose at 198k PUW. Pull tubing hanger to floor. Vault and Baker removed cap line and ESP. Remove hanger and landing joint and lay down in pipe shed. Pump 25 gals of hydraulic fluid down cap line. 12:00 20:30 8.50 20.50 W.O. L 4 P Pull out of hole laying down 4-1/2" completion tubing from 5353' to 105'. 20:30 22:00 1.50 22.00 W.O. L 5 P PJSM Lay down Baker ESP BHA. BHA was clean with no plugged areas. Clamps; 128 cross collar, 2 splice, 3 Mid-jt, 3 protector, 4 pump. 22:00 00:00 2.00 24.00 W.O. M 5 P Rig down completion equipment and unload from shed. Loading Baker tools into pipe shed. Daily Contacts Position Contact Name Company Title Email Office Mobile Eni representative Jody Cornell ASRC Energy Services Drilling Supv. ODSdrilling@eni.com 907-670-6606 Eni representative Russ Wimmer ASRC Energy Services Co. Man Russ.Wimmer@external.eni.com 907-685-0710 Eni representative Bob Smejkal ASRC Energy Services Clerk AkRigClerksDoyon15@eni.com 907-685-0722 Eni representative Yelyzaveta Saprykina ASRC Energy Services Clerk AkRigClerksDoyon15@eni.com 907-685-0722 Safety Representative David Rush ASRC Energy Services HSE David.Rush@external.eni.com 970-685-6622 Safety Representative Greg Lomax ASRC Energy Services HSE Greg.Lomax@enternal.eni.com 970-685-6622 Tool Push Kyle Karsten Nordic Toolpusher rigmanager.rig4@nordic-calista.com 907-685-1470 Tool Push George Orloff Nordic Toolpusher rigmanager.rig4@nordic-calista.com 907-685-1470 Safety Representative Jim Beverage Nordic HSE Jim.beverage@nordic-calista.com 907-685-8603 Last Casing Seat Cas. Type OD (in) ID (in) Grade Top (ftKB) Bottom (ftKB) TVD Bot. (ftKB) Landing Date LINER 5 1/2 4.89 L-80 908.4 12,368.0 3,971.9 12/25/2008 Well Name: OP03-P05 OR Wellbore Name: Original Hole Well Code: 22827 Job: WORKOVER WCEI: N/A Daily Report Date: 3/22/2023 Report #: 6 Page: 1 of 1 Well Header Permit/Concession N° ADL-388583 Operator ENI PETROLEUM Subsidiary ENI Petroleum Co. Inc. Initial Lahee Code DEVELOPMENT WELL Rotary Table Elevation (ft) 41.00 Ground Level (ft) 40.00 First Flange (ft) 31.57 RKB - Base Flange (ft) 9.43 RKB - Tubing Spool (ft) 8.85 Rig Information Rig Name RIG 4 Contractor NORDIC CALISTA Rig Type LAND RIG Rig Num 0981 Daily Information Weather Overcast Temperature (°F) 0.5 Wind W @ 9 MPH Days LTI (days) 2,023.00 Days RI (days) POB 48.0 Daily Summary Operations 24h Forecast Trip in the hole with BHA #1 Polishing mill and Vax tool. 24h Summary Lift meeting with Worley crane crew. Load 4" drill pipe in shed. Trip in hole with 4" drill pipe Pull out of the hole stand back in derrick. Safety stand down meeting. Operation at 07.00 Make up BHA and trip in the hole with 4" drill pipe from pipe shed. Time Log Start Time End Time Dur (hr) Cum Dur (hr)Phase Opr. Act. Plan Oper. Descr. 00:00 02:30 2.50 2.50 W.O. M 5 P PJSM. Lift meeting with crane crew. Hoist ESP spooler and cap line spooler to rig floor. 02:30 12:00 9.50 12.00 W.O. M 5 P Worley operator, Load 4" drill pipe in pipe shed, Clear cannon clamps from pipe shed to back deck, Load Baker clean out BHA assembly in pipe shed, Transfer 290 bbl. 8.8 ppg 3% KCL brine into pits, Work on house keeping and maintenance around rig. Verify drill pipe count on location, Fill hole10 bbl/hr. 12:00 16:00 4.00 16.00 W.O. M 1 P Load 4" drill pipe into the shed. Strap and number. 16:00 16:30 0.50 16.50 W.O. C 5 P PJSM. Install wear bushing. 16:30 19:30 3.00 19.50 W.O. M 4 P PJSM. Pick up BHA #1. Trip in the hole stacked out 34 ft in the well bore. Unable to Run in the hole. Pulled BHA #1 out of the hole. Removed wear bushing and inspect ( wear bushing 9-1/8 ID) Rack back in derrick on drill pipe. 19:30 21:00 1.50 21.00 W.O. M 4 P PJSM. Made up bull nose, magnet, X-Over and 2 joints of drill pipe. Trip in the hole to 75ft. did not tag. 21:00 23:30 2.50 23.50 W.O. M 4 P Trip on the hole with 4" drill pipe to 755'. Trip out of the hole stand back stands in Derrick. 23:30 00:00 0.50 24.00 W.O. M 1 U Safety stand down. Topic is hand safety. Daily Contacts Position Contact Name Company Title Email Office Mobile Eni representative Jody Cornell ASRC Energy Services Drilling Supv. ODSdrilling@eni.com 907-670-6606 Eni representative Craig Smith ASRC Energy Services Co. Man OPPdiilling@eni.com 907-685-0710 Eni representative Bob Smejkal ASRC Energy Services Clerk AkRigClerksDoyon15@eni.com 907-685-0722 Eni representative Yelyzaveta Saprykina ASRC Energy Services Clerk AkRigClerksDoyon15@eni.com 907-685-0722 Safety Representative David Rush ASRC Energy Services HSE David.Rush@external.eni.com 970-685-6622 Safety Representative Greg Lomax ASRC Energy Services HSE Greg.Lomax@enternal.eni.com 970-685-6622 Tool Push Kyle Karsten Nordic Toolpusher rigmanager.rig4@nordic-calista.com 907-685-1470 Tool Push George Orloff Nordic Toolpusher rigmanager.rig4@nordic-calista.com 907-685-1470 Safety Representative Jim Beverage Nordic HSE Jim.beverage@nordic-calista.com 907-685-8603 Last Casing Seat Cas. Type OD (in) ID (in) Grade Top (ftKB) Bottom (ftKB) TVD Bot. (ftKB) Landing Date LINER 5 1/2 4.89 L-80 908.4 12,368.0 3,971.9 12/25/2008 Well Name: OP03-P05 OR Wellbore Name: Original Hole Well Code: 22827 Job: WORKOVER WCEI: N/A Daily Report Date: 3/23/2023 Report #: 7 Page: 1 of 1 Well Header Permit/Concession N° ADL-388583 Operator ENI PETROLEUM Subsidiary ENI Petroleum Co. Inc. Initial Lahee Code DEVELOPMENT WELL Rotary Table Elevation (ft) 41.00 Ground Level (ft) 40.00 First Flange (ft) 31.57 RKB - Base Flange (ft) 9.43 RKB - Tubing Spool (ft) 8.85 Rig Information Rig Name RIG 4 Contractor NORDIC CALISTA Rig Type LAND RIG Rig Num 0981 Daily Information Weather Overcast Temperature (°F) 3.6 Wind 0 MPH Days LTI (days) 2,024.00 Days RI (days) POB 40.0 Daily Summary Operations 24h Forecast Make up BHA assembly #2. Pick up 55 joints of PH6 tubing, and liner clean out assembly. Trip out of the hole break lay down BHA #2 assembly. Clean out Vac tool, lay down 55 joints PH6 Tubing in the pipe shed, Make up 9-5/8 casing Test packer assembly. 24h Summary Safety stand down with town. Made up BHA #2 Trip in the hole polish liner top. Trip out of the hole break lay down BHA assembly #2. Clear and clean rig floor. Operation at 07.00 Trip in the hole with 4' Drill pipe from derrick. Time Log Start Time End Time Dur (hr) Cum Dur (hr)Phase Opr. Act. Plan Oper. Descr. 00:00 01:30 1.50 1.50 W.O. M 1 U Safety stand down-Incident review, Discuss safety action plan forward. Topic hand safety. 01:30 02:00 0.50 2.00 W.O. M 1 P Pre-tour safety meeting with night crew. 02:00 04:00 2.00 4.00 W.O. M 1 P Zoom boom operator, Move new BHA items into pipe shed. Prepare Clear and clean rig floor. 04:00 07:00 3.00 7.00 W.O. M 4 P Baker fishing and rig crew. Pick up BHA #1 reaming / clean out assembly. 07:00 14:30 7.50 14.50 W.O. M 4 P PJSM. Pick up 4' drill pipe from 146' to 3,705' PU 75k,SO 80k. Fill hole 10 bbl/hr. Drift pipe in door. Transfer 277 bbls Brine into pits. 14:30 15:00 0.50 15.00 W.O. M 25 P Rig service. Replace hose on iron roughneck. 15:00 16:00 1.00 16.00 W.O. M 4 P Continue to run in hole from 4,398' to 5,410' PUW 100k SOW 81k. 16:00 18:00 2.00 18.00 W.O. M 4 P Pick up Kelly and wash down from 3 bpm 150 spp from 5,410' to 5,460' tag liner top with 10k. Pick up 50' and slack off 5 times polished liner top for 1min 20rpm 4-9k torque. 18:00 21:00 3.00 21.00 W.O. M 4 P Blow down top drive lay down 1 single in the pipe shed. Trip out of the hole from 5,434' to BHA. 21:00 00:00 3.00 24.00 W.O. M 4 P Break and lay down BHA #1. Drain VAC tool. Clean Magnets. Recovered 3 lbs. metal. Daily Contacts Position Contact Name Company Title Email Office Mobile Eni representative Jody Cornell ASRC Energy Services Drilling Supv. ODSdrilling@eni.com 907-670-6606 Eni representative Craig Smith ASRC Energy Services Co. Man OPPdiilling@eni.com 907-685-0710 Eni representative Bob Smejkal ASRC Energy Services Clerk AkRigClerksDoyon15@eni.com 907-685-0722 Safety Representative David Rush ASRC Energy Services HSE David.Rush@external.eni.com 970-685-6622 Safety Representative Greg Lomax ASRC Energy Services HSE Greg.Lomax@enternal.eni.com 970-685-6622 Tool Push Kyle Karsten Nordic Toolpusher rigmanager.rig4@nordic-calista.com 907-685-1470 Tool Push George Orloff Nordic Toolpusher rigmanager.rig4@nordic-calista.com 907-685-1470 Safety Representative Jim Beverage Nordic HSE Jim.beverage@nordic-calista.com 907-685-8603 Last Casing Seat Cas. Type OD (in) ID (in) Grade Top (ftKB) Bottom (ftKB) TVD Bot. (ftKB) Landing Date LINER 5 1/2 4.89 L-80 908.4 12,368.0 3,971.9 12/25/2008 Well Name: OP03-P05 OR Wellbore Name: Original Hole Well Code: 22827 Job: WORKOVER WCEI: N/A Daily Report Date: 3/24/2023 Report #: 8 Page: 1 of 1 Well Header Permit/Concession N° ADL-388583 Operator ENI PETROLEUM Subsidiary ENI Petroleum Co. Inc. Initial Lahee Code DEVELOPMENT WELL Rotary Table Elevation (ft) 41.00 Ground Level (ft) 40.00 First Flange (ft) 31.57 RKB - Base Flange (ft) 9.43 RKB - Tubing Spool (ft) 8.85 Rig Information Rig Name RIG 4 Contractor NORDIC CALISTA Rig Type LAND RIG Rig Num 0981 Daily Information Weather Clear Temperature (°F) 3.4 Wind S @ 14 MPH Days LTI (days) 2,025.00 Days RI (days) POB 41.0 Daily Summary Operations 24h Forecast Make up 9-5/8" Retrievamatic test packer assembly.Trip in the hole with 4' drill pipe.Test 9-5/8". Trip out of the hole lay down 9-5/8" Retrievamatic packer assembly. 24h Summary Make up BHA assembly #2. Pick up 55 joints of PH6 tubing and Vac liner clean out assembly. Wash down from 5,413' to 5,508' & 5,961' to 6,075'. Then trip in the hole from 6,075' to 7,186' and tag no go.Trip out of the hole break lay down BHA #2 assembly. Clean out Vac tool, lay down 55 joints PH6 tubing in the pipe shed. Operation at 07.00 Running in hole with 9-5/8" test packer at 3,705' MD. Time Log Start Time End Time Dur (hr) Cum Dur (hr)Phase Opr. Act. Plan Oper. Descr. 00:00 01:00 1.00 1.00 W.O. M 5 P PJSM. Break and lay down Baker Vac tool, Break and remove magnet and jar assembly. 01:00 07:30 6.50 7.50 W.O. M 5 P Make up mill/ clean out BHA assembly, Make up mule shoe, Pick up 55 joints 2-7/8" PH6 to 1,718'. Rig down GBR Power tongs. Pick up Baker VAC tool. Fill hole 10 bbl/hr. 07:30 12:00 4.50 12.00 W.O. M 4 P PJSM. Trip in the hole from 1,823' to 6,075'. Wash down from 5,413' to 5,508' & 5,961' to 6,075' PUW 95k SOW 79k, 52 SPM at 710 PSI. 12:00 14:30 2.50 14.50 W.O. M 4 P Trip in the hole from 6,075' to 7,186' and tag no go. Wash down stands 51, 55, 57, 5 bpm at 800 psi PUW 105k SOW 80k. 14:30 18:00 3.50 18.00 W.O. M 4 P Trip out of the hole and stand back in derrick with 4" drill pipe from 7,186' to 1,823'. 18:00 00:00 6.00 24.00 W.O. M 5 P PJSM. Break and lay down BHA #2 clean magnets recovered and 1 lb metal. Drain Baker VAC tool. Lay down 2-7/8" PH6 each connection was wet. Daily Contacts Position Contact Name Company Title Email Office Mobile Eni representative Jody Cornell ASRC Energy Services Drilling Supv. ODSdrilling@eni.com 907-670-6606 Eni representative Craig Smith ASRC Energy Services Co. Man OPPdiilling@eni.com 907-685-0710 Eni representative Bob Smejkal ASRC Energy Services Clerk AkRigClerksDoyon15@eni.com 907-685-0722 Safety Representative David Rush ASRC Energy Services HSE David.Rush@external.eni.com 970-685-6622 Safety Representative Greg Lomax ASRC Energy Services HSE Greg.Lomax@enternal.eni.com 970-685-6622 Tool Push Kyle Karsten Nordic Toolpusher rigmanager.rig4@nordic-calista.com 907-685-1470 Tool Push George Orloff Nordic Toolpusher rigmanager.rig4@nordic-calista.com 907-685-1470 Safety Representative Jim Beverage Nordic HSE Jim.beverage@nordic-calista.com 907-685-8603 Last Casing Seat Cas. Type OD (in) ID (in) Grade Top (ftKB) Bottom (ftKB) TVD Bot. (ftKB) Landing Date LINER 5 1/2 4.89 L-80 908.4 12,368.0 3,971.9 12/25/2008 Well Name: OP03-P05 OR Wellbore Name: Original Hole Well Code: 22827 Job: WORKOVER WCEI: N/A Daily Report Date: 3/25/2023 Report #: 9 Page: 1 of 1 Well Header Permit/Concession N° ADL-388583 Operator ENI PETROLEUM Subsidiary ENI Petroleum Co. Inc. Initial Lahee Code DEVELOPMENT WELL Rotary Table Elevation (ft) 41.00 Ground Level (ft) 40.00 First Flange (ft) 31.57 RKB - Base Flange (ft) 9.43 RKB - Tubing Spool (ft) 8.85 Rig Information Rig Name RIG 4 Contractor NORDIC CALISTA Rig Type LAND RIG Rig Num 0981 Daily Information Weather Clear Temperature (°F) 2.4 Wind S @ 14 MPH Days LTI (days) 2,026.00 Days RI (days) POB 40.0 Daily Summary Operations 24h Forecast Diagnose top drive zone safety board. Trip in the hole with 4" Drill pipe from derrick. Set Liner hanger. Trip out of the hole lay down 4" drill pipe in shed. 24h Summary Make up 9-5/8" Retrievamatic test packer assembly. Trip in the hole to 5,410'. Test 9-5/8" to 2,000 psi for 30 min charted, good test. Trip out of the hole lay down 9-5/8" Retrievamatic packer assembly. Make up Halliburton lower Liner Hanger assembly and trip in the hole to 4,309'. Operation at 07.00 Laying down 4" drill pipe. Time Log Start Time End Time Dur (hr) Cum Dur (hr)Phase Opr. Act. Plan Oper. Descr. 00:00 02:00 2.00 2.00 W.O. M 5 P PJSM. Rig down GBR power tongs. Clean rig floor and prep handling equipment for next operations. 02:00 07:00 5.00 7.00 W.O. M 4 P Make up 9-5/8" Retrievamatic test packer assembly. Trip in the hole with 4" drill pipe from 20' to 5,406' at 90 fpm. Fill hole10 bbls/hr. 07:00 08:00 1.00 8.00 W.O. M 7 P Pick up 1 joint 4" drill pipe space out set test packer, center of element at 5,410'. Set packer. Fill hole and circulate to remove oil cap from well bore prior to testing casing. 08:00 09:30 1.50 9.50 W.O. M 12 P Pressure test casing fo 30 min charted at 2,000 psi, good test. Bring up in 500 psi increments, monitor B Annulus pressure through out test. Increase from 300 psi to 340 psi once A Annulus reached 2,000 psi. Bleed off pressure to 0 psi and open up well. 09:30 10:30 1.00 10.50 W.O. M 5 P Release packer and pick up to verify good release. Rig down test equipment and blow down lines. 10:30 12:00 1.50 12.00 W.O. M 4 P Trip out of the hole from 5,410' to 3,800' at 90 fpm. Continue fill hole 10bbl/hr plus pipe displacement. 12:00 15:00 3.00 15.00 W.O. M 25 P PJSM. Slip and cut drill line 80ft. 15:00 16:00 1.00 16.00 W.O. M 1 P Remove 2-7/8" PH-6 drill pipe from shed and Baker tools and equipment. Load BHA #4 Halliburton liner hanger assembly. 16:00 18:00 2.00 18.00 W.O. M 4 P Trip out of the hole from 3,008' to surface at 90fph, fill hole 10 bbl/hr. plus pipe displacement. 18:00 20:30 2.50 20.50 W.O. M 5 P Pick up BHA #4 liner hanger tie back assembly. 20:30 23:30 3.00 23.50 W.O. M 4 P Trip in the hole from 151' to 4,309' at 90 fpm. Drift drill pipe from derrick. 23:30 00:00 0.50 24.00 W.O. M 25 P Service rig. Daily Contacts Position Contact Name Company Title Email Office Mobile Eni representative Jody Cornell ASRC Energy Services Drilling Supv. ODSdrilling@eni.com 907-670-6606 Eni representative Craig Smith ASRC Energy Services Co. Man OPPdiilling@eni.com 907-685-0710 Eni representative Bob Smejkal ASRC Energy Services Clerk AkRigClerksDoyon15@eni.com 907-685-0722 Safety Representative David Rush ASRC Energy Services HSE David.Rush@external.eni.com 970-685-6622 Safety Representative Greg Lomax ASRC Energy Services HSE Greg.Lomax@enternal.eni.com 970-685-6622 Tool Push Kyle Karsten Nordic Toolpusher rigmanager.rig4@nordic-calista.com 907-685-1470 Tool Push George Orloff Nordic Toolpusher rigmanager.rig4@nordic-calista.com 907-685-1470 Safety Representative Jim Beverage Nordic HSE Jim.beverage@nordic-calista.com 907-685-8603 Last Casing Seat Cas. Type OD (in) ID (in) Grade Top (ftKB) Bottom (ftKB) TVD Bot. (ftKB) Landing Date LINER 5 1/2 4.89 L-80 908.4 12,368.0 3,971.9 12/25/2008 Well Name: OP03-P05 OR Wellbore Name: Original Hole Well Code: 22827 Job: WORKOVER WCEI: N/A Daily Report Date: 3/26/2023 Report #: 10 Page: 1 of 1 Well Header Permit/Concession N° ADL-388583 Operator ENI PETROLEUM Subsidiary ENI Petroleum Co. Inc. Initial Lahee Code DEVELOPMENT WELL Rotary Table Elevation (ft) 41.00 Ground Level (ft) 40.00 First Flange (ft) 31.57 RKB - Base Flange (ft) 9.43 RKB - Tubing Spool (ft) 8.85 Rig Information Rig Name RIG 4 Contractor NORDIC CALISTA Rig Type LAND RIG Rig Num 0981 Daily Information Weather Overcast Temperature (°F) 14.0 Wind SE @ 24 MPH Days LTI (days) 2,027.00 Days RI (days) POB 50.0 Daily Summary Operations 24h Forecast Rigging up to run ESP Completion. Load 171 joints BTS-6 Completion tubing in the pipe shed. Make up ESP Completion pump assembly. Trip in the hole with ESP Completion. 24h Summary Diagnose top drive zone safety panel board. Trip in the hole with velocity string, from 4,309' to 5,354'. Set Liner hanger. Trip out of the hole and lay down 4" drill pipe in shed. Lift plan meeting rigging up to run ESP Completion. Load 171 joints BTS-6 Completion tubing in the pipe shed. Operation at 07.00 Loading 2-7/8" tubing for completion in the pipe shed to drift and tally. Time Log Start Time End Time Dur (hr) Cum Dur (hr)Phase Opr. Act. Plan Oper. Descr. 00:00 04:30 4.50 4.50 W.O. M 25 U Diagnose top drive zone safety panel board. Nordic electrician consult with PECO tech via phone. 04:30 06:30 2.00 6.50 W.O. M 4 P PJSM. Trip in hole from with velocity string 4,309' to 5,492' at 90 fpm as per baker rep. Continue fill at 10 bbl/hr. PUW 94k SOW 80k. 06:30 09:30 3.00 9.50 W.O. M 12 P Drop ball and pump ball on seat with 54 bbl. Set packer with 3,500 psi and hold for 30 min charted. Good test. Bleed off pressure. Fill A Annulus with 43 bbls. Pressure test back side for 10 min at 2,000 psi, good test. Bleed down pressure through choke. Pressure up on drill pipe to 4,500 psi to release running tool from packer. Blow down top drive, stand pipe and choke manifold. 09:30 15:00 5.50 15.00 W.O. M 4 P PJSM. Lay down drill pipe in shed from 5,492' to 3,930' fill hole 10 bbl/hr plus pipe displacement. Remove 4" drill pipe from shed and Baker tools. 15:00 20:00 5.00 20.00 W.O. M 4 P Trip out of the hole from 3,930' to 48' fill hole 10 bbl/hr. plus pipe displacement 20:00 21:00 1.00 21.00 W.O. M 5 P Break and lay down BHA, remove drill pipe from shed. 21:00 00:00 3.00 24.00 W.O. M 1 P PJSM. Lift meeting with Worley crane crew. Pick up ESP spools and load clamps on back deck of the rig. Daily Contacts Position Contact Name Company Title Email Office Mobile Eni representative Jody Cornell ASRC Energy Services Drilling Supv. ODSdrilling@eni.com 907-670-6606 Eni representative Craig Smith ASRC Energy Services Co. Man OPPdiilling@eni.com 907-685-0710 Eni representative Bob Smejkal ASRC Energy Services Clerk AkRigClerksDoyon15@eni.com 907-685-0722 Safety Representative David Rush ASRC Energy Services HSE David.Rush@external.eni.com 970-685-6622 Safety Representative Greg Lomax ASRC Energy Services HSE Greg.Lomax@enternal.eni.com 970-685-6622 Tool Push Kyle Karsten Nordic Toolpusher rigmanager.rig4@nordic-calista.com 907-685-1470 Tool Push George Orloff Nordic Toolpusher rigmanager.rig4@nordic-calista.com 907-685-1470 Safety Representative Jim Beverage Nordic HSE Jim.beverage@nordic-calista.com 907-685-8603 Last Casing Seat Cas. Type OD (in) ID (in) Grade Top (ftKB) Bottom (ftKB) TVD Bot. (ftKB) Landing Date LINER 5 1/2 4.89 L-80 908.4 12,368.0 3,971.9 12/25/2008 Well Name: OP03-P05 OR Wellbore Name: Original Hole Well Code: 22827 Job: WORKOVER WCEI: N/A Daily Report Date: 3/27/2023 Report #: 11 Page: 1 of 1 Well Header Permit/Concession N° ADL-388583 Operator ENI PETROLEUM Subsidiary ENI Petroleum Co. Inc. Initial Lahee Code DEVELOPMENT WELL Rotary Table Elevation (ft) 41.00 Ground Level (ft) 40.00 First Flange (ft) 31.57 RKB - Base Flange (ft) 9.43 RKB - Tubing Spool (ft) 8.85 Rig Information Rig Name RIG 4 Contractor NORDIC CALISTA Rig Type LAND RIG Rig Num 0981 Daily Information Weather Overcast Temperature (°F) 28.2 Wind SW @ 24 MPH Days LTI (days) 2,028.00 Days RI (days) POB 49.0 Daily Summary Operations 24h Forecast Trip in the hole with ESP Completion. Make up tubing hanger ESP Penetrator cable splice. Land hanger and Nipple down BOPE stack. Nipple up tree and test hanger void. Conduct passport test. 24h Summary Rig up to run ESP Completion. Change out hydraulic hose on Driller side pipe elevator. Load 171 joints BTS-6 Completion tubing in the pipe shed. Make up ESP Completion pump assembly. Trip in the hole with ESP Completion to 1,475'. Operation at 07.00 Running in the hole with ESP Completion at 3,600' MD. Time Log Start Time End Time Dur (hr) Cum Dur (hr)Phase Opr. Act. Plan Oper. Descr. 00:00 01:00 1.00 1.00 W.O. C 5 P PJSM. Remove wear bushing. Rigging up to run ESP Completion equipment. Fill hole 10 bbl/hr. 01:00 03:00 2.00 3.00 W.O. M 25 U Rig repair replace hydraulic hose on driller side pipe elevator. 03:00 04:00 1.00 4.00 W.O. M 1 P Load ESP Completion pump boxes in pipe shed and transfer over to off driller side of pipe shed. Fill hole 10 bbl/hr. 04:00 12:00 8.00 12.00 W.O. M 5 P Load 171 joints BTS-6 Completion tubing on the driller side of pipe shed. Rig up GBR Power tongs and torque turn equipment. Pull ESP Cable over sheave. Fill hole 10 bbl/hr. 12:00 19:30 7.50 19.50 W.O. K 5 P PJSM. Pick up completion BHA. Make up ESP motor and Service as per Baker rep. Test motor, good test. Fill hole 10 bbl/hr. 19:30 00:00 4.50 24.00 W.O. K 4 P Change out GBR power tongs. Run in the hole with ESP Completion from 71' to 1,475'. Test ESP Cable and control line every 1,000". Good test. Fill hole 10 bbl/hr. PUW 57k, SOW 55k, A Annulus 0 psi, B Annulus 150 psi. Daily Contacts Position Contact Name Company Title Email Office Mobile Eni representative Jody Cornell ASRC Energy Services Drilling Supv. ODSdrilling@eni.com 907-670-6606 Eni representative Craig Smith ASRC Energy Services Co. Man OPPdiilling@eni.com 907-685-0710 Eni representative Bob Smejkal ASRC Energy Services Clerk AkRigClerksDoyon15@eni.com 907-685-0722 Safety Representative David Rush ASRC Energy Services HSE David.Rush@external.eni.com 970-685-6622 Safety Representative Greg Lomax ASRC Energy Services HSE Greg.Lomax@enternal.eni.com 970-685-6622 Tool Push Kyle Karsten Nordic Toolpusher rigmanager.rig4@nordic-calista.com 907-685-1470 Tool Push George Orloff Nordic Toolpusher rigmanager.rig4@nordic-calista.com 907-685-1470 Safety Representative Jim Beverage Nordic HSE Jim.beverage@nordic-calista.com 907-685-8603 Last Casing Seat Cas. Type OD (in) ID (in) Grade Top (ftKB) Bottom (ftKB) TVD Bot. (ftKB) Landing Date LINER 5 1/2 4.89 L-80 908.4 12,368.0 3,971.9 12/25/2008 Well Name: OP03-P05 OR Wellbore Name: Original Hole Well Code: 22827 Job: WORKOVER WCEI: N/A Daily Report Date: 3/28/2023 Report #: 12 Page: 1 of 1 Well Header Permit/Concession N° ADL-388583 Operator ENI PETROLEUM Subsidiary ENI Petroleum Co. Inc. Initial Lahee Code DEVELOPMENT WELL Rotary Table Elevation (ft) 41.00 Ground Level (ft) 40.00 First Flange (ft) 31.57 RKB - Base Flange (ft) 9.43 RKB - Tubing Spool (ft) 8.85 Rig Information Rig Name RIG 4 Contractor NORDIC CALISTA Rig Type LAND RIG Rig Num 0981 Daily Information Weather Clear Temperature (°F) 1.6 Wind SW @ 25 MPH Days LTI (days) 2,029.00 Days RI (days) POB 48.0 Daily Summary Operations 24h Forecast Nipple down BOP stack. Nipple up tree. Test hanger and perform tree passport test. Perform final checks on ESP cable and chemical injection valve. Rig move from OP-03 to OI-20. 24h Summary Trip in the hole with ESP Completion from 1,475' to 5,327'. Make up tubing hanger and ESP Penetrator cable splice. Landed Tubing hanger. Test tubing hanger body seals ( upper & lower) good test. Lift plan meeting. Crane Baker Hughes completion spools and equipment off rig floor. Operation at 07.00 Nipple down BOPE. Time Log Start Time End Time Dur (hr) Cum Dur (hr)Phase Opr. Act. Plan Oper. Descr. 00:00 09:30 9.50 9.50 W.O. K 4 P Trip in the hole with ESP Completion from 1,475' to 5,283' at 30 ft/min PUW 75k SOW 70k. Fill hole10 bbl./hr. Perform cable checks every 1,000'. Fill pipe pump with one tubing volume at 3,000'. 09:30 12:00 2.50 12.00 W.O. K 5 P PJSM. Make up swivel joint with a.026 gap. Make up tubing hanger and landing joint. Begin tubing hanger install of ESP penetrator. Fill hole10 bbl/hr. 12:00 14:30 2.50 14.50 W.O. K 12 P PJSM. Continue making ESP Penetrator splice at hanger. Tested lower hanger connector (Good test). Tested upper hanger Connector (Good test). Fill hole10 bbl./hr. Blow down Mud pumps #1 and #2. Blow down mud line, manifold, kill and choke lines. 14:30 16:30 2.00 16.50 W.O. K 4 P Run in hole to land tubing hanger at 5,319' and stacked out with 5k - 6' short of landing hanger PUW 70k SOW 70k. 16:30 19:30 3.00 19.50 W.O. K 5 P Rig up power tongs and torque turn module. Pulled hanger to the rig floor. Disconnect ESP penetrator connections. Disconnect control lines from hanger. Break and lay down joint #167. Make up tubing hanger with swivel joint and orientate hanger. 19:30 22:00 2.50 22.00 W.O. K 5 P PJSM. Splice ESP cable connector & terminate lower connector to penetrator on tubing hanger. Terminate control line in tubing hanger. Test lower ESP Hanger connector (Good test). Test upper ESP hanger connector (Good test). Landed hanger and run in lock down screws. PUW 70k SOW 70k. Total full clamps-166, Protectories clamps -4, cross clamp MLE -1, Mid Jt clamp -1, Splice clamp -1, MLE Splice -1. 22:00 22:30 0.50 22.50 W.O. K 1 P Conduct crane lift meeting plan with management and all personal involved in task. 22:30 23:00 0.50 23.00 W.O. K 12 P Test tubing hanger body seals 5,000 psi 10 min witness by ENI company man (good test). 23:00 00:00 1.00 24.00 W.O. K 1 P Crane Baker Hughes completion spools and equipment off rig floor. A Annulus 0 psi B Annulus 300 psi. Daily Contacts Position Contact Name Company Title Email Office Mobile Eni representative Tim Ashley ASRC Energy Services Co. Man OPPdiilling@eni.com 907-685-0710 Eni representative Craig Smith ASRC Energy Services Co. Man OPPdiilling@eni.com 907-685-0710 Eni representative Bob Smejkal ASRC Energy Services Clerk AkRigClerksDoyon15@eni.com 907-685-0722 Safety Representative David Rush ASRC Energy Services HSE David.Rush@external.eni.com 970-685-6622 Safety Representative Greg Lomax ASRC Energy Services HSE Greg.Lomax@enternal.eni.com 970-685-6622 Tool Push Richard Twedt Nordic Toolpusher rigmanager.rig4@nordic-calista.com 907-685-1470 Tool Push George Orloff Nordic Toolpusher rigmanager.rig4@nordic-calista.com 907-685-1470 Safety Representative Jim Beverage Nordic HSE Jim.beverage@nordic-calista.com 907-685-8603 Last Casing Seat Cas. Type OD (in) ID (in) Grade Top (ftKB) Bottom (ftKB) TVD Bot. (ftKB) Landing Date LINER 5 1/2 4.89 L-80 908.4 12,368.0 3,971.9 12/25/2008 Well Name: OP03-P05 OR Wellbore Name: Original Hole Well Code: 22827 Job: WORKOVER WCEI: N/A Daily Report Date: 3/29/2023 Report #: 13 Page: 1 of 1 Well Header Permit/Concession N° ADL-388583 Operator ENI PETROLEUM Subsidiary ENI Petroleum Co. Inc. Initial Lahee Code DEVELOPMENT WELL Rotary Table Elevation (ft) 41.00 Ground Level (ft) 40.00 First Flange (ft) 31.57 RKB - Base Flange (ft) 9.43 RKB - Tubing Spool (ft) 8.85 Rig Information Rig Name RIG 4 Contractor NORDIC CALISTA Rig Type LAND RIG Rig Num 0981 Daily Information Weather Clear Temperature (°F) -4.7 Wind S @ 13 MPH Days LTI (days) 2,030.00 Days RI (days) POB 44.0 Daily Summary Operations 24h Forecast Move rig to OI20-07 and spot. Berm around rig, spot and berm cuttings box. Set auxiliary buildings and hook up to Hi-line power. 24h Summary Remove all equipment and tools from OP03 completion. Nipple down BOPE and secure. Vault completed Passport testing. Rig down from Hi-line power and on generator. Baker performed final checks on ESP system. Turn well over to Production. Rig released at 24:00 hrs Operation at 07.00 Moving rig to well OI20-04. No further reports. Time Log Start Time End Time Dur (hr) Cum Dur (hr)Phase Opr. Act. Plan Oper. Descr. 00:00 02:30 2.50 2.50 W.O. M 1 P PJSM with Worley crane and Baker for completing lifting operations. Crane off Baker equipment and thread protectors from back deck. Off loading brine from pits. PJSM with Logistic"s zoom boom. Remove Baker ESP boxes from pipe shed. Cleaning cuttings box. 02:30 03:30 1.00 3.50 W.O. M 1 P Load pup joints to pallets and band down. Load out pup joints and 4 joints of 2-7/8" BTS-6 from pipe shed. Continue off loading brine and cleaning pits. Clean and organize rig floor. 03:30 10:00 6.50 10.00 W.O. C 5 P Nipple down BOPE. Clean flow box and remove upper riser. Bleed down accumulator. Disconnect Koomey hoses and store. Nipple down choke and kill HCR's. Jack up rig. Split BOP's at single gate and rack back double gate, annular and single gate. Spool up Hi-line cable. 10:00 12:00 2.00 12.00 W.O. C 5 P PJSM with Vault. Brake out GrayLoc clamp, remove Hi pressure riser and secure in cellar box. Dress well head and complete feed through lines. Nipple up tree. 12:00 15:30 3.50 15.50 W.O. C 5 P Rig up for Passport testing. Rig down Hi-pressure hoses and bleed hoses. Remove 1502 fittings from well head. Clean and store pipe shed shimming. Blading location OI20 from rig move. Scope up cuttings box chute and secure, Vacuum fluids from cuttings box and dispose. Move heater away from cuttings box. 15:30 18:30 3.00 18.50 W.O. C 12 P Vault performing Production tree Passport testing as per ENI procedure- Good test. Rig down containment for cuttings box. Stage Hi-line away from rig moving. Scope up and secure BOP enclosure. Install well bay hatch. 18:30 19:00 0.50 19.00 W.O. M 12 P Baker perform final tests on ESP cables- Good tests. 19:00 22:30 3.50 22.50 W.O. A 2 P Worley bed truck moved cuttings box from rig. Clean up matt board, berming and pit liner. Move equipment and materials away from rig area. Install flow box plug. Rig down cable trays and berming on drillers side. 22:30 00:00 1.50 24.00 W.O. A 1 P Lay out herculite and rig mats for OI20. Complete pre-move checklist. Rig released at 24:00 hrs. No further reports. Daily Contacts Position Contact Name Company Title Email Office Mobile Eni representative Tim Ashley ASRC Energy Services Co. Man OPPdiilling@eni.com 907-685-0710 Eni representative Russ Wimmer ASRC Energy Services Co. Man Russ.Wimmer@external.eni.com 907-685-0710 Eni representative Bob Smejkal ASRC Energy Services Clerk AkRigClerksDoyon15@eni.com 907-685-0722 Safety Representative David Rush ASRC Energy Services HSE David.Rush@external.eni.com 970-685-6622 Safety Representative Greg Lomax ASRC Energy Services HSE Greg.Lomax@enternal.eni.com 970-685-6622 Tool Push Richard Twedt Nordic Toolpusher rigmanager.rig4@nordic-calista.com 907-685-1470 Tool Push George Orloff Nordic Toolpusher rigmanager.rig4@nordic-calista.com 907-685-1470 Safety Representative Jim Beverage Nordic HSE Jim.beverage@nordic-calista.com 907-685-8603 Last Casing Seat Cas. Type OD (in) ID (in) Grade Top (ftKB) Bottom (ftKB) TVD Bot. (ftKB) Landing Date LINER 5 1/2 4.89 L-80 908.4 12,368.0 3,971.9 12/25/2008 1. Type of Request:Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown Suspend Perforate Other Stimulate Pull Tubing Change Approved Program Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing Other: _ESP Changeout_ 2. Operator Name:4. Current Well Class: 5. Permit to Drill Number: Exploratory Development 3. Address: Stratigraphic Service 6. API Number: 7. If perforating:8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool?N/A Will planned perforations require a spacing exception?Yes No OP03-P05 9. Property Designation (Lease Number):10. Field: Current Pools: 11. Total Depth MD (ft):Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD): 12391 3933 12385 3934 939 N/A Casing Collapse Structural Conductor Surface 2,270 Intermediate 4,760 Production Liner Slotted Packers and SSSV Type:Packers and SSSV MD (ft) and TVD (ft): 12. Attachments:Proposal Summary Wellbore schematic 13. Well Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations:OIL WINJ WDSPL Suspended 16. Verbal Approval:Date: GAS WAG GSTOR SPLUG AOGCC Representative: GINJ Op Shutdown Abandoned Contact Name: Stefano Pierfelici Contact Email: Contact Phone: Authorized Title: Conditions of approval: Notify AOGCC so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other: Post Initial Injection MIT Req'd? Yes No Spacing Exception Required? Yes No Subsequent Form Required: APPROVED BY Approved by: COMMISSIONER THE AOGCC Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng Perforation Depth MD (ft): 5960' 5960-12368 5-1/2" 3686-3934 123686614 4-1/2" 3934 20" 13-3/8" 115' 9-5/8"5960' 2350' MD 6,870 5,020 115' 2158' 3686' 115' 2350' Length Size Proposed Pools: TVD Burst Nikaitchuq Schrader Bluff Schrader Bluff PRESENT WELL CONDITION SUMMARY STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL337701, ADL355024, ADL355023, ADL390615 208-137 3700 Centerpoint Drive, Ste. 500, Anchorage, AK 99503 50-029-23396-00-00 Eni US Operating Co. Inc. Slotted Tubing Grade:Tubing MD (ft): N/A Perforation Depth TVD (ft):Tubing Size: L-80 5344 21-Jan-23 N/A 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: AOGCC USE ONLY Amjad Chaudhry amjad.chaudhry@eni.com 97-865-3379 Well Operations Project Manager m n P s 2 66 t _ Form 10-403 Revised 10/2022 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov rfelici By Samantha Carlisle at 8:02 am, Jan 17, 2023 323-025 DSR-1/17/23 BOP test to 3500 psi. Annular test to 2500 psi DLB 01/17/2023 X BJM 1/18/23 X 10-404 GCW 01/18/23 JLC 1/18/2023 1/19/23Brett W. Huber. Sr.Digitally signed by Brett W. Huber. Sr. Date: 2023.01.19 08:25:17 -09'00' RBDMS JSB 011923 3800 Centerpoint Drive Suite 300 Anchorage, Alaska 99503 Stefano Pierfelici Phone (907) 865-3320 Email: Stefano.pierfelici@eni.com January 16 th, 2023 Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Application for Sundry Approval for OP03-P05 Rig Workover Dear Commissioners, ENI US Operating Co. Inc. hereby applies for a Workover Sundry for well OP03-P05. OP03-P05was completed on Oliktok Point on March 16 th, 2014 with an electric submersible pump set at a depth of 5,310’ MD. This ESP producer was completed without a packer. The well was started up for production in March 2014. On July 7 th, 2017 an ESP failure was occurred and in December 2017 another WO was conducted and ESP was installed ESP is working but with 50% fluid lift because of excessive sand in the heel area of the well. Plan is to pull current ESP completion, run a middle completion and run back conventional ESP. estimated start of this workover is January 21 st, 2023. Please find attached for the review of the Commission forms 10-403 and supporting documentation. If you have any questions or require further information, please contact Amjad Chaudhry at 907- 865-3379. Sincerely, Stefano Pierfelici Well Operations Project Manager OP03-P05 Workover –Summary Page PTD#:208-137 Current Status Well OP03-P05 is currently producing. Scope of Work Scope of this workover is to pull the current conventional ESP system and run a middle completion (Velocity string hanging below ESP shroud) and complete with a new ESP system General Well info Reservoir Pressure/TVD: This well is expected to have a static max bottom hole pressure of approximately 1300 psi (3,604’ TVD) during the time of workover. Wellhead type/pressure rating: Vetco Gray, MB-247/5000 psi BOP configuration: Annular/blind/vbr/pipe rams TIFL/MIT-IA/MIT-OA: Intermediate csg 9 5/8” was tested to 2000 psi on December 15th, 2017. Well type: Producer Estimated start date: January 21st, 2023 Drilling rig: Nordic 4 Completion Engineer: Amjad Chaudhry: amjad.chaudhry@eni.com Work: 907-865-3379 Well Operations Project Manager: Stefano Pierfelici: Stefano.pierfelici@eni.com Work: 907-865-3320 Procedure: 1. MIRU Nordic 4. 2. Circulate 9.5 ppg 3% NaCl/KCl brine through tree. 3. Set BPV. ND tree and NU BOP and test to 3500 psi. 4. POOH and lay down ESP assembly. 5. PU work string and RIH to cleanout inside of 5-1/2” liner. POOH and LD the BHA. 6. PU middle completion, RIH and set the same. 7. MU new ESP assembly and RIH to setting depth. 8. Land hanger and test it. 9. Install BPV and nipple down BOP. 10. NU tubing adapter and tree. 11. Pull BPV, install test plug and test tree. (5000 psi test) 12. Circulate Freeze protect through tree down IA. 13. Shut in well. 14. RDMO Below the current schematic of the well: Proposed Completion Rig Nordic #4 Stack measurements Note: To be confirmed when rigged up Top Flange Upper Lock Down Screws Rotary Table 8’ 5” 13’ 2” 14’ 3” 34’ to GL (Nordic Rig 4 RKB 33.5’ + 6” mats) 24’ 9” 25’ 3” 29.5” 85” RISER 16’ 4” Projected KILL LINE CHOKE LINE TOP OF WELL HOUSE 13’ 10” to GL 4-1/2” pipe rams 2-7/8” x 5” VBR rams Updated: 2/28/18Revision: 7Updated By: BWRig #4 Flowpath DiagramPIPE RAMS BLIND/SHEAR RAMS VBR RAMS BUFFER TANK MM 7 MM 8 MM 9 MM 6 MM 5 MM 2 MM 4 MUD GAS SEPERATOR SHAKER #2 SHAKER #1 ANNULAR MM 1 MM 10 MM 3 MM 14 PLUG VALVE CUTTINGS BOX MM 11 MM 12 SPARE CIRC LINE MM 13 FILL UP LINE FV -1 2" STAND PIPE 2" BLEEDER TO PITS TOP DRIVE GAUGE TREE CAPPED AT END 3" 5,000 PSI WP KILL LINE CM1 CM2 CM3 CM4 CM5 CM6 CM7 CM8 CM9 CM10 CM11 CM12 CM13 CM14 CM15 MANUAL CHOKE CM16 REMOTE ACTUATED MP 2 MM 15 MANUAL CHOKE MM GA 1 MM GA 2 MM SN 1 MM SN 2 SN 1 SN 2 CM GA 1 FLOW BACK TANK UKC (ACTUATED) LKC (MANUAL) TO MGS TO SHAKER MP 1 OPEN PORT CAPPED 3-1/8" 5,000 PSI WP CHOKE MANIFOLD Drilling Riser: 13-5M Flange x Hub KILL HCR INSIDE KILL CHOKE HCR MANUAL CHOKE 3" 5,000 PSI WP CHOKE LINE DV -1 SP -1 CV -1 FB -1 12" Flow line 8" vent line 20' long PRV 1 Pit 4 PRV 2 Pit 4 Spacer Spool: 13-5M Flange x Flange THE STATE 01ALAS- A GOVERNOR MIKE DUNLEAVY Stefano Pierfelici Well Operations Project Manager Eni US Operating Co. Inc. 3800 Centerpoint Drive, Suite 300 Anchorage, AK 99503 Re: Nikaitchuq Field, Schrader Bluff Oil Pool, OP03-P05 Permit to Drill Number: 208-137 Sundry Number: 319-053 Dear Mr. Pierfelici: Alaska Oil and Gas Conservation Commission 333 west Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 w .aogcc.alaska.gov Enclosed is the approved application for the sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, 10� Daniel T. Seamount, Jr. Commissioner DATED this day of February, 2019. SCANNED FEB 0 6 2019 LIVED STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION FEB 0 1 2019 APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 AP1<9^e% 1. Type of Request: Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Repair Well ❑ e s W down ❑ Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing Q - Change Approved Program ❑ Plug for Reddll ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other: ESP Change out Q 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: Ent US Operating Co. Inc. Exploratory ❑ Development Q • Stratigraphic Service El 208-137 ' 3. Address: 6. API Number: 3800 Centerpoint Drive, Ste. 300, Anchorage, AK 99503 50-029-23396-00-00 ' 7. If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require a spacing exception? Yes ❑ No ❑ OP03-P05 - 9. Pr y Dg ignation (Lease Number): 10. Field/Pool(s). A(m3C� /ADL355024, ADL355023' ADL390615• Nikaitchu 11.L �/5% PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD): II- 12391 J2QRq 12385 3934 1237 N/A N/A Casing Length Size MD TVD Burst Collapse Structura y Conductor 115' 20" 115' 115' Surface 2350' 13-3/8" 2350' 2158' 5,020 2,270 Intermediate 5960' 9-5/8" 5960' 3686' 6,870 4,760 Production Liner 6614 5-1/2" 12368 3934 1 Slotted Slotted Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 5960-12368 3686-3934 4-1/2" L-80 5344 Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): 12. Attachments: Proposal Summary .i Wellbore schematic L 13. Well Class after proposed work: Detailed Operations Program BOP Sketch Exploratory ❑ Stratigraphic ❑ Development Q Service ❑ 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: OIL Q WINJ ❑ WDSPL ❑ Suspended ❑ GAS ❑ WAG ❑ GSTOR ❑ SPLUG ❑ 16. Verbal Approval: Date: Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17. 1 hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name: Stefano Pierfelici Contact Name: Amjad Chaudhry Authorized Title: Well Operations Pr fact Mnager Contact Email: am ad.chaudh eni.com Contact Phone: 907-865-3379 Authorized Signature: Date: OZ O7 to COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: /t Plug Integrity ❑ BOP Test L!J M1eLchanical Integrity Test El Location Clearance Other: k 3500 psi 8() / LE �e3h /Yes Post Initial Injection MIT Req'd? ❑ No ❑ _ Spacing Exception Required? Yes ❑ No Q Subsequent Form Required: `o-7 c)q I C'' APPROVED 2— S l Approved by: COMMISSIONER THE COMMISSION Date: /I '� ` Form 10-403 Revised 412017 Approved applicatGisR111 tpr{ 04h/ �o�n tl, M? .� y��5 jjl�meubmin Duplicate /'T Cin lii Poearolle u� n� 3800 Centerpoint Drive Suite 300 Anchorage, Alaska 99503 Stefano Pierfelici Phone (907) 865-3320 Email: Stefano.pierfelici@eni.com February 151, 2019 Alaska Oil and Gas Conservation Commission 333 West 7" Avenue, Suite 100 Anchorage, Alaska 99501 RE: Application for Sundry Approval for OP03-P05 Rig Workover Dear Commissioners, ENI US Operating Co. Inc. hereby applies for a Workover Sundry for well OP03-P05. OP03-P05was completed on Oliktok Point on March 16", 2014 with an electric submersible pump set at a depth of 5,310' MD. This ESP producer was completed without a packer. The well was started up for production in March 2014. On July 7', 2017 an ESP failure was occurred and in December 2017 another WO was conducted and ESP was installed but in Janury 2018 it was stopped. Plan is to pull out ESP and complete it with new PCP system. Estimated date for beginning this work is March 111. 2018. Please find attached for the review of the Commission forms 10-403 and supporting documentation. If you have any questions or require further information, please contact Amjad Chaudhry at 907- 865-3379. Sincerely, Stefano Pierfelici Well Operations Project Manager OP03-P05 Workover — Summary Page PTD#:208-137 Current Status Well OP03-P05 is currently down due to an ESP failure. Scope of Work Scope of this workover is change ESP pump with a PCP system. General Well info Reservoir Pressure/TVD: This well is expected to have a static max bottom hole pressure of approximately 1670 psi (3,934' TVD) during the time of workover, which places the fluid level well below surface. Wellhead type/pressure rating: Vetco Gray, MB -247/5000 psi BOP configuration: Annular/blind/vbr/pipe rams TIFL/MIT-IA/MIT-OA: Intermediate cs�was tested to 200_0 psi on December 15`h, 2017. z, - Well Well type: Producer ®� Estimated start date: March 1" 2019 � z f - Drilling rig: Completion Engineer: Well Operations Project Manager: Nordic 4 Amjad Chaudhry: ami ad.chaudhry(a),eni.com Work: 907-865-3379 Stefano Pierfelici: Stefano.pierfelici@eni.com Work: 907-865-3320 Procedure: 1. MIRU Nordic 4. 2. Pump in bull heading 9.3 ppg KCl brine through tree. Pump in bull heading 9.3 ppg KCl brine in IA. Ensure well is killed. 3. Set BPV. ND tree and NU BOP and test to 3500 psi. 4. Start POOH completion. 5. Rig up Slick line and pull tubing stop check valve. 6. Circulate out remaining production fluid. 7. Continue POOH and lay down ESP assembly. 8. Perform a CO run, depend on the hole condition multiple CO run may require. 9. POOH and LD CO BHA 10. MU new PCP assembly and RIH to setting depth. 11. Land hanger, and test it. 12. Install BPV and nipple down BOP. / 13. NU tubing adapter and tree. 14. Pull BPV, install test plug and test tree. 15. Circulate Freeze protect through tree down IA. 16. Shut in well. 17. RDMO. Below the current schematic of the well: '*—� Tubing Hanger with 4" nom. Type'H" BPV profile Surf. Casing \ 13-318", 68 is V MD, 2,158' TVD 48° Inc. 5,460' MD, 3,663' TVD L7 - Baker SLXP Liner Hanger/Packer 5,735' MD – 3,644' T% Baker SLXP Liner HangerlPacker Nunn (Upper LateraMO fl 5 112" Oil Swell Pak #1 5,661' 5 112" Oil Swell Pak 92 6,053' 5 V2" Oil Swell Pak #3 7,409- 5 112" Oil Swell Pick #4 7.738' 5 1/T' ON Swell Pak Its 8.10T 5 1/r" Oil Swell Pck #6 9.507 5 112" Oa Swell Pak #7 10,199' Nikailc5ua Field- Olii Point 4L912.6ppf L-80 Hydnl-563 Production Tubing 4-W x-cplg cable clamps, for ESP Power Cable, (1) 318" Chem Inj Line 5.276.5' MD /3,482.1' TVD - Discharge Gauge Sub petroleum OP03-P05 Dual Lateral Producer with ESP Lift As Run Completion 5,327.6' MO / 3,501.6' TVD – Motor Gauge Sub 12/1912017 5,331' MO 13,504' TVD, 67° Inc– Bottom of Motor Centr4Nzer BHGE (ALS) ESP, 66 -stages PIex47SXF pump i 513 GS3BDB seals. 225HP MTRXP motor 5,335' MD / 3,504.5' TVD Bottom of 7-5/8" Shroud Assembly with cable and chemical injection W line feed-thrus 5-h' Silver Bullet Ecc. Nose Guide Shoe with Bent Joint 5,626-6,643' MD, 12385' MD HAL 5-•h' Oil Swell 5-W 15.5 ppf Planned Casing Exit Packer Slotted Liner TO of Ill A" OH Window r 12,391' MD, 3,933' TVD 89° Inc. IRM Interm. Casing \ Z 9.518", 47# HAL 5-h' Oil Swell 5,960' MD, 3,686' TVD Packer 82- Inc S -W Silver Bullet Ecd. Slottetl Liner, Nose Guide Shoe 5117 ppf 12,368' MD, 3,934' TVD 90P Inc. VetcoGray MB -247 SURFACE COMPLETION SYSTEM PRP 10161, NC 10 OF 10 23 JANUARY 2009 0 G_umaci own at w�jr8 2-7/8" x 5" VBR rams 4-1/2" pipe rams KILL LINE TOP OF WELL HOUSE 13' 10" to GL Rig Nordic #4 Well OP -18 Stack measurements Note: To be confirmed when rigged up mSIDE KILL KILL MaIUAL CHS CHOKE HCR CHOKE LINE Top Flange Upper Lock Down Screws 85" 7 RISER 16' 4" Projected 1911 25' 3" 34' to GL (Nordic Rig 4 RKB 33.5' + 6" mats) Draft 09-28-18 OF 7.1 r 0,`' I//7„.4' „.4' THE STAT Alaska Oil and Gas � ts1 of® LAsKA Conservation Commission %gett = _= 333 West Seventh Avenue *'� GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Main: 907.279.1433 ALAS' Fax: 907.276.7542 www.aogcc.alaska.gov Marc Kuck Drilling and Completions Engineering Manager OV 2 2 2 !. ENI US Operating, Co. Inc. 3800 Centerpoint Drive, Suite 300 Anchorage, AK 99503 Re: Nikaitchuq Field, Niakitchuq Pool, OP03-P05 Permit to Drill Number: 208-137 Sundry Number: 317-454 Dear Mr. Kuck: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown,a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Hollis S. French �,L Chair DATED this\2- day of October, 2017. RBDOMIS V Li 00 1 2017 • • RECEIVED STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION SEP 2 5 2Q17 APPLICATION FOR SUNDRY APPROVALS or-S /o/ )Z/I 20 MC 25.280 AOGGC 1.Type of Request: Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Repair Well ❑ Operations shutdown❑ Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing Q. Change Approved Program❑ Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other: ESP Change out Q 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: Eni US Operating Co.Inc. Exploratory ❑ Development Q, 208-137 3.Address: 6.API Number: Stratigraphic ❑ Service ❑ 3800 Centerpoint Drive,Ste.300,Anchorage,AK 99503 50-029-23396-00 4 7.If perforating: 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require a spacing exception? Yes ❑ No ❑ OP03-P05 • 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL337701,ADL355024,ADL355023, ADL390615 Nikaitchuq 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth TVD: MPSP(psi): Plugs(MD): Junk(MD): 12391 3933 12385 3934 747 N/A N/A Casing Length Size MD TVD Burst Collapse Structural Conductor 115' 20" 115' 115' Surface 2350' 13-3/8" 2350' 2158' 5,020 2,270 Intermediate 5960' 9-5/8" 5960' 3686' 6,870 4,760 Production Liner 6614 5-1/2" 12368 3934 Slotted Slotted Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 5960-12368 , 3686-3934 4-1/2" L-80 5344 Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft): 3'Y6al/PO 12.Attachments: Proposal Summary Q Wellbore schematic ❑ 13.Well Class after proposed work: Detailed Operations Program Q BOP Sketch ❑ Exploratory ❑ Stratigraphic ❑ Development El • Service ❑ 14.Estimated Date for 15.Well Status after proposed work: Commencing Operations: OCT is, }� ya,"i OIL ElWIND ❑ WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: GAS ❑ WAG ❑ GSTOR ❑ ❑ SPLUG Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 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: Marc Kuck Am ad Chaudhry Contact Name: j Authorized Title: Drilling&Completions Engineering Mnager Contact Email: amlad.chaudhnaenit2etroleum.com Contact Phone: 907-865-3379 Authorized Signature. � Date: 0'2,-////2— COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number p..4_ rk.,,.- , 3(7- 'f5'`f Plug Integrity El BOP Test Mechanical Integrity Test ❑ Location Clearance ❑ Other: 4 350c.( �p:� D C to /-----,-;f-- (-/�.'`. I-..,k v '�' r"-eQ 1,.fir' 1010,)I\r� h3 I.s-►, te_r .ix^ K..G r"(— pC._rc.}`�r;"t,-..5, `:t- $/1 4 C=ec_s v-i -t s- - I,1Zest p5 1- Post Initial Injection MIT Req Yes ❑ No ❑ V 7L Spacing Exception Required? Yes ❑ No 2r" Subsequent Form Required: t 0 —'/D tsi RBDNIS (i`.-Oe i 1 3 2017 APPROVED BY Approved by: 4:11 _�— COMMISSIONER THE COMMISSION Date: ib (11-111- *I fitti# /4,(‘—.0° 7, 7+ ,, ,,,,, dro, ./`` thSubmit Form and Form 10-403 Revised 4/2017 GfoGHENI or 12 months fro e date of approval. Attachments in Duplicate • i En11 PetirolleLuim troiot NeCEIVED 5 2017 3800 Centerpoint Drive Suite 300 Anchorage,Alaska 99503 Marc Kuck Phone(907) 865-3322 Email: marc.kuck@enipetroleum.com September 22`d , 2017 Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage,Alaska 99501 RE: Application for Sundry Approval for OP03-P05 Rig Workover Dear Commissioners, ENI US Operating Co. Inc. hereby applies for a Workover Sundry for well OP03-P05. OP03-P05was completed on Oliktok Point on March 16th, 2014 with an electric submersible pump set at a depth of 5,310' MD. This ESP producer was completed without a packer. The well was started up for production in March 2014 On July 7th, 2017 an ESP failure was occurred. The estimated date for beginning this work is October 15th, 2017. Please find attached for the review of the Commission forms 10-403 and supporting documentation. If you have any questions or require further information, please contact Amjad Chaudhry at 907- 865-3379. Sincerely, Marc Kuck Drilling& Completions Engineering Manager • • OP03-P05 Workover— Summary Page PTD#:208-137 Current Status Well OP03-P05 is currently down due to a ESP failure. Scope of Work Scope of this workover is change ESP pump. General Well info Reservoir Pressure/TVD: This well is expected to have a static max bottom hole pressure of approximately 1180 psi (3,686' TVD) during the time of workover, which places the fluid level well below surface. Wellhead type/pressure rating: Vetco Gray, MB-247/5000 psi BOP configuration: Annular/pipe/blind rams TIFL/MIT-IA/MIT-OA: Due to the completion design these tests were not performed. Intermediate csg 9 5/8" was tested prior to drill out on December 2008. Well type: Producer Estimated start date: October 15th 2017 AJ 4i CC_ Drilling rig: Nordic 4 N Completion Engineer: Amjad Chaudhry: amjad.chaudluy@enipetroleum.com Work: 907-865-3379 • • Procedure: 1. MIRU Nordic 4. 2. Shear upper GLM valve and pump in bullheading 8.6 ppg KC1 brine through tree. Pump in bullheading 8.6 ppg KC1 brine in IA. Ensure well is killed. 3. Set BPV. ND tree and NU BOP and test to 3500 psi. -- .11K,:41''�1"��/65 e -r`�� 4. Pull tubing to upper GLM. ...t-- �`�` �'`� `� " 5. Shear lower GLM valve and pump in bullheading 8.6 ppg KC1 brine. 6. Pull tubing to lower GLM. Rig up wireline and pull tubing stop check valve. 7. Circulate out remaining production fluid. e 8. Continue POOH and lay down ESP assembly. Zat�r. 3 (sad=CP 9. Perform a CO run „`._-- f t_, . '7Zs1' c Csl'-0 4.11 10. MU new ESP assembly and RIH to setting depth. I- /0'2.'17 11. Land hanger, and test it. 12. Install BPV and nipple down BOP. 13. NU tubing adapter and tree. 14. Pull BPV, install test plug and test tree. 15. Circulate Freeze protect through tree down IA. 16. Shut in well. 17. RDMO. Below the current schematic of the well: 4-W 12.6 ppf Production Tubing likik 2,040'MD,1,935'TVD 39°Inc-GLM,KBMG, 4-W x 1",with enl etroPeum 2,000 psi STS-1 SOV installed "_---.,_ 4-W x-cpig cable clamps,for ESP OP03-P05 Power Cable,(1)3/8"Chem Inj Line Dual Lateral Producer 5.096'MD,3,413'TVD,86°Inc-GLM,KBMG. 4-14"x 1", with ESP Lift j_ -� with 3,100 psi STS-1 SOV installed As Completed 5.199'MD,3,453'TVD-Discharge Gauge Sub 03/16/2014 .-.' ` 5,310'MD.3,495'TVD,87°Inc-Bottom of Motor Centralizer lio Centrilift,TTC-ESP,178 stage P18SXD pump+21 stage FCNPSH,513 GSB3DB seals,210 HP MSP motor 5,354'MD Shroud Assembly with cable and 5-W Silver Bullet Ecc.Nose /��♦ chemical injection line feed-thrus Guide Shoe with Bent Joint Surf.Casing "V�" 12.385'MD 5,626-5,643'MD, 13-3/8",68# V''' HAL 5-%a"Oil Swell TO of 8%"OH ,\ Planned Casing Exit 5-%"15.5 ppf 2,351'MD.2,158'TVD Packer Slotted Liner 12,391'MD,3,933' 48"Inc. Window TVD 89°Inc. 5,460'MD,3,553'TVD 1 411111.1.- _ law MIN= L1 -Baker SLXP Liner Hanger/Packer 5,735'MD-3.644'TVD, .11111111111111.11 -J Baker SLXP Liner ^�� Hanger/Packer '1` Item(Upper Lateral) MD(ft) \ „ „� ,",; - ,. 5 1/2"Oil Swell Pck#1 5 661' ""` 5 1/2"Oil Swell Pck#2 6.053' .1111111 Jilin JIIIIMMIlk 5 1/2"Oil Swell Pck#3 7.409' --... 5 1/2"Oil Swell Pck#4 7.738' /�/ 5 1/2"Oil Swell Pck#5 8.107 Inlerm.Casing / 5-1/2"Silver Bullet Ecc. Slotted Liner, 5 1/2"Oil Swell Pck#6 9.509' 9-618".47# HAI.!. Coil swell Nose Guide Shoe 5-'''/"17 ppf 5 1/2"Oil Swell Pck#7 10,199' 5,960'MD,3,686'TVD Packer 12,368'MD,3,934'TVD 82°Inc. 80°Inc. Nlkaitchuq Field-Oliktok Point . • • (Iii[ N\liO p x u a 3 Ii O0 W Iv, M J V -c V V w W '8 p. Y R Z m U J Yl L 4 zO aQx V O .,., N N c Z c . ,., ,I . N _ 8 3 III • IIL- ,,,, y 0' is; - ce arn z m III IIII ,,,, • • z2 ', a. J J = a I A Mild i W Z J J Y a 17 a 0 0 0 at; m - 'I • • Rig 4 BOP Schematic SUF,r7"N - F,,,„,, ii.0 ANNULAR PREVENTER ....,_.. -----_,.......................miimu ,,, VBR ram 14 u k• 5/11' ...if Blind Shear _.. 10••••• ,,,'W 1 ' 0111111111111 °i I i • • .1r ' III.V4 I* (EE Maim IF' II10:0)::1 CHOKE CHOKE if pi. INSIDE HCR KILL KILL ,40• 0 1 HCR 46. 11111 ,,iii 11111 3" 5,000 PSI WP _ ,.. ----" -i lip ,,,,, 11111 11111 11111 111 4 11 CHOKE LINE RETURN TO CHOKE 11111 ..„ I I II I '',-,...„.,.....„‘,.., --.... Ciaa3 3t:la SUPERCEDED eIEAAIPRIM•oe...igMMMWMM•npg.M.O.••mN.M.72r•IMICVCt•M..21••IitII.EMIMOIMIMI. 1 • o NO 3 1/8" 5000# NACE TRIM CHOKE & KILL MANIFOLD SYSTEM MAY 2016 ITEM SERIAL # CUST. I.D. DESCRIPTION 1 AS1410024 PV-4519 3-1/8" 5000# CNV SLAB GATE VALVE 2 14110802 PV-4520 3-1/8" 5000#x 3" XXH BUTT WELD FLANGE 3 AS1410021 PV-4521 3-1/8" 5000# CNV SLAB GATE VALVE 4 14110802 PV-4522 3-1/8" 5000#x 3" XXH BUTT WELD FLANGE 5 AS1410018 PV-4523 3-1/8" 5000# CNV SLAB GATE VALVE 6 14110802 PV-4524 3-1/8" 5000#x 3" XXH BUTT WELD FLANGE 7 A9877A PV-4525 3-1/8" 5000# BLIND FLANGE 8 AS1410020 PV-4526 3-1/8" 5000# CNV SLAB GATE VALVE 9 C16363 PV-4527 3-1/8" 5000#x 9.125" OAL FLANGED SPACER SPOOL 10 Q22831-1 PV-4528 3-1/8" 5000# Q.O.T SWACO STYLE ACTUATED CHOKE 11 AS1410015 PV-4529 3-1/8" 5000# CNV SLAB GATE VALVE 12 AS1410014 PV-4530 3-1/8" 5000# CNV SLAB GATE VALVE 13 14110802 PV-4531 3-1/8" 5000#x 3" XXH BUTT WELD FLANGE 14 AS1410017 _ PV-4532 3-1/8" 5000# CNV SLAB GATE VALVE 3-1/8" x 3-1/8" x 3-1/8" x 3-1/8" x 2-1/16" 5000# STUDDED 15 N/A PV-4076 5-WAY BLOCK 16 AS1410010 PV-4533 3-1/8" 5000# CNV SLAB GATE VALVE 17 AS1410016 PV-4534 3-1/8" 5000# CNV SLAB GATE VALVE 17A CC141554/1-1 PV-4535 3-1/8" 5000# CORTEC "NH-2" ADJUSTABLE CHOKE 18 AS1410023 PV-4536 3-1/8" 5000#CNV SLAB GATE VALVE 19 AS1410025 PV-4537 3-1/8" 5000# CNV SLAB GATE VALVE 20 N/A PV-4538 3-1/8" 5000" x 12.75" OAL FLANGED SPACER SPOOL 21 AS1410026 PV-4539 3-1/8" 5000# CNV SLAB GATE VALVE 9" NOMINAL BORE BUFFER CHAMBER 22 68870-ACD PV-4540 c/w 8-3-1/8" INLET/OUTLET FLANGES 23 AS1410009 PV-4541 3-1/8" 5000# CNV SLAB GATE VALVE 24 31 KA6443 PV-4542 3-1/8" 5000#x 3" WECO UNION FLANGE 25 AS1407007 PV-4543 2-1/16" 5000# CNV SLAB GATE VALVE 26 17DC1350 PV-4544 2-1/16" 5000#x 2" WECO UNION FLANGE 1 • • • I9 r1 r,2,, vi i INA—AIS W CO ,rS . i i 4+1.:* :_I `--� +�Ic� _� w F- w Z J >- Y - A 0 Z 06 Q 74\ e ,n ( w0o lc o e i. co 2 O Z cv H c%) 1- U2 d 0 \ t.: ;- I > M I: ^+z�r *WO OW 01010 . OVONii U7 , 2 Z o Q 0 O cc U a®.. U 6 =�. >- 0 - - CM o +it. 2-* O N z — — - �� Q __1( =J ' II Z X Li T `�I a�: a 4�j r CO 2 U g cn O U a N N co CO W M DO � W L a_ '+:�c�' n_ W_ _WCO Lo > > N N Q — Q I WO .9'901. �. -4 ' W > 0-1OdINVW H1 .dO W01109 S _e • VetcoGray MB-247 SURFACE COMPLETION SYSTEM N/CL 50 �•� "-15 37.19 _ II CI' ss M. 111r---------63 111 lufoo ■ISI Ii nt ___' ,---. ' rn 'I elltrAuk ''' ieP ON* ii lit,--' cip id:: di i _• �4 'I'��� T.O.S. EL 26' 5-3/4" :7411111 X 062 OFFSET C/L I B.O.S. EL 25' 7-1/4" Q TOP OF WELLHEAD 5.00" EL 25. 2-1/4" 1 \ r L.� O O 11119 1 CPFT � ` FEEDIHPU 21.61 ora 1 . j I /: 1 1 13-5/8'5000 PSI -- j VG 5137 CLAMP II em1r. r_ 11011♦ . 12■11 R. """1"""" 4-1/16" ll 50 00 PSI 'A II '� '. d, : -'rrl 71lII Il.�� --..-a-..C.1 A�pi I'I'll! • OFFSET 10I.0 6.50* ,III 11� .--.7,..:1-1 5000'PSI Ii■ 2-1/18' 7,7II ' _.••r}.• S= �� �.''ri 5000 PSI ;' ®..- ,, ��__.� I. 66.71 OUT O ' a � iii POSmON - .ter; jL- 13'5000 PSI 52.96' , h�,, 1N VG 134 MOD. L___-_._26.5: ir. i. j .Z., ■ '..',.. t :� 34.00' 2-1/16'. I ♦:..1. ': 5000 PSI .1 IL OUT OF 24.2 ert .'. ' 15.25" PosmoN •_ TOP OF GRADING �ti .- f I 1 r EL 16TOG 1/4 • L1.00 PROPRICTMY WOOL CO �. .airgrr Y- 20' OD 133# K-55 ` I�•j4-•4 13-3/8" 0D 66# L-60 1 • °1�'V^ ENI ALASKA 9-5/8" OD 53.5(1 L-80 WOW HORIZONTAL MULTI-BOWL SYSTEM ARADO 4-1/2" OD WITH 6-5/8 VTI) .L....., 20 X 13-3/8 X 9-5/8 X E X 4-1/2 WITH 6-5/8 VII mum AND ESP FLAT CABLE 23 MRL CO ca 4).i VI°�...lr' H173370-1 (A�'' a l >a+'Pmmc XI...XX XI4a1 S I.m a1 PRP 10161, NC 10 OF 10 23 JANUARY 2009 0./r , • • Schwartz, Guy L (DOA) From: Kuck Marc <marc.kuck@enipetroieum.com> Sent: Wednesday, October 11, 2017 1:24 PM To: Schwartz, Guy L(DOA) Cc: amiad.chaudhry@enipetroleum.com; Regg,James B (DOA) Subject: RE:OP03-P05 (PTD 208-137) RWO and Nordic 4 Attachments: R4 One Line Diagram 10-05-17 modified BOP stack add single.pdf;Special Shear Test Report ER02058 reduced.pdf; 501661-RE-A-0007.pdf; NOV-Shaffer FAT AX060172-Test Spec.pdf; 13-5 LXT Shear Calcs Larry Lehmann 1-29-16.pdf; BOP Pressure Tests.pdf; Post Shear MPI.PDF Guy, We will add the 2,000 psi casing test to the workover program. I am attaching the updated BOP schematic that includes the Pipe,VBR and Blind/Shear rams. We are running a kill line on the Blind/Shear and a choke on the Pipe rams. Our company policy does not include the mud cross as this is viewed as a possible weak point in the system as the BOP is a solid body. The BOPE will be inspected and tested prior to all use and maintained as necessary. I am also attaching the shear test we performed on this BOP stack for your reference with tubing, ESP cable and cap strings included. We are still compiling the full rig book and will pass to you when completed...should have in a few days. Thanks, Marc From: Schwartz, Guy L(DOA) [mailto:guy.schwartz@alaska.gov] Sent: Monday, October 02, 2017 2:06 PM To: Kuck Marc Cc: amiad.chaudhry@enipetroleum.com; Regg, James B(DOA) Subject: OP03-P05 (PTD 208-137) RWO and Nordic 4 Amiad/Marc: In reviewing the sundry for this RWO I assume this will be the first well for the new rig Nordic 4. This will require an inspection once the rig is over the well and ready to test BOPE. I checked with Jim and he has not seen a rig book yet.... We won't do an inspection until we have one in hand and we generally want some time to review it before the inspection&BOPE test. A couple of things I noticed specific to the sundry. 1. The casing has not been tested since 2008 so am requiring a 2000 psi test as part of the program. In general, the AOGCC recommends a casing test at least once every 8 years on producing wells. 2. The BOPE setup doesn't have a mud cross for the choke and kill lines. What is the reason for the omission? Our preference is to always use one as there are concerns with erosion of the BOPE body whenever fluid is pumped or returns are taken through the choke line.This can impact long term BOPE performance. 3. We will need BOPE shear ram test specs/results as part of the rig book. Regards, 1 • • • Guy Schwartz Sr. Petroleum Engineer AOGCC 907-301-4533 cell 907-793-1226 office 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 Guy Schwartz at(907-793-1226) or(Guy.schwartz@alaska.gov). This message may contain information that is confidential, and is being sent exclusively to the Recipient. If you are not the designated Recipient, you are prohibited from utilizing, copying or divulging the information contained in this message,or taking any action whatsoever on the basis of the information herein. If you have received this message by mistake,we ask you to kindly inform the Sender and to delete the message. It is understood that, with regard to messages sent by its network, the Company is not responsible for any statements made or opinions expressed, that are not strictly related to the Company's operations. 2 w O a W w W Z J IL 22 c O - Do U (3) J Q M� ,W V/ LQ r L 0 a M O a O O H Y z O z E E m z L` 0 E O N Df af J v 0 of m of m o. of o, m of 0� 0l o of o� c c � E o 0 0 0 0 o 0 0 0 0 0 0 0 0 0 0 0 0 0 o 0 4 4 p N J J J J J J J J J J J J J J J J J J U U m 9 O N Z L d N p V Or 0 W I Z 0 E E O c my OLL z W p Q N J F —A O) O) O) Ol O7 m °l m Ol o) OI O) 0) O) m O7 °l O7 Ol 0) a T � O� T J J J J J J J J J J J J J J J J J J J J c m ❑ Z W O O O 0 0 N N U U O l ❑ ❑ O O 0) O N (NJ Q) °� m 00O O C zJOb p o E m z O 0 OO O J10 E o J o a m c m ° U m ❑ m ° m ❑ ❑ ❑ VI J S] C T U OI C N U O7 c o E E o T ❑ E E ❑ c - c W W EE E ❑ LL' C _ LL J C9 ❑ LL J U ❑ U❑ j ❑ j ❑ cl O j m m m m m m m m m m m > > y o 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 o O O o 0 0 0 o O o 0 0 0 0 0 0 0 0 0 0 � N N N N N N N N N N N N N N N N N N N N Q Q Q N) Q N N y N N NNN N N N N N N N N N N N N ZZ K N N N N N N N N N N N N N N N N N N N N C C C C C C C C C C C C C C C C C C C C N d N N N N O N O N N O N N N N N N O N 000 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 d � N � � � � l0 Il0 N N N N � M M M M V V m m m m m m m v v e v o a v a v v e r n O M M m M m M mo 0 0 0 tOp cOp c°O d r o 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 o m y O O O O O O O O O O O O O O O O O O N h O a:z A v o ^' 75 o o b o 0 0 0 0 0 0 0 0 0 o b o 0 0 0 J 2U U U U U U U U U U U U U U U U U U U U rnR J y N N N N N N N N N N N N N N N N N N N l° rn m c 0 a 3 T T 0 0 N O Z O N N N N N N LU C) W❑ IA � U N N ❑ � � ❑ ❑ � _ _ _ t0 o ❑ 3 0 ❑ 3 '� N N N UU Z Z Z Z Z Z U m U N a a N N N N O❑ N O❑ N m a Z 4 4 4 0 0 `o 0 c c m 0 0- m o a v C tq N N N ❑ ❑ ❑ ❑ ~ (� C ~ U J p a 0== W W W W N N 0.--- 0=— ❑ ❑ m m w W K K W W n'mco nmm o O W 0 N N N X K W LL' 0: 0: D: 0 L. 0: Q V m of K K w U U U 0 U U d y.3 a v N o o a > Z > > ❑ ❑ 33� 33� 00 m =° U c9 C7 C7 C7 r o 0 F a a m m m a wUK w0`K ILL > e O 07a D7 O 0 0 D7 0 a Of A 0 m U o 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 N N N N N N N N N N N N N N_ N N N N N N N N N N N N N N N C C C C C C C C C C C C C C C J 6 6 6 d d ¢ 6 ¢ ¢ ¢ ¢ 6 n n n U U U U U U U U U U U U U U U U r r r o o a a m M o1°i M m o 0 0 0 0 0 0 o n M O r r r r r (OD tOa � t00 O O � N y 00 0 0° 0 0 0 0 0 0 0 0 0 0 0 m m 0 0 m m m o 0 0 0 o m m E U J U ❑ W ❑ m w 3 C E E m 0 a U E n E z N Z rn rn 0 0 � O O > O O 'd N N U � � K a m d 0 O O ry U U J U O p UUU U U U U UUU 0 M r N N O 10 N N O h N h N a cl 0 6 n m O .T. L' .T. .T. .T. .T. N (/ VI 1/i Vl N N N VI N N a N a a a a a a a a C C K K D:: K K K K K ILL ILL 000000000`00 _ _ _ _ _ _ _ _ _ _ r r O f M U ❑ a 0 J 0 J 0 J 0 J 0 J 0 J 0 J 0 J 0 J 0 J 0 J M ❑ W J U ❑ W ❑ m w 3 C E E m 0 a U E n E z N Z rn rn 0 0 � O O > O O 'd N N U � � K a m d 0 O O ry U U J U O r O CL w w W U Z a 0. J r 0 O- UN m J a F- �2 In U) Q L a 0 L .l G d 3 Z U_ E E d V d n O .L. C d E E O V 11 1m VL/ m D K U C A 6 E 0 U m m N 0 o 0 0 M N N m M m � � m > T V- K h Z N U O N C a O O L E y U U K .L. C d E E O V 11 1m VL/ m D K U C A 6 E 0 U • • r-- co M 9 . tp -0° /y Q O t71 s. N r N W N N co N m O co' �D m m V- N m a O a m V LL ^ o n O n n • r 01 of �n t� n m n h m m O W O U U 2 m O) 8 m O M m m CO n co )n„ T b n N n 0) 0 CO V M o o as 0 a V M 0) M m 0) CO CO V r N N N M M N V N N M V N M • N W H GV CD r/ 78 W O N - N_ 0 N O M N v) C7 m O) M O ra m m fA CO CO 10 CO n CO N CO �+ C N O a O N P. CO U3 A N m g m W V N 0) M p CO N N CO. n ECC N M N V {� am V n V O N V N Y] N a) N M M N V V M V V FO O Ca— s. 3 W I _ CJ`) LL Oo 2 :co co m to co N co m m O CA ts CO CO O Is .n Is W m ^ N W N O) n m Q Ci co ea r C o iYi z w S �, N cr Y C co J m m 10. CO CO r N N O) m M O m Of V 10 Oj r n M 10 n .8 m V `O ? r N M Prm V M N 8 a I N V f+) N N N 0 m m V 1` g 2 N a Y_ > m Z = Z O _ s` CO ou a) CC/ dn n N CO m N CO O N 0) CO CO m M O O) 0) CO U) O CO u) N CO 0 O 0) m Eo a E n n m n n P n CO n n m m n CO CO n CO CO n CO N- n N- CO n b n co N y~ o O i— 0 U R r o 0. (L W C 5 or N N N N N N N N N N 0 M M la 0 N N n M N N N N N 0 Q ret- ' Ol r r r r r r r r r r r r r r r r r O CO Y Q C C 0 5 r w N 2 J CO' w 6 O iiid QCO Y N .0 P O Z JU N NI 10 0 0) co N Ma s O 0) 0 M N 0 M 0) V CO 0 N n 0 CO M M W W O OO) 0) mO0) Ona) O tr r r r r V YM O M V V N) MN U) 0MMVV M V NNNNNNNNNNNNNNNNNN LII U O F /) N do Q Y , J W Q H C M O n N N Is..... 00 O V n v n co O O CO co co co M co co N CO n r n t y w O O) O) w O) p W 0. •m m v V O) m M V u) u) V7 r N V m Q O CO N N r eqi N M N N N N N N N N N C J 0 a U 0 eO t c r M n m O N n M CO n m N n N O V O O W V O) m M O) M COO O O O COm com O m O V O m m V 1t) m N N n N N M 2 vi co F N r Ca N r N N N CONN C7 N N N N N N N N N N N N M C gco Qa p7 O m co CO co m m m m m W m CO m a) V m m m O CO m m m m V m n N Ti cY N N V 3 N N W N N N N N N M N N V N N . N N m ,- ^ N a a) O r r r r r r r r r r 0 co .0 W "0-. to U d 1 a 2 x 0 o a) a 2 g d O 0 N O m it) )0 b 0 O N CO O N 10 a) 10 O O O 10 10 U) N 1n 0 0 10 0 u7 ,5 E C W N z t-i z a m 4a as 5 m m m CO CO CO CO CO CO CO CO CO CO co m co co co co CO co co co co CO CO CO co co r, S e C a5 d d d ri d 6a3 d o) )E d d d r d a; N el. c6 em $ d d d ab .2 o m W o 00 o Oo 0 o OO $ oo ID 5 g X O O o O o 0 0 o q n o o W XXyXy d 0 m d, 1b n N o) N r alb aoS d ao d m co 1d N d N y U.. Z X COO O N aN �A eA A yA app +A O} co gym} tf) Q 10 O 1a 1 sn� ia0 Y7 1V0 A ti '4 °Vm Oaf y XX M co NI M NI t+) C") M l0 N f+) co M t0 M M M M M N N a•J a! M l") M t") {� E C Q N N N N N N N N N N N N N N N N N N N N N N N N N N N N N N W` g, N N N N N N N N N N N N N N N N N N N N N N N N N N N N N N .. �' O C '0 Le E m o Z. E g W 10 n m co N Z n 10 n O M M 1 m W c a m z q o 0 0 S o M o o m w w z n z w z cn 3 z 0 w � °� I E Z ° ay a a , a a Co a a o 1= of oi u. zi a to a z z u. z CO z z .. 5 2 C on E a a g. 3 g g 8 d N a5 )L co m g 8 8 d N d m g c h m cA `b d a co 'E > 0 0 0 0 0 0 0 0 0 0 0 0 0 CO COaW co to cn to w 0 co co co co to N O co 7 — fix- Eni E&P Division — — V w.n Nam.:. 3-P05 Daily Report Wen Code: 22827 ENI Petrole um Field Name: Nikaitchuq CO. Inc. Date: 1111312008 - Report#: 7 APVUWI: 50529-23396-00 Eni Wellbore name: Original Hole page 7 of 1 Well Header Permlt/Concesslen N° Op*nbr ENI Shu"""" Woll Corrflgulellen type Oliklok Point 208-137 ENIPETROLEUM 100.00 DIRECTIONAL Rotary Table Elevation (n) around Level (n) Water Depth (R) RKB - Base Flange (R) RKB -Tubing Bpoel (R) 41.00 12.20 9.43 8.85 Rig Information Contractor Rig NameRig Type NABORS ALASKA NABORS 245E LANDRIG Job Information WNlbero Job Phase Spud Dab Target Depth (nKB) Target Depth (TV... Drilled Depth (n) Drilling Neuro (hrs) Average ROP (R/hr) DFS (days) 1 Odginal Hole DRILLING 11/16/2008 13,374.0 25,234.00 163.47 154.4 -2.56 Daffv Information Depth End (RKB) Depth End (TVD) (... Depth Progress (n) Drilling Hours (hro) Average ROP (R/hr) POB Temperature ('F) Weather Wintl 83.0 14.0 PC, light snow, WC E 90° @ 7 mph 3' Daily summary operation 201, Forecast Rig up and spud well. 24h Summary Continue rig up for spud. Operation at 07.00 Continue welding Flashing around cellar box, cutting of walkway from cuttings holding tank, continue run base oil line. Lithology Shows MAASP Pressure(psi) Mud Welgh!(IWoal) Time Lo Cum Start End Dur Dur Thne Time (hre) (hre) phase Gin AOL Plan Oper. Dsser. 00:00 12:00 1200 12.00 PREP A 1 P PTSM Continue cleaning raw mud pits with CH21ylHill vac -truck, general housekeeping of entire rig, cut and remme desilter return line and weld in place. Weld in two each 4" nipples on conductor pipe at 60' angle and install 4" ball valves on same (Vetco Gray Rep.'Rowdy' witness installation). Cut mutl pits cuttings chute trunk -hose to length. Shorten up conveyor drag chain to correct length for adjusbnent. Organize Nabors 245E pad, rig modules, and location in preparation for spudding well. Last load of MI Swaco mud products arrived on location, offload same. Stage all liquid mud products in 110% containment on OPP. 12:00 00:00 12.00 24.00 PREP A 1 P PTSM. Pick up and rack back 66 joints of 5" drillpipe in derrick. ENI Petroleum group tour arrived on location at 12:20 pm and inspected entire rig and location. Finishing insulating cellar wind walls and welding Flashing around cellar box. Finish cutting and move desilter return line. Install walkways to service modules on tap of utility module. Install drilling line kick rollers on drawworks drum guards. Cut hole in cellar windwalls for diverter line rig up. Rig up wire cables to traveling block bales and Hydril lining eyes to take weigh of hydril for orientation of diverter spool to make up diverter line. CH2MHill delivered Schlumberger cement bulk tanks to OPP. offload and spot same. DWO-0500 Align diverter spool, clean area to bring in diverter line. Continue welding Flashing around cellar box. Move cuttings holding tank to welding shop and cut off walkway. Start running lines from LET base oil holding tank to shakers. Daily Contacts Posillon Contact Nam Cenparry THIS EarMll OMs* Mobile Eni representative Scott Beauchamp Eni Petroleum Drilling Supervisor sooh.beauchamp@enipstroleum.cam 9078705580 907-841-8759 Eni representative Bobby Walls Eni Petroleum Drilling Supervisor bobby.walls@enipetroleum.com 9075705580 Eni representative Bemis Leas Eni Petroleum Rig Clerk bemie.leas@enipetroleum.com 9075705560 907575-9427 Eni representative Greg Parker Eni Petroleum Expediter 907-980-7545 907-980-7545 Eni representative Joe Longo Eni Petroleum Ong Engr. 907565-3323 Eni representative Tom Gennings Eni Petroleum Drlg 8 Comp Sup. 9075655224 Last Casino seat Cas. pa iOD (In ID (In) Chad* TOP RKB) SWbm (RKB) Run Date CONDUCTOR 20 18.250 X85 U.Ul 154.0 9/25/2008 Lost Leakofl Test Depth (nKB) TVD (Me) Fluid Type Fluid Density (ib/gal) P (Burr) (Psi) Eq. Mud Weight (lb/gal) Leak Off Pleasure (psi) 6.62 Eni E&P Division fl�ifae C�r�rf _• ENI Petroleum Inc. "ally '%1UN`"c Date: 11/1412008 - Report#: 8 Wen code:2ze27Nika FleId Name: itohuR APIIUM: 50-029-23396-00i l Wellbore name: Original Hole EnCo. page 1 of 1 Well Header PemOtiConeesslon N• Oliktok Point 208-137 Operator ENIPETROLEUM ENI Sham (%) lWell 100.00 IDIRECTIONAL Configuradon type Rotary Table Elevation (R) 41.00 Ground Level(R) )2 20 Water Depth (R) RKB - Bass Merge (R) 9.43 RKB - Tubing Spool (R) 8.85 Ric Information Contractor NABORS ALASKA Rig Name NABORS 245E Rig Type LAND RIG Job Information Wellbore Original Hale Job Phase DRILLING SpudDate 11/16/2008 Target Depth 13,374.0 Target Depth (TV... Drilled Depth (R) 25,234.00 DRlling Hours (hre) 163.47 Averogs ROP (fill 1544 OPS (days) -1.56 Dail Information Depth End (RKB) Depth End (TVD) (... Depth Progress (R) Drilling Hours (hrs) Average ROP (RMr) POB 83.0 Temperature (°F) Wool Wlntl Daily summary operation 24h Forecast Rig up and spud well. Nis Summary Continuie rig up for spud. Operation at 07.00 Continue rigging up for spud. Llthology Shows MAASP Pressure (psi) Mud Welght (ib/gall Time Lo Cum Start Tile, End The, Dur (11i Our (hm) Phase Opr. AeL Pian Oper. Dow. 0000 12:00 12.00 12.00 PREP C 1 P PTSM. Set and align diverter tee -spool Steck, cut out hole in cellar box wall for diverter line installation. Clean up knRe valve and threads, install diverter knife valve, lie in and nipple up diverter line. Run in lock down screws on 20" speed head. Cut and thread 2" pipe with clamps and plumb in LTV line. Move second contingency cutting tank to Nabors welding shop to remove walkway from drillers side to off drillers side. Weld in Poor plate around heater trunk exit in cella wind well, replace bent piping and replace fittings below, casing jumper hose for rig floor to remote casing unit line. General housekeeping and maintenance. Welder cominue to work on welding out flashing top and bottom of cellar box wind wells. GCI continue to rig up communications in Kenai camp. Epoch continue to rig up monitors and rig up gas line chromatograph lines. Rig electricians work on wiring up miscellaneous items on rig, rigging up wiring on Nabors shop trailer on ground. Nabors forklift driver unloaded 2000 o`2 3M' HTSLH90 tubulars and unload Hydril 2 318" fixed pipe rems. 12:00 00:00 12.00 24.00 PREP C 1 P PTSM. Continue nipple up surface stack, connect flowJkne, bleeder line, and hole fill line. Secure stack with tum buckles. Anchor down diverter line. Plumb in and connect Koomey control lines to diverter knife valve, function same,o.k Troubleshoot and adjust crown sever to desired height. Mixing spud mud. Continue welding flashing in cellar. Finish installing drill line kick rollers on drewworks. Continue plumbing in LVT tine in shaker room. Prep for pre -spud as per pre -spud check list. 0000-0500 Fork lift driver install catch pan under end of diverter line and moving 13 3/8" casing into pipe shed. Mixing spud mud. Rigging dni lour for picking up BHA. Function test diverter bag and knife valve. Walder continue welding flashing around cellar and cellar box. Daily Contacts Position contort Name cerapa TRIG EanaB OMw Mobile Eni representative Jack Eni representative Bobby Ent representative Bernie Eni representative Greg Ent representative Joe Eni representative Tom Keener Eni Petroleum Walls Eni Petroleum Leas Eni Petroleum Parker Ent Petroleum Longo Eni Petroleum Gennings Eni Petroleum Drilling Supervisor Drilling Supervisor Rig Clerk Expediter Ddg Engr. Drlg&Comp Sup. jack.keener@enipstrokeum.com bobby.walls@empetrokeum.can bemie.leas@empetrokeum.com 907-670-8580 9078705580 9075705580 907-980-7545 907565-3323 907-865-3224 907-715-6434 907,575-9427 907-9807545 Last Casing seat cos. Type OD (Inti ID Ilnl i Grade T (RKB)Bottom (RKB) Run Dab CONDUCTOR 20 18.250 X55 0.0 154.0 9/252008 Last Leakoff Test DepM (RKB) TVD (IRKS) Fluid Type Fiultl Density (Ib/gaq P (Surf) (Pal) Eq. Mud Weight (Iblgal) Leak OR Pressure (psi) Eni E&P Division Ws11 Name: - 3-P05 Daily Report EN/Petroleum PlaidNtl.:22627 Flab Name: Nikeilchuq Co. Inc. Date: 11/15/2008 - Report #: 9 APII-0292339600 Eni Wellbore name: Original Hole page 1 of 1 Well Header PermlUConeeealon N° Operator ENI Share (%) Well Configuration type Oliktok Point 206-137 JENI PETROLEUM 1 100.00 DIRECTIONAL Retry Table Elevation (R) around Level (n) Waver Depth (R) RKS - Base Flange (R) RKB - Tubing SPool jR) 41 00 12.20 9.43 8.85 Rig Information Contractor Rig Name Rig Type NABORS ALASKA NABORS 245 E LAND RIG Job Information WNlbore Job Phase Spud Dab Target Depth (RKB) Target Depth (TV... Drilled Depth (R) Odiling Noun (hn) Ave Me ROP (it/hr) OFS (days) Original Hole DRILLING 11116/2008 13,374.0 25,234.00 163.47 154.4 -0.56 Dail Information Depth End (flKB) Depth End (... Depth Progress (R) Ddlllne Hoare (nrs) AveroBa ROP (R/hr) POB Temperature (°F) Weather Wintl 3460 346.0.0 221.00 4.00 55.3 70.0 -9.0 Pertly Cloudy 090' at 6 mph Daily summary operation 24h Foreeut Repair leaking knife valve, ng up Gyro Data, pick up BHA, spud in and drill ahead. 24h Summary Continue ng up to spud in. Operation at 07.00 Pick up BHA. Lltholegy Shows MAASP Pressure (psi) Mud Weight (1 1) Time Lo cum start End our our Time Time (his) (hm) Phase opr. ACL pW1 Oper. pastor. 00:00 06:00 6.00 6.00 PREP A 1 P PTSM. Nipple up diverter system, anchor diverter line and set cuttings bucket under end of diverter line. Finish banning cuttings tank and install key stock in elevator pins. Weld drilling line kick back rollers on drawworks and weld out cellar box. Continue muting 600 bbls spud mud, remove thread protectors from 13 3/8" casing in pipe shed, and bring up xover and stabilizer to ng floor for BHA. 06:00 09:30 3.50 9.50 PREP A 1 P Continue welding flashing on cellar box and rig up cellar pump. 09:30 11:00 1.50 11.00 PREP A 1 P Simulate diverter evacuation drill and man down drill with ENI and support crews. 1100 12:00 1.00 12.00 PREP A 1 TR04 Change out leaking o -ring an top drive. 12:00 16:00 4.00 16.00 PREP A 1 P PTSM. Pick up stand of drillpipe, function Hydril and diverter knife valve for John Crisp (Alaska State Man). Bag closed in 35 seconds and knife valve opened in 20 seconds. Draw down test at Koomey unit 2 minutes 20 seconds. Function lest fire alarms, gas detectors, and PVT alarms. 16:00 18:30 1 2.601 18.50 PREP JA 1 T503 Imempt to funci0n test PVTS on Epoch/rig watch. Troubleshoot and repair system as per Caning. 1830 21:30 3.00 21.50 PREP JA 11 ITRO5 Fill surface sick with weer knife valve leaking, tire in stick. 2130 23:00 1.50 23.00 PREP A 1 P Simulate diverter evacuation dnll and man down tlrill with ENI end supportcrews. 23:00 00:00 1.00 24.00 PREP A 1 TR05 Troubleshoot leaking diverter knife valve. 0000-0500 Troubleshoot and repair diverter knife valve. Fill stack with water, no leaks, check flow sensor, a.k. Prepare to rig up Gyro Data wireline and pick up BHA. Dail Contacts P>sisen Cemaat Name Ce"MY 7111 Ematl OlOae Mahle Eni representative Jack Keener Eni Petroleum Drilling Supervisor jackkeener®enipetroleum.com 907570.8580 907-7155434 Eni representative Bobby Walls Eni Petroleum Drilling Supervisor bobby.walls@anipetroleum.com 9075705580 Eni representative Bemie Leas Eni Petroleum Rig Cleric bemie.leas@empelroleum.corn 9075705580 907575-9427 Eni representative Greg Parker Eni Petroleum Expediter 907-980.7545 907-9804545 Eni representative Joe Longo Eni Petroleum Drlg Engc 907-865-3323 Eni representilive Tom Cannings Eni Petroleum Drlg & Comp But. 907-8853224 Last Casino seat Cas. Type i oil 10 (MI Grade T (RKB) Beeem (itKB) i Run Dab CONDUCTOR 20 18.250 %55 0.0 154.0 9/25/2008 Last LeakoN Test Depth (RKB) TVD jRKB) Fluid Type Fluid Density (lb/gal) P (Surf) (psi) Eq. Mud Welght (Ib/ga1) Leak OR Pressure (PN) Eni E&P Division ENI Petroleum EniCo. Inc. _ n Well Name: A-P05 Daily Report Well Cotls: 22'k Field Name: Nika Date: 11/16/2008 - Report#: 10 API/UHO: 50-029-23396.00 page 1 of 1 Wellbore name: Original Hole Well Header Pis ItfCones uslon N° Oli7 Point 209-137 Operator ENIPETROLEUM ENI Shan (%) 100.00 Well CeMlBuragon type DIRECTIONAL Rotary Table FJevaBon (R) 41.00 Ground Laves (ft) 12.20 Water Depth (n) RKB - Base Flange (R) 9.43 FIND -Tubing Spool (R) 8.85 Rio Information Cordraetor NABORS ALASKA RIB Name NABORS 245 E Rlg Type LAND RIG Job Information Wellbore Original Hole Jeb PMse DRILLING SPatl Dab 11/16/21 Target Depth (RKB) 13,374.0 Target Depth (W... Drilled DePth (R) 25,234.00 Drilling Noune 1s (hrs) 63.47 Anrag ROP ("r) 154.4 DFS (days) 044 Dailv Information Depth End (RKB) 346D Depth End (WD) (... 1 MD Depth Progress (R) 221.00 I Drilling Hours (hrs) 4.00 Avenps ROP (fVhr) 55.3 POB 70.0 Temperature (°F) Weather Wind Daily summary operation 24h Forecast Drill ahead. 24h Summary Continue rig to spud, spud in at 1330 his, drill and survey from 125'to 346'. Operation at 07.00 Drilling LHhology Shows MAASPPressure(Psi) Mud Weight(Ib/gal) Time Lo Can st art Errs Dur our Tlms Wrro I Ih (h Phe» Opr. Apt. w. Plan Opcti 1. i. 00:00 01:00 1.00 1.00 PREP C 1 n sure P Fill riser with water, tliverter knife valve leaking. Clean suction screens on number 1 and 2 mW plumps. 01:00 04:00 3.00 4.00 PREP H 1 TR05 Nipple down diverter knife valve from diverter spool, clean, repair, and nipple back up to dwerter spool. 04:00 04:30 0.50 4.50 PREP C 1 P Fill riser with water, check for leaks, all oX 04.30 05:00 0.50 5.00 PREP C 1 P Blau down drill water transfer pump line and clean suction screen on #2 mud pump. 05:00 09:00 4.06 9.00 PREP A 1 P Hang Schlumberger wireline sheave, make up Gyro Dala tools and test 0900 11:30 2.50 11.50 PREP A i P Make up BHA 111. 11:30 12:30 1.00 12.50 PREP A 1 P Circulate spud mud through mud system to check for leaks and proper alignment. Circulate at 40 spm and 165 gpm. 1230 14:00 1.50 14.00 DRILL E 3 P Drill from 125' to 163' wKh W rpm, 2-0 wob, 130 psi, and 350 gpm. 14.00 15:30 1.50 15.50 DRILL E 4 P Pull out of hole with BHA #1 and lay out. 15:30 19:00 3.50 19.00 DRILL E 4 P Pick up BHA i/2 and run in hole. 1900 2300 4.00 23.00 DRILL E 3 P Drill from163'to 346' with 30 rpm, 48 woo, 495 psi, and 504 gpm. Survey at 179' and 241'. MM-0500 Continue drill and survey from 346' to 501'. 23:00 00:00 1.00 24.00 PREP E 1 P Ream and wash down from 115'to 125' with 30 rpm, 24 wob, 350 gpm and 130 psi. Dailv Contacts PeaNbn I coastal Name I Company 71110 Prrrall ORIw Moblb Eni representative Jack Eni representative Eni representative Eni represemative Eni representative Joe Keener Bobby Walls Bernie Leas Greg Parker Longo Eni Petroleum Eni Petroleum Eni Petroleum Eni Petroleum Eni Petroleum Drilling Supervisor Drilling Supervisor Rig Clerk Expediter Ddg Emir lack.keenar�enipetroleum.can bobby.walls�enipetroleum.com bemie.leas@enipetroleum.can 907870.8580 9078708580 9078708580 907-980-7545 907865-3323 9W-7158434 907-575-9427 907-980-7545 Last Casing seat ces. -rye DD i) ro Pn) BesideToP RKB) Bottom MIM Run Data CONDUCTOR 20 18.250 X85 0.0 164.0 9/25/2008 Last Leakoff Test Depth(RKB) WD(fIKB) Fluid Type Flultl Denalty (Ip/gal) P(Surf)(PSI) Eq. Mud Weight(lb/gal) LeakoR Premure(psi) Eni E&P Division Well Name: d -P05 Daily Report Well Code: 22827 ENI Petroleum Name: Nikailohuq CO. Inc.Field Date: 11/17/2008 - Report #: 11 APIIUWI: 50412923396-00 Wellbore name: Original Hole page 1 of 1 Well Header ParmlUCeneessien N° Operator ENI Sham (%) Well Configuration type Oliktok Point 208-137 ENIPETROLEUM 100.00 DIRECTIONAL Rosary Table Elevation (R) Ground level (R) Water Daplh (R) RKB -Base Flange (R) RKB -Tubing Spool (R) 41.00 12.20 9.43 8.85 Rta Information Contractor Rig Name Rig Typa NABORS ALASKA NABORS 245E LANG RIG Job Information Wellbore Job Phase Dab Si111162008 Target Depth (RKB) Target Depth (TV... Drilled Depth (R) Dnilinp Hours (hre) Avenge ROP (RArr) DFS (days) Original Hole DRILLING 13,3740 25,234.00 163.47 754.4 1 1.44 Dail Information Depth End (RKB) Depth End (TWD) (... Depth Progress (n) Igniting Hours (him) Average ROP (Rttlr) POB Temperature (°F) Wei Wind 594.0 593.6 248.00 7.00 35.4 70.0 .9.0 Panty Cloudy WC 090 at 6 mph -18 Daily summary operation 24h Foraesst Fish junk from hole, RIH with drilling assembly and drill ahead. 24h Summary Drill and slide to 594'. Drop bar peg in hole, fish ferjun,. Operation at 07.00 Run in hole with 16" Globe junk basket. Llthology Shows MAASPPmssum(psi) Mud Weight (legal) 8.80 Time Lo Cum Start End our Our Time Time (hm) (hrs) Phase Opsi AOL Ran Open Dmi 0000 08:30 8.50 8.50 DRILL E 3 P Drill from 31T to 594' with 590 gam, 890 psi, 25 rpm, 25-30, wob, 3,51k torque. 3.4 hrs actual drlg time, 1.9 hrs actual slide time, and 1.5 hrs actual rotate time. 0830 12:00 3.50 12.00 DRILLE 4 P Trip out of hole, lay down threejoints of HWDP, stand back four stands of HWDP with jars. Lay down BHA, and stand back non-magnetic drill collar. 12:00 15:00 3.00 15.00 DRILL E 4 P Pick up BHA #3. 15:00 16:00 1.00 16.00 DRILL E 20 TP99 Dropped steel peg used for standing tools on peg through hole in master bushings. (Note, these holes are in master bushings used for kelly drive bushings). Notify Anchorage and call out Baker fishing tools. 16:00 18:30 2.50 18.50 DRILL E 4 TP99 Pull out of hole, lay down BHA, and prepare to pick up fishing tools. 18:30 21:00 2.50 21.00 DRILL E 20 TP99 Load drillfloor with Baker fishing tools. Clean cellar area, looking for peg. 21:00 22:00 1.00 22.00 DRILL E 4 T -P59 don. Make up 14" magnet, bit sub, and over, run in hole with S' drillpipe, tag up at 485' with 101,w 2200 23:00 1.00 23.00 DRILL E 19 TP99 Top drive up, wash antl rotate past ledge with 15 rpm, 60 spm, 255 goal, aid 46 psi. Run in hole , wash down to 594', fission. bottom firm, shut down emission. 2300 00:00 1.00 24.00 DRILL E 4 TP99 Pulloutof hole with fishing assembly. Nofish. (Note, build berms and move mechanic shop and Toolpusher trailer from Air Force pad to OPP, Put a top on cuttings tank and install steam to steam lines). 0000-0200 Prepare and pick up Globe junk basket, :overs and HWDP. Nabors Tongs unable to go around 1 T' Globe shoe basket connection. 0200-0500 Waiting an tongs from Baker oil tool. Service ng. Daily Contacts Position Demand: Name I Company I Title Eanall Office Moblle Eni representative Jeck Keener Eni Petroleum Drilling Supervisor jack.keener@enipebvleum.cam 907670-8580 907-7156434 Eni representative Bobby Walls Eni Petroleum Drilling Supervisor bobby.walls@enipetroleum.carn 9076706580 Eni representative Bennie Leas Eni Petroleum Rig Clerk bemie.leas@enipetroleum.can 907670-8560 907-575-9427 Eni representative Greg Parker Eni Petroleum Expediter 907-980-7545 907580-7545 Eni representative Joe Longo Eni Petroleum Dng Engr. 90766543323 Last Casing seat CAA Type OD in ID (in) Grade Top (RKe) Bottom (RKB) Run Dab CONDUCTOR 201 18,250!X-6 0.0 154.0 925/2008 Last Leakoff Test Depth (RKB) TWD (RKB) Fluid Type Ffuld Density (Ib/Baq P (Surf) (psi) Eq. Mud Weight (Ibi Leak Off Pressure (psi) Well Header Eni E&P Division ENI Petroleum Eni Co. Inc. Well Header WII Name: _: 03P05 Daily Report PermMoncesslon N° Oliktok Point 208-137 Well Code: 22827 Field Name: Nikaitchuq Date: 11/18/2008 - Report#: 12 API/UM 50-029-23396.00 page I of I Wellbore name: Original Hole Well Header PermMoncesslon N° Oliktok Point 208-137 Operator ENI PETROLEUM ENI Sharo (%) 100.00 DIRECTIONAL Well Cerdiguration type Rotary Table Elevation (R) 41.00 Ground Level(R) 12.20 Water Depth (n) RKB - Base Flange (R) 9.43 RKB -Tubing SPool (R) 8.85 Rig Information Contractor NABORS ALASKA ftie No NABORS 245E Rig Type LAND RIG Job Information Wallbero Original Hole Job Phase DRILLING Spud Dab 11/16/2008 Target Depth (RKB) 13,374.0 Target Depth (TV... Drilled Depth (R) 25,234.00 Drilling Hours (hra) 163.47 Average ROP (fVhr) 154.4 DFS (days) 2.44 DatIV Information Depth End (ftKB) ID.pth End (TVD) (... 1,5087 Depth Progress (R) 956.00 Orllling Hours (hrs) 8.00 Average ROP (mhr) POB 119.5 71.0 Temperature (°F) -7.0 Weather Parry cloudy Wind1,550.0 090° at 8 mph. Daily surrimmy operation 2M Forecast RIH with Drilling BHA and drill ahead. 24h Summary Fishing. Operation at 07.00 Rigging down Gyro survey tools at 741'. Lltirolugy She" UAASP Pressure(psp Mud Wight (lblgal) 9.10 Time Loar Cum Start End Our Dur Tim Tim (hre) (hrs) phase OW. AOL Plan Opts. Descr. 00:00 00:30 0.50 0.50 DRILL E 4 TP99 Lay down BHA, stand back stand of HWDP, clear drillfloor of #1 fishing BHA. 00:30 02:00 1.50 2.00 DRILL E 4 TP99 Pickup 1 joint of HWDP, make up xovers, and pick up Globe junk basket. Nabors tongs unable to go around 16" basket to tighten basket shoe. 02:00 05:30 3.50 5.50 DRILL E 23J 23 TP99 While waiting on tongs enroute from Deadhorse, service top drive, crown, and drawworid. Clean rod wash boxes on mud pumps. 05:30 07:00 1.50 7.00 DRILL E TP99 Rig up Baker Oil tool tongs, tighten connections on Globe basket and make up joint of HWDP. 07:00 08:30 1.50 8.50 DRILL E 4 TP99 Trip in hole with 5" drillpipe, lag up at 475', make up top drive, ash and ream to 594' with 20 rpm, 60 spm, and 41 psi. 0830 0930 1.00 9.50 DRILL E 10 TP99 Cut core with Globe basket to 598' with 24k woo. 09:30 11:00 1 1.50 11.00 DRILL I E 4 TP99 iTrip out of hole from 596'. 1100 1200 1.00 12.00 DRILL E 4 TP99 Lay down BHA and 2 joints a HWDP, break down Globe basket, remove core, no fish recovery. 1200 1300 1.00 13.00 DRILL E 20 TP99 oor of fishing tools and dean. Cleaj16" 13:00 13:30 0.50 13.50 DRILL E 20 TP99 Greawworks brake linkage. 13:30 1430 1.00 14.50 DRILL E 4 TP99 Makker reverse dreulating junk basket and trip in hole to 482', tag up with 10k down, top drive up and wash down l0 59 17 rpm, 45 psi, and 279 gpm. 1430 1530 1.00 15.50 DRILL E 14 TP99 Milli01'with 1-2k woo. 27 psi, and 93 gpm. 15:30 18:00 2.50 18.00 DRILL E 4 TP99 Trip hole, lay down fishing BHA, no junk recovery. Clean dr` dor. 18:00 20:00 2.00 20.00 DRILL E 4 TP99 Pick bit, stabilizer, xover, and stand of HWDP. Run in hole, tog up at 482'. 2000 2130 1.50 21.50 DRILL E 19 TP99 Makp drive, wash antl ream to601'with 600 gpm, 142 spm, 470 psi and 10 rpm. 21:30 22:00 0.50 22.00 DRILL E 3 TP99 Drill 01'to 615'with 798 gpm, 800 psi, 188 spm, 40400 rym, and 2-i5kweb. Drilling o.k. noindicationofGrillingOn junk.reain up and down several times while drilling to 615' with no indications of junk below bit. 22:00 00:00 2.00 24.00 DRILL E 4 TP99 Trip out of hole, lay down BHA, wash 16" bit and Mack for any indications of running on junk. Bit o.k. clean dnllFloor. 0000-0500 Run in hole with drilling BHA, drill 10 647'. Daily Contacts position Cemart Nam• ntb E+rMll 1 Orion, Mebne Eni representative Jack Keener Eni representative Bobby Walls Eni representative Bemis Leas Eni representative Greg Parker Eni representative Joe Longo Eni Petroleum Eni Petroleum Eni Petroleum Eni Petroleum Eni Petroleum Drilling Supervisor Drilling Supervisor Rig Clerk Expediter Drg Engr. jadk.keenergenipalmieum.cam boblay.wals@empetroleurn.com bemie.leas@empetroleum.com 907670-8580 907670-8580 907670-8580 907-9804595 907-865-3323 9074156434 907575-9427 907-980-7645 Last Casing seat Cu, s OD In) 10 (In) Grads Top (RKB) Bottom (RKe Run Dab CONDUCTOR 20 18 250 X-85 0.0 154 0 9Y25/2008 Last Leakoff Test Depth (RKB) TVD (RKB) Fluid Type Fluld Density (Ib/gal) P (Sura (psi) Eq. Mud WaigM (IO/gaI) Leak OR Prossuro (psi) Daily Report Date: 11119/2008 - Report #: 13 page 1 of 1 Well Name: - A -`P05 Well Cotle: 22827 FINtl Name: Nikaitchuq TUWI: 50-029-23398.00 Wellbore name: Original Hole Well Header Eni E&P Division ENI Petroleum Eni Co. Inc. Daily Report Date: 11119/2008 - Report #: 13 page 1 of 1 Well Name: - A -`P05 Well Cotle: 22827 FINtl Name: Nikaitchuq TUWI: 50-029-23398.00 Wellbore name: Original Hole Well Header PerMOConin sslon N. Gill Point 208-137 operator JENI PETROLEUM ENI Sham (%) 100.00 DIRECTIONAL Well Configuration type Rotary Table Elevation (R) 41.00 Ground Level (R) 12.20 Water Depth (R) RKB - Base Flange (R) 9.43 RKB - Tubing Spool (R) 8.85 RAY Information Contractor NABORSALASKA Rig Name NABORS 245 E RIB Type LAND RIG Job Information Wellbore Original Hole Job Phase DRILLING Spud Data 11/162008 Target Depth (RKB) 13,374.0 Target Depth (TV... Drilled Depth III) 25,234.00 Drilling Heure (hre) 183.4] Average ROP (Whir) 1 154.4 DFS (days) 3.44 Daily Information Depth End (fIKB) 2,358.0 Depth End (TVD) (... 2,181.2 Depth Progress (R) 808.00 Drilling Neure (hire) 10.00 Average ROP (Nhr) POB 80.8 66.0 Temperature (•F) -17.0 Weather P/C, light snow. WC �-27- Wintl 090- at 5 mph. Daily summary o eradon 24h Forecast Drill to TO, circ, wiper trip, POOH, He up and run 13 3/8" casing. 24h Summary Drill to 1,550' POOH to orientate motor. Operation at 07.00 Drilling ahead. Lithology, Shows MAASPPreasurePid) Mud Weight(Iblgaq 9.10 Time Lo Start This, Cum End Dur our Time (hire) (hire) phase OF, Act Pim open. Dinser. 00:00 04:00 4.00 4.00 DRILL E 4 P Pick up BHA, upload MWD and check orientation. OLIN) 0430 0.50 4.50 DRILL E 4 P Trip in hole, shallow test MWD with 700 gpm and 1,000 psi. 04:30 10:00 5.50 10.00 DRILL E 3 P Drill from 615'to 931' with 40 rpm, 700 gpm, 1,430 psi, 166 spm, and 30-351, wab. Gyro survey at 738'. 10:00 10:30 0.50 10.60 DRILL E 19 P Run Gyro survey at 928', rig down Gyro wireline. 10:30 17:30 7.00 17.50 DRILL E 3 P Drill and slide from 931'to 1,550' with 700 gpm, 1,500 psi, 166 spm, 40 rpm, 30-35k arab. PIU weight 95k, DN 93k, 3,0001, torque on bottom, off bodon 1,900k. Survey every stand. 17:30 19:00 1.60 19.00 DRILL E 4 P Trip out N hole, to orientate motor and pick up stab. above motor to build angle, from 1,550'to 834', monitor hole, proper displacement, and no swabbing. 19:00 2230 3.50 22.50 DRILL E 4 P Trip out of hole, rack back H WDP/DC. Download MWD, lay down MWD and Nab. Orientate motor from 1.5° to I.S. 22:30 00:00 1.50 24.00 DRILL E 4 P Pick up BHA, new MWD and stabilizer. 0000-0500 Pick up BHA, upload MWD, run in hole. Daily Contacts Position I Contact Nal y TRIG Er mi oRlcG MOblb Eni representative Jack Eni representative Eni representative Eni representative Eni representative Joe Keener Bobby Walls Bemis Leas Greg Parker Longo Eni Petroleum Eni Petroleum Eni Petroleum Eni Petroleum Eni Petroleum Drilling Supervisor Drilling Supervisor Rig Clerk Exped4er lDrin Engr. jackkeenergenipetroleum.can bobby.walls�enipelroleum.can bemie.leas@enipetroleum.cwn 9078708580 9078708580 9078708580 907-980-7545 907-865-3323 907-7158434 907875-9427 907-980-7545 Last Casing seat Cas. Type i OD In) ID (in) I Guam, Tap (RKB) Bokem fall Ruth Data CONDUCTOR 20 18.250 X85 0.0 154.0 9/25/2008 Last Leakoff Test Depth (RKB) TVD (RKB) Flub Type Fluid Density (Iblgal) P (Surf) (psi) Eq. Mud Weight (Ibigal) Leak OR Pressure (psi) Eni E&P Division ENI Petroleum CO. Inc.Date: Well Nam.: 03 -POS Daily Report Well Code: 22827 Field Nam: Nikslchu i 11120/2008 - Repo#: 14 APVUWI: 50-029-23396 -00Eni page 1 of 1 Wellbore name: Original Hole Well Header PenMt/Coneesslon N• Oliktok Point 206.137 Operator ENI PETROLEUM ENI Share (%) Well 100.00 DIRECTIONAL Con"guraeon type Rotary Table Elevator, (R) 41.00 GroundLeel (R) 12 20 Water Depth (R) RKB - Base Flange IR) 9.43 RKB -Tubing Spool (R) 8.85 Rio Information Contractor NABORS ALASKA Rig Name NABORS 245 E RIB Type LAND RIG Job Information WMlboro Original Hole Job Phase DRILLING Spud Date 11/162008 Target Depth (RKB) 13,374.0 Target Depth (N... Drilled Depth 0 25,234.00 Drilling Hours (his) 163.47 Average ROP (Rthr) 154.4 DFS (days) 4.44 Daily Information Depth End(RKB) 2,358.0 Depth End(TVD)(... 2,161.2 Depth Progress IN) 0.00 Drilling Hours flus) Avenge ROP(Rlhr) FOB 66.0 Temperaturo(°F) -16.0 Weather P/C, tight show WInO 0910 fol4 mph DaYV summary operation 24h Forecast POOH, lay out BHA, make dummy run with landing joint, rig up and run 13 3/8" casing, cement and displace. 24h Summary Drill from 1,550' Io TD at 2,358' wiper trip, circ 2 btms up, Pooh. Operation at tl Make dummy run with 13 3/8" hanger. Lithology Shows MAASPPressuro(psi) Mud Weight(lb/gal) 9.60 Time Lo cum Start EndDur Our Time Time (hm) (has) Phase OF, Act. Flesh Oper. Deer. 00:00 01:30 1.50 1.50 DRILL E 4 P Picking up BHA, upload MWD. 01:30 0230 1.00 2.50 DRILL E 20 P Service rig, adjust brake bands on drewworks. 02:30 04:30 2Z 4.50 DRILL E 4 P Run in hole with BHA, pick up stand of 5" drillpipe and shallow test MWD with 1000 gpm and 1,260 psi. Blow down top drive. 04:30 05:00 0.50 5.00 DRILL E 4 P Continue run in hole to 1,520', make up lop drive. 05:00 09:00 4.00 9.00 DRILL E 3 P Drill from 1,550'to 1,898. 09:00 10:00 1.00 10.00 DRILL E 7 P Circulate bottoms up to clean hole with 700 qpm, and 1,375 psi. 1000 1400 4.00 14.00 DRILL E 3 P Drill from 1,890' to 2,191' with W415k wob, 1,900 psi, 800 Qpm, 5,500k torque on bottom, 4,5001, off btm. 118k pickup, t00k dawn and 110k rotate weight. 14:00 15:00 1.00 15.00 DRILL E 20 TR04 Canrig troubleshoot electrical problems en top drive. 15:00 1800 3.00 18.00 DRILL E 3 P Drill from 2,191' to TD st 2,358', TVD 2,163'. 1800 20:30 2.50 20.50 DRILL E 4 P Wiper trip from 2,358'to 834', RIH, no hole problems a restrictions. 203D 23:00 2.50 23.00 DRILL E 7 P Circulate and condition hole with 787 gpm, and 1,785 psi. Pump nutplug sweep and circ out. 23:00 00:00 1.00 24.00 DRILL E 4 P Pull 4 stands out of hole, blow down top drive. 0000-0500 POOH, lay out BHA, and make dummyrun with landing joint. Daily Contacts Position Co too Nam Cormamy title Ercall OR1e Mobile Eni representative Jack Eni representative Bobby Eni representative Bennie Eni representative Eni representative Joe Keener Walls Leas Greg Parker Longo Eni Petroleum Eni Petroleum Eni Petroleum Eni Petroleum Eni Petroleum Drilling Supervisor Drilling Supervisor Rig Clerk Expediter Drlg Engr. jack.keener@enipetroleum.ocm bobby.walls@enipetroleum.com bemie.leas@enipetroleum.com 907670-8580 9076706580 907670-8580 907-980-7545 9076663323 907-715.6434 907-575-9427 907-980-7545 Last Casing seat Gs. Type OD (in) 1ID lin) Grad, I Top RKS) Bottom (nKB) i Run Data CONDUCTOR zul 9252008 Last Leakoff Test -Mud Depth (RKB) TVD (IRKS) Fluid Type Fluid Density fibigal) P (SUM (Psi) Eq. WeIBM (Ib/gal) Leak OR Procure (pal) Eni E&P Division ENI Petroleum CO. Inc.Flaltl Eni Well Name: 3-P05 Daily Report Field Nam 22827 huq Name: N 9-233% 50 name: Date: 17!21/2008 -Report#: page Wellb�APUUMore i page 1 of 1 Wellbore name: Original Hole Well Header PennitfConeassion N° Operator Oliktok Point 208-137 ENIPETROLEUM ENI Shan (%) 100.00 DIRECTIONAL Well Congguratlon type Rotary Table ElsvaRon (1t) 41.00 Grountl Level (R) 12.20 Water Depth (R) RKB - Base Flange (R) 9.43 RKB -Tubing Spool (K) 8.85 Ric Information Contractor NABORS ALASKA Rig NameRig NABORS 245E Typs LAND RIG Job Informal -ion Wellbore Original Hole Job Phase DRILLING Spud Dab 11/162008 Target Depth (RKB) 13,374.0 Target Depth (N... Drilled DepM (R) 25,234.00 Drilling Houn (hro) 163.47 Averoga ROP (ftlhr) 1 154.4 DFS (days) 5.44 Daily Information DOM End ("KB) 2,358.0 Depth EIW (TVD) (••• 2,161.2 Depth Progress Ih) 0.00 DOiling Hours (hn) Avenge ROP (ftlhr) POE 66.0 Temperot m, (°F) 3.0 Weamer P/C, WC -23° Wintl 045° NE 23 mph Daily summary operation 241, Foremast Circulatethewellbore. Camara 133t8" casing. Nippleup ROPE. 24h Summary Finish POOH. Lay down BHA. Rig up and run 13 31V casing. Open ion at 07.00 Cementing 13 3/e" casing. Lithology Shaws MAASP Pressure (psl) Mud Weight (Ibigal) 9.60 Time Lo Cum Start End Dur Dur Tim Time (hm) (11111111 Phase Opr. Act Plan Oper. Ower. 00:00 02:30 2MI 2.50 DRILL E 4 P Pull out of hole from 1,988'. 02:30 06:30 4.00 6.50 DRILL E 4 P Stand back HWDP and lay down BHA. 06:30 1100 4.50 11.00 DRILL E 20 P Rig up 13 3/8" casing equipment. 11:00 12:00 1.00 12.00 DRILL E 20 P Make dummy run with 13 WU casing hanger. Measured at 37' RKB. 12:00 13:00 1.00 13.00 DRILL E 20 P Move centralizers to rig Boor antl continue rig up to run casing. 13:00 13:30 0.50 13.50 DRILL E 20 P Pre -task safety meeting. 13:3D 1800 4.50 18.00 DRILL E 13 TR99 Blew hydraulic hose on stabbing board. Replace hose. 18:00 22:00 4.00 22.00 DRILL E 19 P Run 13 3/8" casing to 1,036', filling every joint. Rewrd pickup and slacko8 every 5 joints. 22:00 122M 0.50 22.50 DRILL I E 7 1 P Circulate at 1,036' with 200 gpm and 200 psi. Pickup 100k antl Slack o8 85k. Full ratums. 22:30 00:00 1.50 24.00 DRILL E 19 P Run 13318" casing to 1,783'. 0000-0130 Circulate 0130-0230 Blew "0" ring on pressure regulator on power tongs, could not repair, changr out tongs. 0230-0400 Run 13 3/8" casing to 2,281'. 0400-050D Pipie skate broke dmn, repair same. Dell Contacts position Contact Karin CompaM I me I Enrlsil I Ocoee Montle Eni representative Jack Eni representative Eni representative Eni representative Eni representative Joe Keener Bobby Walls Bernie Leas Greg Parker Longo Eni Petroleum Eni PeVoleum Eni Petroleum Eni Petroleum Eni Petroleum Drilling Supervisor Dnliing Supervisor Rig Clark Expediter Onto Engr. jack.ksener@empetroleum.can bobby.wallsCenipetrolaum coin bernie.Ieas@enipstroleum.com 907-670-8580 907.870-8580 907.670-8580 907-980-7545 907-865-3323 907-715-6434 907575-9427 907-980-7545 Last Casing seat Cee. Type I OD (in) ID (in) Grade i Top (1008) Beaem (11KB) Run Dab CONDUCTOR 20 18.250 K-65 0.0 154.0 9252008 Last LeakoH Test Depth (RKB) TVD (RKB) Fluld Type Fluid Density gbigal) P (Surf) (Psi) Eq. Mud Weight (IbigaO Leak OR Pressure (psi) Eni E&P DivisionWall ENI Petroleum CO. Inc.Fleltl Eni Name: W -POS Daily Report w.11eetl.: zz327 Name: Nikaitchuq Date: 11/22/2008 - Report 16 Wellbo so name:Ori page 1 of 1 Wellbore name: Original Hole Well Header Pormi1/Conoesslon N° Oliktok Point 208-137 Operator ENI PETROLEUM ENI Share (%) 100.00 Well Configuration typo DIRECTIONAL Rotary Table Elevation (11) 41 00 Ground Level (R) 1220 Water Depth (R) PIKE - Base Flange 1111 9.43 RKE -Tubing Spool (11) 8.85 Rig Information Contractor ALASKA Rig Name NABORS 245E Rig Type pe LAND RIG Job Information Wellbore Original Hole Job Phase DRILLING Spud Date 11!1612008 Target Depth (11KE) 13,374.0 Tarest Depth (TV... Drilled Depth IN) 25,234.00 Drilling Hours (hrs) 163.47 Average ROP (IVhn 164.4 DFS (days) 6.44 Dailv Information Depth End (IBB) 2,358.0 Doper Entl (TVD) (... 2,10.2 Depth Propross (R) 0.00 Drilling Moore (hrs) Averegs ROP (11Rrr) POB 62.0 Temperature (°F) 4.0 Weather P/C, WC -24• Wind 068° ENE @17 mph Daily summaa operation 24h Forecast Clean pits, prepare /nipple do ROPE Min Summary Run /ant 135!8 csg, clean pits, nipple do ROPE Operation at 07.00 Nipple on BOPE. Clean pits and rig floor. Uthology Shows MAASPPrassure(psp Mud Walght(lb/gai) 9.60 Time Loci Start End TIM TIM our (hrs) cum our (hrs) Phase Opr. Act Ren Open Dealt. 00:00 01:30 1.50 1.50 DRILL G 7 P Ciro / cond fluids. 220 psi! 195 gpm, up 150, on 120 01:30 0230 1.00 2.50 DRILL G 25 TS03 Blown "0" ring GOR calf tangs. Replace tongs. 02:30 04:00 1.50 4.00 DRILL G 4 P Resume RIH 13-3/8 csg, 1865-2281 ft 04:00 05:00 1.00 5.00 DRILL G 7 P Ciro / mnd fluids 150 psi 1203 gpm, w 170, on 130 05:00 08:00 3.00 8.00 DRILL G 4 P PU two 10 ft pups, two 5ft pups, wash on, tag load shoulder. Shoe 23501L 08:00 09:30 1.50 9.50 DRILL G 25 TRO5 Flow line repairs, hgr Wiled bell nipple from stack. 0930 1400 4.50 14.00 DRILL H 7 P Ciro/ mnd fluids, PJSM, RAJ ant M. cont circ I Gond fluids in prep for antjcb. 1400 18:00 4.DO 18.00 DRILL H 9 P PJSM, Commence cmt 13J cog: Pump 10 PIIS pre Bush, test lines 4000 psi, pump 100 bbl mud push, drop btm plug, me / pump 454 bbls 10.7 ppg lead slurry, observed dye in mud push, switched to tail slurry, pumped 73 bbls of 12 ppg Lite CRETE cement, leaving top of tail @ 1936, displace with rig pumps @ 5 bpm, bumped plug, held 900 psi, for 5 mins, floats held. CIP at 1700 hours. a 6.00 24.00 DRILL C 5 P Nipple up!down diverter. Clean pits. Remove cement head. Lay down landing joint. Clean floor and cellar. Blau down mud tines. 0000.0500: Continue to clean pits, mud tanks and rig floor. Dail Contacts PoePoen I Contact Woos I Company TMIs E41WI ORiw Mobile Eni representative Jack Eni representative Dave Eni representative Bemie Eni representative Greg Keener Moms Leas Parker Eni PeVoleum Eni Petroleum Eni Petrvlaum Eni Petroleum Drilling Supervioor jeck.keener@enipet ch"uhn am Drilling Supervisor dave.martis@e nipetroleum.can Rig Clerk bemie.leas@empetroleum.com Expediter 9075705580 907-670.8580 907570-8580 907-980-7545 90(-7155434 907575-9427 907-980-7545 Lost Casing seat Cas.Typs OD In)I IDlin) i these TOP t1 B) IBettem 111K8) Run Dab CASING 133/8 12.4151L 0.0 2,350.] 11/22/2008 Last Leakoff Test Depth IRKS) TVD (fill Flultl Type Fluid Density (flb/gal) P (Sort) (Psi) Eq. Mud Weight (Ibi Leak OR Pressuro (psi) Eni E&P Division Wall Name: 13-P05 Daily Report Well Code: 22827 ENI Petroleum Field Nam: Nikaitchuq Inc. Date: 11/23/2008 - Report #: 17 APBUWI: 50-029-23396'00 In-1Co. Wellbore name: Original Hole page 1 of 1 Well Header Penniticoneesslon N• Operator ENI Share(%) Wolf ConBgurstion type Oliklok Point 208-137 ENI PETROLEUM 100.00 DIRECTIONAL Rotary Table Elevation (ft) Ground Level (n) Water Depth (ft) PIKE - Bass Flange (R) PIKE -Tubing Spool (K) 41.00 12.20 9.43 8.85 Rig Information Contractor Rig Nam Rig Type NABORS ALASKA NABORS 245E LAND RIG Job Information Wellbore Job Phase Spud Data Target Depth (RKe) Target Depth (TV... Drilled Depth (ft) Orllling Houre (hrs) Average ROP (Pohr) DFS (days) Original Hale DRILLING 11/16/2008 13,374.0 25,234.00 163.47 1544 7.44 Daily Information Depth End IRKS) Depth End (TVD) (... Depth Progress (R) Drilling Hours (his) Average ROP (Rmr) POB Temperature (•F) Weather Wind 2,358.0 2,161.2 0.00 62.0 4.0 pic, WC S 068° ENE @3 mph DEW summary operation Rah Forecast Nipple up wellhead / BOPE 24h Summery Nipple on BOPE Operation at 07.00 Nipple up BOPE Lithology Shows MAASP Pressure (psi) Mud Weight (Ib/pap 9.60 Time Lo Cum awn End Dur our Tlmm Time IM) (his) Phase Opr. AOL Plan Oper. Dsser. 0000 0000 24.00 24.00 DRILL C 20 P PJSM, Nipple do ROPE, remove floMine, fillup line, risersemove flowline from utility side wall, place on landing. wash annular, remove diverier lines / knife valve from cellar. PJSM. RID scaffolding. Tie on to annular, break bolls leaving two in place. Space lint nations prevent forklift from reaching annular. RIU slings to blocks. Tail annular out of cellar with ng blocks and forditL Remove riser spool, Remove wellhead. Clean / inspect same. OOOD-0500 Prepf install Vetco Multibowl wellhead. Test 5000 psi Daily Contacts Position Cenbo! Name Company Two I P mall oftim I Mobile Eni representative Jack Keener Eni Petroleum ng Supervisor iada.keener(9,anipeboleum.COM 907.670.8580 907-715.6434 Eni representative Dave Monis Eni Petroleum ng Supervisor tlave.manis�anipetroleum.ccm 907870A5B0 Eni representative Bemis Leas Eni Petroleum lerk Editor bemie.leasCenipetrolaum.com 907-670A680 907-675-9427 Eni representative Greg Parker Eni Petroleum 907-980-7545 907-990-7545 Last Casino seat Cas. Type OD Iln) ID (In) Gredo Ta (RKB) BORam (RKB Run Data CASING 133/6 12.4151-80 0.0 2,350.711/22/2008 Lost Leakofl Test Depth (RIME) TVD (RKB) Fluid Type Fluid Density (ibfgaI) P (Surf) (psi) Eq. Mud Weight (Ib/Bal) Leak OM Pressure (psi) Well Header Eni E&P Division %ENI Operator ENI PETROLEUM Petroleum Ent F ' Name: Nikeitchuq Co. Inc. Well Header 11 Nams: i.A3-POS 004FI:: Daily Report Operator ENI PETROLEUM Code: 22827 ENI Share (%) 100.00 DIRECTIONAL F ' Name: Nikeitchuq Date: 11/24/2008 - Report #: 18 API/UWi: 50-029-2339600 page 1 of 1 Wellbore name: Original Hole Well Header PertnlVCom esslen N° Oliktok Point 208-137 Operator ENI PETROLEUM ENI Share (%) 100.00 DIRECTIONAL Well Configuration type Rotary Table Elowt on (R) 41.00 Ground Level (R) 1220 Water Depth (R) KKR - Base Flange (R) 9 43 RKB - Tubing Spool tri) 8.85 Rig Information Contractor NABORS ALASKA WE Name NABORS 245E Rig Type LAND RIG Job Information Wellbore Original Hole Jeb Phase DRILLING Spud Dab 11/16/2008 Target Depth (RKB) 13,374.0 Target Depth (N.. . Ddlietl Depth (R) 25,234.00 Dduing Hours (las) 163.47 Averege ROP (fdhr) 154.4 DFS (days) 8.44 Dail Infomtation Depth Entl (hKB) 2,358.0 Depth Entl (TVD) (... 2,1612 Depth Pregresa (R) 0.00 DrllllnE Hours (hrs) Avenge ROP (fUhr) POB 61.0 Temperature (°F) -2.0 Weather P/C, WC -73° Wind 068°ENE 8mph Daily summaty operation 241, Forecast Nipple up BOP, test BOP 24h Summary Install mullibowl wellhead, test 5000 psi, nipple up ROPE Operation at 07.00 Nipple up ROPE Uthology Snows MAASP Pressure (psi) Mutl Ws(Ib/gsi) 9.60 9' Time Loci Start Tlms Cum End Dur Dur Time (hrs) (hm) Phase Ops. Act. Plan Oper. Deser. 00.00 05:00 5.00 5.00 DRILL C 20 P PJSM, install Vetoo 13,/8 5K mullibow1 wellhead. Test to 5000 psi 10 min. Test successful, no re -tests. 05:00 16:30 11.50 16.50 DRILL C 20 P PJSM, nipple up 13,/8 5K BOPE, all related equipment. 16:30 18:00 1.50 18.00 DRILL C TO P PJSM, erect scaffolding to upper BOP area. 1800 00:00 6.00 24.00 DRILL C 20 P PJSM, resume nipple up ROPE, hemmer up bolls while prepare choke and kill lines for installation. 0000 - 0500 Torque up BOP bolts, prepare install ckoke and kill lines. Daffv Contacts position I Cerate@ Narm Company Title E-mail I Office Moblle Eni representative Jack Eni representative Eni representative Eni representative Keener Dave Mortis Bemie Leas Greg Parker Eni Petroleum Eni Petroleum Eni Petroleum Eni Petroleum Drilling Supervisor Drilling Supervisor Rig Clerk Expediter jackkeenergenipemoleum.com dwe.mortis@enipetroleum.com bemie.leas@enipetroleum.can 907,70.8580 907-670.8580 907870-8580 907-980-7545 907-715-fi434 907-575-9427 907-980.7545 Last Casing seat Cas. TypeOD (m) ID (In) Graft T IRKS) Bettem (RKB Run Dab CASING 133/8 12.415L80 0.0 2,350.711/222008 Last Leakoff Test Depth (RKB) TVD (RKB) Fluid Type Fluid Density (Iblgap P (Sure) (psi) Eq. Mud Weigh(lWgal) Leak ON Pressure (psi) MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg�� 3131', DATE: March 22, 2011 P. I. Supervisor FROM: Lou Grimaldi SUBJECT: No Flow Verification Petroleum Inspector ENI Petroleum OP03-P05 PTD # 208-137 Nikaitchuq Field Tuesday, March 22, 2011: 1 witnessed the No -Flow test on ENI Petroleum's well OP03-P05 in the Nikaitchuq Field. I had been in contact with the operator Delton Carrol about equipment and procedure. When I arrived he was very prepared for the test. I arrived at the facility to find the well open to atmosphere. The tubing and annulus were tied together with a "C" section used to vent free gas on the backside to the flowline. This well is a packer -less completion. After verifying the position of the pertinent valves The Flow (if any) would be measured by an Erdco "Armor flo" gas meter capable of measuring 150-1500 scf/hour of gas flow. There also was a calibrated 30 psi "Test" gauge (0.1 psi increment) used to monitor the tubing/annulus pressure. A''/4 turn block valve downstream of the gauge was used to close the flow from the tubing/annulus to atmosphere/tankage. I required 2 equal -time tests, both involving shut-in and flowing intervals. During the 2 tests, tubing pressure never rose above 17 psi and sustained gas flow was well below the measurable capacity of the flow meter (150 scf). There was no fluid produced to surface during the entire no flow test I monitored. The following table describes the details of the test: 2011-0322_No-Flow_ Nikaitchuq_0P03-P05_1g.doc 1 of 2 Nikait huq OP03-P05 No Flow Test Time Pressure Flow Notes 1045 0.5 ----------- Start of test, well lined up too en top tank 1100 0.8 ----------- Shut in well at wellhead 1115 4.9 ----------- Shut in. 1130 6.9 ----------- Shut in. 1145 9.4 ----------- Shut in. 1215 17 ----------- Shut in. 1215 ----------- > 1500SCF/hour Open well too en top tank. 1220 1.5 1000SCF/hour Flow thru flow -meter to bleed trailer 1225 0 180SCF/hour Flow thru flow -meter to bleed trailer 1315 0.6 ---------- Shut-in for 2" SI period 1330 1.0 ----- ---- Shut in. 1345 1.4 ----------- Shut in. 1400 4.8 -- - Shut in. 1415$1.0 ----------- Shut in. 1415n200SCF/hour r Flow thru flow -meter to bleed trailer 1417r Flow thru flow -meter to bleed trailer 1420r Flow thru flow -meter to bleed trailer 1430urFlow thru flow -meter to bleed trailer 1445r Flow thru flow -meter to bleed trailer 1515r Flow thru flow -meter to bleed trailer The test was concluded at this point. I observed less buildup in the second shut-in test and quicker bleed down in the second flow test. This well appears to meet the criteria set forth in 20 AAC 25.265 for No -Flow status. Attachments: None Non -Confidential 2011-0322_No-Flow_ Nikaitchuq_OP03-P05_Ig.doc 2of2 9 T11 R! I EL As K A SEAN PARNELL, GOVERNOR Marc D. Kuck Senior Completion Engineer Eni US Operating Co. Inc. 3800 Centerpoint Drive, Suite 300 rl 00 Anchorage, AK 99503 (� ALASSA OIL AND GAS 333 W. 7th AVENUE, SUITE 700 CONSERVATION Re: Nikaitchuq Field, Nikaitchuq Pool, OP03-P05 Sundry Number: 310-387 Dear Mr. Kuck: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday oyweekend. DATED this y_�day of November, 2010. Encl. COMDIISSION ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907)276-7542 Re: Nikaitchuq Field, Nikaitchuq Pool, OP03-P05 Sundry Number: 310-387 Dear Mr. Kuck: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday oyweekend. DATED this y_�day of November, 2010. Encl. RECEIVED NOV 1 8 2010 Alaska Oil & Gas Cons. Commission AnOorage STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25280 1. Type of, Request: Abandon ❑ Plug for Redrill ❑ Perforate New Pool ❑ Repair Well 21 - Change Approved Program ❑ Suspend ❑ Plug Perforations ❑ Perforate ❑ Pull Tubing ❑ Time Extension ❑ Operations Shutdown ❑ Re-enter Susp. Well ❑ Stimulate ❑ Alter Casing ❑ Other: ❑ 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: Eni US Operating Co. Inc. Development 0. Exploratory ❑ Stratigraphic ❑ Service ❑ 208-137- 3. Address: 6. API Number: 3800 Centerpoint Drive, Ste. 300, Anchorage, AK 99503 50-029-23396-00 7. If perforating, closest approach in pool(s) opened by this operation to nearest 8. Well Name and Number: property line where ownership or landownership changes: IOP03-P05 Spacing Exception Required? Yes ❑ No ❑ ' 9. Property Designation (Lease Number): _ 10. Field/Pool(s): ADL337701: ADI -355024, ADI -355023, ADL390615 Nikaitchu ' 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depfh TVD (ft): Plugs (measured): Junk (measured): 12384 gcm; 12368 3974 N/A NIA Casing Length 11,Pj, (q+i' Size MD TVD Burst Collapse Structural Conductor 115' 20" 115 115 Surface 2350' 13-3/8" 2350' ��,12-; c- `L� y 8 5,020 2,270 Intermediate 5960' 9-5/8' 5960' ff, (qd° 3 �g3IN 36 x,876 4,760 Production 66145-1/2" 19-3 2-Y pws 3934 slotted slotted Liner "(,(q„c Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 5960-12368 3686-3934 4-1/2” L-80 5344 Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): N/A N/A 12. Attachments: Description Summary of Proposal 0 13. Well Class after proposed work: Detailed Operations Program ❑Q BOP Sketch ❑ Exploratory ❑ Development 2- Service ❑ 14. Estimated Date for 28 -Nov -10 15. Well Status after proposed work: Commencing Operations: Oil ❑ . Gas ❑ WINJ ❑ GINJ ❑ WDSPL ❑ Suspended ❑ WAG ❑ Abandoned ❑ 16. Verbal Approval: Date: Commission Representative: GSTOR ❑ SPLUG ❑ 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Marc D. Kuck Printed Name Marc D. Kuck Title Sr. Completion Engineer Signature Phone 907 865-3322 Date COMMISSION USE ONLY �/(� Commission that Sundry Number: 1 0 �3 Conditions of approval: Notify so a representative may witness Plug Integrity ❑ BOP Test 2r/ Mechanical Integrity Test ❑ Location Clearance ❑ Other: ,� 35� yrs BoP GSf *LN4 Subsequent Form _ APPROVED BY NE / q 'TISO-0IWS MMI THE COMMISSION Date. 11-2. Form 10-403 Revised 1/2010 '-/ "� ��,�3U K I I IV H L "/ OfI114J Submi in Duplicate to /' /U OP03-P05 Workover Data Additional Data Sheet Workover Objectives: • Objective of this workover is to pull the current TTC-ESP tubing completion and run in with a new TTC-ESP system. • Complete the planned work with no HSE accidents or incidents. Well History: OP03-05 was the first well completed by Eni Petroleum on Oliktok Point. This well was completed on January 1", 2009 with a Through -Tubing Conveyed Electric Submersible Pump (TTC-ESP) set at a depth of 5344' MD. The well was left as completed until October 2010 when the well was started up for clean out. The well was operated for approximately three days when the ESP failed due to a fault in the downhole electrical system. The well was left with production fluid in the tubing and diesel in the inner annulus. BPV is not installed. OP03-P05 production is required for "first oil" start-up of production facilities scheduled for early January. Pressure Data: This well is expected to have a static pressure of approximately 1659 psi (grad of .45 at 3686 ft TVD) with an equivalent mud wt of 8.65 ppg. 8.8 ppg hot seawater with 3% KCI is planned as kill wt fluid for this workover. Operational Plan Summary: 1. MIRU Nabors 245E. Rol; a 2. Shear GLM valve and circulate hot 8.8 ppg hot 3% KCI seawater kill fluid through tree. —i 3. Set BPV. ND tree and NU BOP and test to 3500 psi. 4. Pull tubing and examine for electrical fault or damage. LD ESP assembly. a >°� 5. MU new ESP assembly and RIH to setting depth. 6. Land hanger, RILDS and test hanger. 7. Install BPV and nipple down BOP. 8. NU tubing adapter and tree. 9. Pull BPV, install test plug and test tree. 10. Circulate Freeze protect through tree down IA taking returns up tubing. 11. Shut in well. 12. RDMO. Surf. Casing 1 13-3/8", 68 # 2351' MD/ 2158' TVD 48° Inc. Nikaitchuq Field — Oliktok Point Pad 40.1' MD/TVD Vacuum Insulated Tubing (VIT), 4-'/i' x 5-'/2", approx 78.52', two joints 4-'/2" 12.6 ppf Production Tubing 4-'/�" cable clamps, for ESP Power Cable, (1) 3/8" Chem Inj Line 5155' MD - GLM, KBMG, 4-'/" x 1 with STS -1 SOV installed Cinii PeArr®Iletumnn OP03-P05 Oil Producer with ESP Lift 5342' MD/ 3507 TVD — Bottom of Motor Centralizer Centrilift TTC-ESP, 43 -stage FC6000 pump, 513 GST3 seal, 76 HP KMH motor 5735' MD, 3644' TVD - Baker FlexLock Liner Hanger and ZXP Packer Interm. Casing 9-5/8", 47 # 5960' MD, 3686' TVD 82° Inc. Confidential As Completed 1/03/09 HAL Zonal Isolation Swell Packers (6 pkrs @ approx 910' spacing) Open Hole 12384' MD/ 3935 TVD Slotted Liner, 5-1/2" 17 ppf 12368' MD/ 3934' TVD MDK Maunder, Thomas E (DOA) From: Sent: To: Cc: Subject: rage i of jr � a Brink Jason Uason.brink@enipetroleum.comj Wednesday, March 04, 2009 8:52 AM Maunder, Thomas E (DOA); Gennings Tom; Grandi Maurizio; Longo Joseph, Province Robert Roby, David S (DOA); Davies, Stephen F (DOA); Brink Jason ENI Operations: Requires Immediate Action for change of Operator Importance: High Tom 1. The disposal well has been perforated. I am working the 10-407 and you will have the details on this well by early next week. The EPA witnessed the entire operation and verbally approved the well. We are currently completing their lengthy completion report summary and will submit to them next week. All operations were witnessed and performed successfully. ENI expects no difficulties having this disposal well approved by the EPA. 2. 1 suspected you would ask about a change of Operator. We submitted this request to our Land department on January 27th, 2009 (your initial request) and were told that ENI filed a change of operator notice about one year ago or so. Our Land department will follow up on this immediately. S p� Jason Brink St NN -Q Drilling EngineerENI P aska Office: 907-865-3321 Cell: 907-947-3790 From: Maunder, Thomas E (DOA) [mailto:tom.maunder@alaska.gov] ��r Sent: Wednesday, March 04, 2009 8:20 AM , —O To: Brink Jason; Gennings Tom; Grandi Maurizio q \ c Cc: Roby, David S (DOA); Davies, Stephen F (DOA) V\o Subject: RE: ENI Operations Thanks much Jason. Some additional questions ... 1. Has the disposal well been perforated and all the EPA verifications performed? 2. Regarding the Kerr-McGee wells, our records still show KM as the operator. It is probably appropriate to file a change of operator notice for those wells. Call or message with any questions. Tom Maunder, PE AOGCC From: Brink Jason [mailto:jason.brink@enipetroleum.com] Sent: Tuesday, March 03, 2009 5:30 PM To: Maunder, Thomas E (DOA); Gennings Tom; Grandi Maurizio Cc: Roby, David S (DOA); Davies, Stephen F (DOA) Subject: RE: ENI Operations Tom, Answers to your questions: 1. Nabors 245 is currently being cold stacked as we speak. Completion of the cold stack procedure will be next week. 3/4/2009 Page 2 of 8� 2. (permit 1) OP03-P05 is completed and shut-in with BPV installed and VR plugs installed in the annular valves. This producer will be put on production as production facilities are commissioned in late 2010. (permit 2) OP26-DSP02 is completed and shut-in with BPV installed. I am currently writing the completion 10-407 summary for the AOGCC. This disposal well could be utilized for disposal this year. ENI is currently decisioning whether or not to commission grind and injection facilities this year or in 2010. (permit 3) OPO4-P07 will not be drilled this year but will be drilled in the first quarter of 2010. 3. (permit request 4) Please continue to process this application. ENI plans to drill this water source well in the first quarter of 2010. 4. ENI wishes to not rename the two Oliktok Point wells drilled by Kerr-McGee. Please let me know if you have further questions. Jason Brink Drilling Engineer ENI Alaska Office: 907-865-3321 Cell: 807-947-3790 From: Maunder, Thomas E (DOA) [mailto:tom.maunder@alaska.gov] Sent: Tuesday, March 03, 2009 11:35 AM To: Gennings Tom; Brink Jason Cc: Roby, David S (DOA); Davies, Stephen F (DOA) Subject: ENI Operations Tom and Jason, Sorry that the current economic climate has so drastically affected your operations. I have a couple of questions I . When will rig operations be halted? 2. You have received permits for 3 new wells. What will the status of these wells be at the completion of rig operations? 3. We have received an application for a 4th well, do you desire the Commission to continue processing it? 4. In an earlier email I asked if it was intended to rename the two Oliktok Point wells drilled by Kerr-McGee. received an acknowledgement of that question; however no decision has been communicated to me. I would appreciate hearing of the decision. Thanks in advance. Call or message with any questions. Tom Maunder, PE AOGCC 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. 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. 3/4/2009 Page 1 of I) Maunder, Thomas E (DOA) From: Brink Jason Uason.brink@enipetroleum.com] Sent: Friday, January 23, 2009 10:14 AM To: Maunder, Thomas E (DOA) Subject: RE: Well OP03-P05 (208-137), ENI Petroleum Tom, Answers to questions 3. The BOP test was performed 12/3 through 12/4. This BOP test witness was waived by John Crisp We will remember to mention State witness details in our time log from now on. Wellview actually has a section to enter data specifically related to this I will paste a picture of it below Last A uthority Visit 0*0 Tot insp. Nbr Total I.N.C. number Comment 12/4=06 Alaska State Inspector BOP testwitness waived by John Crisp. Next test Dec 11. - waived visit 4. 5245' Tag hard cement 5300' is the KOP. We will take your comments and implement them in the future. Thanks Jason Brink Drilling Engineer ENI Alaska Office 907-865-3321 Cell_ 907-947-3790 From: Maunder, Thomas E (DOA) [mailto:tom,maunder@alaska.gov] Sent: Thursday, January 22, 2009 4:15 PM To: Brink Jason Subject: RE: Well OP03-PO5 (208-137), ENI Petroleum Jason, I got the days reconciled. Spud on 11116, TD on 12/22 and completed 1/3 Here are the other comments/questions . . 1. Cementing operations, addressed in earlier message. 2. LOT charts received 3. For most of the BOP tests, it is stated which Inspector either witnessed or waived witness however there are few where it is not noted. Dates are 12/3, 4. Is the KOP for drilling off the pilot hole plug 5400 or 5300 (12/9) Both depth are given 5. 1 suspect you will ask for this, but I find it useful if the size, weight, grade and thread of any tubular are given in the narrative 6. As far as the drawings go, it appears that I/we only need pages 1 and 2 which only have 1 cost entry near the 8/12/2009 r wcoO Page 2 of Y _,, bottom of page 2 and I can remove that These are my questions I will be passing this on to my colleagues so they can do their tasks. I will let you know if they have any questions Tom Maunder, PE AOGCC From: Maunder, Thomas E (DOA) Sent: Thursday, January 22, 2009 3:15 PM To: 'Brink Jason' Subject: RE: Well OP03-P05, ENI Petroleum Thanks Jason, As I said, I will send you a nate regarding my questions. One date item I did find was on Day 52 it is stated "go to completion phase at 0300 12/28/08". Using that date, I am planning to backtrack to get the dates with the operations days One "thing" that jumps right out is that I don't think I will come up with a spud date of 11/16. lam sure we will exchange more messages on this. Best regards, Tom Maunder, PE AOGCC From: Brink Jason[mailto:jason.brink@enipetroleum.com] Sent: Thursday, January 22, 2009 3:10 PM To: Maunder, Thomas E (DOA) Subject: Well OP03-P05, ENI Petroleum Just a FYI You are correct as spud is actually November 16th instead of the 17th as I have written into the Completion Summary 10-407. 1 spoke with the Company Men on the surface hole details. They did not include the level of detail that I am used to and they know it. I can tell you verbally that they loaded 2 vac trucks with surface Lead cement returns. Total of about 300 bbls surface Lead cement returns to surface. We don't have much gravel or sand in the 15r 1200' like you would expect. We are not seeing much washout. The cement returns volume and a nutplug fluid caliper both confirmed this. Reciprocation was confirmed during surface cementing until the hole got sticky and then they landed it. There is no detail on exactly when during the cement job that the casing was landed. Jason Brink Drilling Engineer ENI Alaska Office: 907-865-3321 Cell: 907-947-3790 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. 8/12/2009 PRESSURE INTEGRITY TEST Well Name: OP03-P05 Rig: Nabors 245 Date: 11/29/2008 Volume Input Volume/Stroke Pump Rate: Drilling Supervisor: _ Beauchamp / Morris Pump used: #2 Mud Pump Strokes 0.1000 Bbls/Strk 'W 5.00 Strk/min Type of Test: Casing Shoe Test LOT/Frr 1 Pumping down annulus and DP. q Casing Test Pressure Integrity Test Hole Size: Other - See Comment, V Casin Shoe Depth Hole Depth PumpingShut-in Pum in Shut-in RKB-CHF: 31.6 Ft 2351 Ft -MD 2155.0 Ft -TVD I 2358.0 Ft -MD 2160.0 Ft -TVD Casing Size and Desl:riintion: 13-3/8" 68#/Ft L-80 BTC w Strks si Min psi Strks psi Min psi 2 62 0 2538 0 30 0.00 468 Casing Test Pressure Int e rit Test 4 160 1 2528 2 40 0.25 430 Mud Weight: Mud 10 min Gel: Test Pressure: Rotating Weight: Blocks/Top Drive Weight Estimates for Test: 9.4 ppg Lb/100 Ft2 psi Lbs Lbs bbls Mud Weight: Mud 10 min Gel: Rotating Weight: Blocks/Top Drive Weight: Desired PIT EMW: Estimates for Test: 8 9 ppg Lb/100 Ft2 Lbs Lbs ppg psi#REFI 6 270 2 2500 4 63 0.50 390 6.0 6.0 8 379 3 2500 6 120 1.00 33R 2500.0 85000.0 47000.0 10 468 4 2500 8 167 1.50 3�_ 85000.0 47000.0 3.2 12 547 5 2500 10 2071 2.00 321 13.0 14 629 61 2500 12 2431 2.50 315 459 16 720 18 787 7 2500 8 2500 14 277 16 309 3.00 310 3.50 305 IwL v EMW = Leak -off Pressure + Mud Weight = 334+ 8 9 0.052 x TVD 0.052 x 2155 EMW at 2351 Ft -MD (2155 Ft -ND) = 11.9 ppq PIT 15 Second Shut-in Pressure, psi 20 861 9 2500 18 334 4.00 301 22 935 10 2500 20 368 4.50 297 430 24 1005 15 25001 22 396 5.00 293 3000 2500 2000 w 1so0 w e: e 1000 500 0 Lost 38 psi during test, held 98.5% of test pressure. 26 1092 20 25001 24 418 5.50 289 28 1170 25 2500 26 436 6.00 285 30 12481 30 2500 28 4511 6.50 282 A 32 1331 30 463 7.00 278 34 1422 32 468 7.50 275 36 1504 34 467 8.00 271 38 1595 36 468 8.50 268 40 1682 38 468 9.00 264 42 1790 40 468 9.50 2P' 44 1888 10.00 46 1987 481 2091 50 2190 52 2303 54 2409 56 2538 0 1 2 3 4 5 Barrels 'y -CASING TEST -11--LEAK-OFF TEST 6 o 5 10 15 20 25 30 Shut -In time, Minutes O PIT Point Volume Pum ed Volume Bled Back Volume Pum ed Volume Bled Back S S S S Comments: 16" Hole, not available at pick list. LV I MI -771-7) is aro water base.xls Summary PRESSURE INTEGRITY TEST Well Name: IOP03-P05 IRig: I245E Nabors Date: 12/14/2008 Volume Input Volume/Stroke Pump Rate: Drilling Supervisor: Keener / Walls Pump used: #t Mud Pump IV strokes 'W 0.1010 Bbls/Strk 'W 3.00 Strk/min Type of Test: Casing Shoe Test LOT/FIT Pumping down annulus and DP. w Hole Size: 8-1/2" Casin Shoe De th RKB-CHF: 35.5 Ft 5960 Ft -MD 3685.0 F Casing Size and Description: 9-5/8" 40#/Ft L-80 BTC Casina Test Mud Weight: 9.7 ppg Mud 10 min Gel: 19.0 Lb/100 Ft2 Mud 10 min Test Pressure: 2650.0 psi Rotating We Rotating Weight: 110.0 Lbs Blocks/Top Drive Wi Blocks/Top Drive Weight 43.0 Lbs Desired PIT E 3000 2500 2000 W 7 N 1500 W It Q. 1000 Soo rressure * mug vlletgnt = i2 x TVD EMW at 5960 Ft -MD (S 0.052 x 3685 +9.2 Ft -ND) = 12.0 ppg 011� ght: ppg 3e1: 19.0 Lb/100 Ft2 ght: 111.0 Lbs ight:l 43.0 Lbs AW: 1 12.0 ppg est: 537 x___0.9 bbls PIT 15 Second Shut-in Pressure, psi 535 Lost 40 psi during test, held 98.5% of test pressure. 0 1 2 3 4 5 0 5 10 15 20 25 30 Barrels Shut -In time, Minutes 'CASING TEST —11—'LEAK-OFF TEST O PIT Point 15 5361 1 151 13011 1.501 5.. ume II volume Summary ®� mom EF1 M01 ume II volume Summary Kt(;EIVE% STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION A 4D JAN 1 5 2009 WELL COMPLETION OR RECOMPLETION REPORIA'AINOW rIs. scion Ia. Well Status: Oil Gas[_] Plugged ❑ Abandoned ❑ Suspended ❑ 20AAC 25.105 20AAC 25.110 GINJ❑ WINJ❑ WDSPL❑ WAGE] Other❑ No. of Completions: 1b. Well Class: Anchorage Development 0 Explore ory❑ Service ❑ Stratigraphic Test[] 2. Operator Name: ENI US Operating Co Inc 5. Date Comp., Susp., or Abend.: 1/3/2009 . 12. Permit to Drill Number: 208-137 ' 3. Address: 3800 Centerpoint Drive Suite 300, Anchorage 99503 6. Date pud d: //L 6) 11 20 13. API Number: 50-029-23396-00 4a. Location of Well (Governmental Section): Surface: 3,220' FSL and 1,533' FEL of S5, T13N, R9E, UM Top of Productive Horizon: 601' FSL and 4395' FEL of S33, T�14,Nt, R9E, UM Total Depth:` 2,t,.37�✓�Al•yr • SL and q,36 FEL of S28, T14N, R9E, UM 7. Date TO Reached: 12/22/2008 14. Well Name and Number: OP03-P05 8. KB (ft above MSL): 52 Ground (ft MSL): 12 15. Field/Pool(s): Nikaitchuq . 9. Plug Back Depth(MD+TVD): 12324' MD / 3934' TVD 4b. Location of Well (State Base Plane Coordinates, NAD 27): Surface: x- 516746.34 y- 6036573.11 Zone- 4 TPI: x- 519183.17 y- 6039086.69 Zone- 4 Total Depth: x- 519138.37 y- 6045610.42 Zone- 4 10, Total Depth (MD +TVD): . 12384' MD / 3935' TVD - 16. P Designation: 3 , 55024, 355023, 390615 11. SSSV Depth (MD +TVD): none 17. Land Use Permit: ADL 390616 18. Directional Survey: Yes LJ No (Submit electronic and printed information per 20 AAC 25.050) 19. Water Depth, if Offshore: NA (ft MSL) 20. Thickness of Permafrost (TVD): 1775' TVD 21. Logs Obtained (List all logs here and submit electronic and printed information per 20 AAC 25.071): GR/Res Neu/Den 22. CASING, LINER AND CEMENTING RECORD WT. PER GRADE SETTING DEPTH MD SETTING DEPTH TVD HOLE SIZE CEMENTING RECORD AMOUNT CASING FT TOP BOTTOM TOP BOTTOM PULLED 20" 178.89 X-65 SURFACE 115' SURFACE 115' 30 Cement to Surface 13-3/8" 68 L-80 SURFACE 2350' SURFACE 2156' 16 454 bbls AS Lde, 73 bbls Litecmte 9-5/8" 47 L-80 SURFACE 5960' SURFACE 3693' 12.25 84 bbls Deeperete 5.5" 17 L-80 5765' 12324' 3641' 3934' 8.5 slotted liner 23. Open to production or injection? YesO No❑ If Yes, list each interval open (MD+TVD of Top & Bottom: Perforation Size and Number): slotted liner 24. TUBING RECORD SIZE I DEPTH SET (MD) PACKER SET (MD) 4.5" 1 5344' 1 ESP completion/ no PKR 25. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED 26, PRODUCTION TEST Date First Production: NA / Constructing Processing Facility Method of Operation (Flowing, gas lift, etc.): ESP Date of Test: Hours Tested: Production for Test Period Oil -Bbl: Gas -MCF: Water -Bbl: Choke Size: Gas -Oil Ratio: Flow Tubing Press. Casing Press: Calculated 24 -Hour Rate -.0p Oil -Bbl: Gas -MCF: Water -Bbl: Oil Gravity - API (corr): 27. CORE DATA Conventional Cores) Acquired? Yes ❑ No[D Sidewall Cores Acquired? Yes ❑ No E - 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. r C06f. PL LTi ON 0 IZBDIYIS WL JAN 2 61009 VERIfLE, Form 10-407 Revised 2/2007 CONTINUED ON REVERSE ORIGINAL 28. GEOLOGIC MARKERS (List all formations and markers encountered): 29. FORMATION TESTS NAME MD TVD Well tested? LJ Yes 21 No. If yes, list intervals and formations tested, briefly summarizing test results. Attach separate sheets to this forth, if Permafrost - Top Surface Surface needed, and submit detailed test information per 20 AAC 25.071. Permafrost - Base 1848' 1775' OA sand top 5964' 3686' Formation at total depth: OA sand 12384' 3935' 30. List of Attachments: Summary of Daily Operations, Directional Survey 31. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Jason Brink @ 907-865-3321 Printed Name: Maurizio Grandi ! Title: Well Operation Project Manager Signature: Phone: Qz)7 ' 6 T330 c Dater 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 Is: Classification of Service wells: Gas Injection, Water Injection, Water-Ahernating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 4b: TPI (Top of Producing Interval). Item 8: The Kelly Bushing and Ground Level elevations in feet above mean sea level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). Item 20: Report true vertical thickness of permafrost in Box 20. Provide MD and TVD for the top and base of permafrost in Box 28. Item 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in hem 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, or Other (explain). Item 27: Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Submit detailed description and analytical laboratory information required by 20 AAC 25.071. Item 29: Provide a listing of intervals tested and the corresponding formation, and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Form 10-407 Revised 2/2007 %' \ 11 G 1 V ! \ L Enri� Ffttrollewnnn Schlumberger OP03-POS Survev Report Client: ENI Field: Nikailchuq Structure I slot: Oliktok Point I OP03 Well: OP03-P05 Borehole: OP03-P05 UWUAPIk: 500292339600 Survey Name l Date: OP03-PO51 December 22, 2008 TOO I AND I DDI I ERD ratio: 294.073° 110385.56 ft / 6.98312.639 Grid Coordinate System: NAD27 Alaska State Planes, Zone 04, US Feet Location LaULong: N 70.51110601, W 149.86296360 Location Grid WE YIX: N 6036573.110 fIUS, E 519746.340 fIUS Grid Convergence Angle: +0.12918509° Grid Scale Factor: 0,99990032 Vertical Section Azimuth: 1.000° Vertical Section Origin: N 0.000 it E 0.000 it TO Reference Datum: Rotary Table ND Reference Elevation: 53.20 ft relative t0 MSL ' Sea Bed / Ground Level Elevation: 12.20 It relative t0 MSL Magnetic Declination: 22.447' Total Field Strength: 57668.368 nT Magnetic Dip: 80.930° Declination Dale: December 15, 2008 Magnetic Declination Model: BGGM 2008 North Reference: True North Total Corr Mag North -> True North: +22.447° Ccmmenls Measured Inclination Azimuth Sub4ea TVD TO Vertical Along Hole Closure NS EW OLS Northing Easting Latitude Longitude 516746.34 Depth N70.5 i TI 060 Vv i49.6629636U NSG+SSHOT Section Departure 281.67 -2.20 51.00 0.01 0.05 0.05 0.01 k de de fl tt it k fl fl k de look kUS flUS 27.80 RTE U.UU U.UU U.UU -53.2U U.UU U.UU U.UU U.UU U.UD U.VU 0.00 6036573.11 516746.34 N70.5 i TI 060 Vv i49.6629636U NSG+SSHOT 51.00 0.11 281.67 -2.20 51.00 0.01 0.05 0.05 0.01 -0.05 0.22 6036573.12 516746.29 N 70.51110603 W 149.86296399 81.00 0.08 46.14 27.80 81.00 0.03 0.07 0.07 0.03 -0.06 0.56 6036573.14 516746.28 N 70.51110609 W 149.86296410 111.00 0.17 94.73 57.80 111.00 0.04 0.13 0.04 0.04 0.00 0.44 6036573.15 516746.34 N 70.51110612 W 149.86296361 141.00 0.17 134.04 87.80 141.00 0.01 0.22 0.08 0.01 0.07 0.38 6036573.12 516746.41 N 70.51110602 W 149.86296299 179.00 0.19 158.18 125.80 179.00 -0.09 0.34 0.17 -0.09 0.14 0.20 6036573.02 516746.48 N 70.51110576 W 149.86296246 241.00 0.15 161.26 187.80 241.00 -0.26 0.52 0.33 -0.26 0.20 0.07 6036572.85 516746.54 N 70.51110529 W 149.86296194 302.00 0.35 89.34 248.80 302.00 -0.33 0.76 0.53 -0.34 0.41 0.55 6036572.77 516746.76 N 70.51110509 W 149.86296020 333.00 0.71 69.17 279.80 333.00 -0.26 1.D4 0.74 -0.27 0.69 1.29 6036572.84 516747.03 N 70.51110528 W 149.86295796 364.00 1.03 56.86 310.79 363.99 -0.03 1.51 1.10 -0.05 1.10 1.19 6036573.07 516747.44 N 70.51110588 W 149.86295458 394.00 1.39 55.11 340.79 393.99 0.34 2.14 1.66 0.31 1.63 1.21 6036573.42 516747.97 N 70.51110685 W 149.86295029 425.00 1.69 48.87 371.78 424.98 0.86 2.98 2.42 0.82 2.28 1.11 6036573.94 516748.62 N 70.51110826 W 149.8629449E 456.00 2.08 47.70 402.76 455.96 1.56 3.99 3.39 1.50 3.04 1.26 6036574.62 516749.38 N 70.51111011 W 149.8629387, 487.00 3.09 33.86 433.73 486.93 2.64 5.39 4.69 2.58 3.92 3.81 6036575.69 516750.25 N 70.51111304 W 149.86293152 520.00 3.82 30.92 466.67 519.87 4.34 7.37 6.55 4.26 4.98 2.28 6036577.38 516751.31 N 70.51111764 W 149.86292284 550.00 4.92 29.25 496.58 549.78 6.34 9.66 8.74 6.24 6.12 3.69 6036579.36 516752.45 N 70.51112305 W 149.86291349 593.00 5.45 28.94 539.40 592.60 9.77 13.55 12.53 9.63 8.01 1.23 6036582.76 516754.33 N 70.51113232 W 149.86289804 Last Gyro 643.00 6.60 27.70 589.13 642.33 14.44 18.79 17.70 14.26 10.50 2.31 6036587.39 516756.80 N 70.51114495 W 149.86287771 MWD+GMAG 675.74 6.75 27.81 621.64 674.84 17.83 22.60 21.47 17.62 12.27 0.46 6036590.76 516758.57 N 70.51115415 W 149.86286320 768.13 8.26 28.84 713.24 766.44 28.55 34.67 33.49 28.24 18.00 1.64 6036601.39 516764.28 N 70.51118315 W 149.86281628 863.79 9.86 30.84 807.70 860.90 41.73 49.73 48.54 41.29 25.52 1.70 6036614.46 516771.76 N 70.51121881 W 149.86275480 959.39 13.95 30.83 901.23 954.43 58.84 69.45 68.26 58.22 35.62 4.28 6036631.41 516781.83 N 70.51126506 W 149.86267211 1055.45 13.29 37.29 994.59 1047.79 77.78 92.04 90.83 76.95 48.25 1.73 6036650.16 516794.41 N 70.51131622 W 149.86256881 1151.78 17.23 47.29 1087.52 1140.72 96.57 117.33 115.73 95.45 65.45 4.90 6036668.69 516811.57 N 70.51136675 W 149.86242807 SuweyEdftor Ver SP 2.1 Bid( doc4Ox_100 ) OP03\OP03-PO5\OP03-PO5\OP03-PO5 Generated 111 5120 09 11:06 AM Page 1 of 5 Comments Measuretl Inclination Azimuth Sub -Sea TVD Vertical Along Hole Closure HIS EW OLS Northing Easting Latitude Longitude Depth 88.30 I Section Departure 816655.3/ N /0.51142039 W 149.86275291 1342.33 22.19 % de de % k N N k % % 0 1100% Nus flus 134.68 124L25 20.88 53.28 117/.85 1231.05 118.62 148.24 148.80 118.08 88.30 4.118 8u38688.38 816655.3/ N /0.51142039 W 149.86275291 1342.33 22.19 57.65 1266.38 1319.58 136.72 182.89 178.97 134.68 117.86 2.38 6036708.04 516863.89 N 70.51147393 W 149.86199918 1439.00 24.00 59.30 1355.30 1408.50 157.08 220.80 215.46 154.49 150.19 1.99 6036727.92 516896.17 N 70.51152804 W149.86173465 1485.63 24.31 59.06 1397.84 1451.04 167.14 239.89 233.95 164.26 166.58 0.70 6036737.73 516912.53 N 70.51155474 W149.86160057 1532.89 24.77 59.66 1440.83 1494.03 177.44 259.51 253.04 174.27 183.47 1.11 6036747.77 516929.40 N 70.51158207 W 149.86146238 1628.19 24.76 60.43 1527.37 1580.57 197.97 299.43 292.00 194.20 218.06 0.34 6036767.78 516963.94 N 70.51163652 W 149.86117937 1723.85 26.67 62.34 1613.55 1666.75 218.46 340.94 332.55 214.05 254.50 2.18 6036787.71 517000.33 N 70.51169075 W149.86088118 1820.50 29.22 62.28 1698.93 1752.13 240.20 386.22 376.91 235.10 294.60 2.64 6036808.85 517040.38 N 70.51174825 W 149.86055304 1915.77 32.88 62.44 1780.53 1833.73 263.75 435.35 425.25 257.89 338.13 3.84 6036831.73 517083.85 N 70.51181050 W149.86019689 2011.43 36.93 62.27 1858.97 1912.17 289.99 490.08 479.28 283.28 386.60 4.23 6036857.24 517132.26 N 70.51187987 W 149.85980021 2107.31 42.53 63.06 1932.68 1985.88 319.04 551.34 539.88 311.39 441.03 5.86 6036885.46 517186.62 N 70.51195665 W 149.85935482 2202.72 44.14 64.83 2002.07 2055.27 348.81 616.81 604.60 340.13 499.85 2.11 6036914.34 517245.37 N 70.51203516 W 149.85887349 2289.22 46.70 67.27 2062.79 2115.99 374.76 678.41 665.30 365.11 556.16 3.58 6036939.44 517301.62 N 70.51210338 W 149.85841275 13-3/8" 2351'md 2416.08 49.99 67.89 2147.09 2200.29 412.42 773.19 758.58 401.24 643.77 2.62 6036975.76 517389.14 N 70.51220207 W 149.85769583 2512.29 52.61 70.38 2207.25 2260.45 440.35 848.26 832.37 427.95 713.93 3.39 6037002.63 517459.23 N 70.51227502 W 149.85712174 2607.91 54.14 71.93 2264.29 2317.49 466.39 925.00 907.54 452.73 786.55 2.06 6037027.57 517531.79 N 70.51234269 W 149.85652746 2703.27 59.45 73.10 2316.50 2369.70 491.65 1004.76 985.57 476.67 862.63 5.66 6037051.68 517607.81 N 70.51240806 W 149.85590489 2799.58 61.55 74.35 2363.92 2417.12 516.53 1088.57 1067.51 500.15 943.09 2.46 6037075.33 517688.21 N 70.51247218 W 149.85524648 2894.25 65.66 73.35 2406.00 2459.20 541.55 1173.36 1150.63 523.75 1024.53 4.44 6037099.11 517769.58 N 70.51253661 W 149.85458011 2990.61 67.91 73.03 2443.98 2497.18 568.63 1261.91 1237.87 549.36 1109.29 2.35 6037124.91 517854.28 N 70.51260654 W 149.85388644 3086.28 67.62 72.12 2480.18 2533.38 596.62 1350.46 1325.42 575.87 1193.78 0.93 6037151.62 517938.70 N 70.51267895 W 149.85319503 3181.28 67.80 72.25 2516.22 2569.42 624.97 1438.37 1412.54 602.77 1277.47 0.23 6037178.69 518022.32 N 70.51275238 W 149.85251020 3276.99 67.63 70.31 2552.51 2605.71 654.85 1526.93 1500.55 631.19 1361.34 1.88 6037207.30 518106.12 N 70.51282998 W 149.85182385 3373.28 67.47 67.26 2589.29 2642.49 688.49 1615.91 1589.36 663.38 1444.29 2.93 6037239.68 518188.98 N 70.51291790 W 149.85114503 3469.07 66.53 65.02 2626.72 2679.92 725.55 1704.09 1677.52 699.04 1524.92 2.37 6037275.52 518269.53 N 70.51301527 W 149.85048515 3564.54 66.33 63.39 2664.90 2718.10 764.99 1791.59 1765.00 737.12 1603.71 1.58 6037313.77 518348.22 N 70.51311924 W 149.84984040 3661.47 64.98 58.37 2704.88 2758.08 809.27 1879.89 1853.02 780.06 1680.83 4.92 6037356.87 518425.24 N 70.51323649 W 149.84920922 3757.78 63.04 52.93 2747.11 2800.31 859.30 1966.44 1938.42 828.85 1752.28 5.46 6037405.82 518496.57 N 70.51336974 W 149.84862443 3853.53 63.58 49.59 2790.12 2843.32 913.99 2051.99 2021.71 882.38 1818.99 3.17 6037459.50 518563.15. N 70.51351593 W 149.848078431 3950.54 63.41 46.87 2833.42 2886.62 972.93 2138.80 2105.33 940.20 1883.73 2.52 6037517.46 518627.76 N 70.51367384 W 149.847548E 4046.70 62.46 43.33 2877.19 2930.39 1034.40 2224.42 2186.75 1000.62 1944.38 3.42 6037578.01 518688.26 N 70.51383886 W 149.8470520 4141.64 62.01 40.30 2921.42 2974.62 1097.97 2308.43 2265.39 1063.22 2000.39 2.86 6037640.73 518744.12 N 70.51400983 W 149.84659364 4236.81 62.15 37.36 2965.99 3019.19 1164.38 2392.51 2342.91 1128.72 2053.10 2.73 6037706.34 518796.69 N 70.51418873 W 149.84616209 4330.40 62.49 34.16 3009.48 3062.68 1232.46 2475.39 2418.00 1195.96 2101.53 3.05 6037773.68 518844.95 N 70.51437239 W 149.84576567 4427.15 62.75 31.02 3053.98 3107.18 1305.62 2561.29 2494.33 1268.33 2147.79 2.89 6037846.15 518891.05 N 70.51457007 W 149.84538690 4523.33 62.48 27.20 3098.23 3151.43 1380.93 2646.69 2568.39 1342.93 2189.33 3.54 6037920.83 518932.41 N 70.51477381 W 149.84504678 4618.58 62.22 24.86 3142.44 3195.64 1457.37 2731.06 2639.97 1418.73 2226.35 2.19 6037996.71 518969.26 N 70.51498087 W 149.84474360 4714.49 61.60 23.50 3187.60 3240.80 1535.15 2815.67 2711.08 1495.92 2261.01 1.41 6038073.97 519003.74 N 70.51519170 W 149.84445977 4811.08 61.02 22.60 3233.97 3287.17 1613.68 2900.40 2782.16 1573.88 2294.19 1.01 6038152.00 519036.74 N 70.51540466 W 149.84418806 4907.50 62.79 20.67 3279.38 3332.58 1693.28 2985.46 2853.13 1652.94 2325.53 2.55 6038231.12 519067.90 N 70.51562062 W 149.84393132 5002.69 65.14 16.43 3321.18 3374.38 1774.81 3070.97 2922.67 1734.01 2352.70 4.70 6038312.24 519094.89 N 70.51584206 W 149.84370876 SurveyEditor Ver SP 2.1 Bid( doUOx_100 ) OP03\OP03-P05\OP03-PO5\OP03-PO5 Generated 1/15/2009 11:06 AM Page 2 of 5 Comments Measured Inclination Azimuth Sub-Sea TV NO Vertical Along Hole Closure NS EW DLS Northing Easling Latitude Longitude 2991.88 Depth 1819.17 Section Departure 3.20 6038397.44 519117.27 N 70.51607468 W 149.84352377 % tl da k k k X k X X d H00 (Xus) (XUS 3247.85 SurveyEditor Ver SP 2.1 3ld(doc4Ox_100) OP03\OP03-P05\OP03-P05\OP03-P05 Generated 1/15/2009 11:06 AM Page 3 of 5 5099.36 66.29 13.28 3360.94 3414.14 1860.34 3159.08 2991.88 1819.17 2375.28 3.20 6038397.44 519117.27 N 70.51607468 W 149.84352377 5195.77 67.79 10.30 3398.56 3451.76 1947.53 3247.85 3059.64 1906.05 2393.40 3.24 6038484.36 519135.20 N 70.51631202 W 149.84337522 Tie -In Survey 5195.77 67.79 10.30 3398.56 3451.76 1947.53 3247.85 3059.64 1906.05 2393.40 1.44 6038484.36 519135.20 N 70.51631202 W 149.84337522 MWD+GMAG 5259.92 68.26 9.73 3422.56 3475.76 2006.29 3307.34 3104.48 1964.64 2403.75 1.10 6038542.96 519145.41 N 70.51647205 W 149.84329040 5319.20 67.13 9.62 3445.06 3498.26 2060.51 3362.18 3146.04 2018.70 2412.96 1.91 6038597.04 519154.50 N 70.51661974 W 149.84321482 5362.87 65.95 10.13 3462.44 3515.64 2100.08 3402.24 3176.73 2058.17 2419.83 2.91 6038636.52 519161.28 N 70.51672755 W 149.84315849 5397.42 66.32 9.51 3476.42 3529.62 2131.31 3433.84 3201.07 2089.30 2425.22 1.96 6038667.66 519166.60 N 70.51681259 W 149.84311430 5428.29 67.74 8.62 3488.47 3541.67 2159.45 3462.26 3222.84 2117.37 2429.70 5.31 6038695.73 519171.01 N 70.51688926 W 149.84307759 5458.27 69.15 8.16 3499.48 3552.68 2187.10 3490.14 3244.08 2144.95 2433.77 4.91 6038723.32 519175.02 N 70.51696461 W 149.84304422 5492.34 69.91 7.49 3511.40 3564.60 2218.79 3522.06 3268.31 2176.57 2438.11 2.89 6038754.95 519179.29 N 70.51705099 W149.84300857 5523.36 70.57 6.02 3521.89 3575.09 2247.84 3551.25 3290.23 2205.56 2441.54 4.94 6038783.95 519182.66 N 70.51713019 W 149.84298040 5553.27 71.67 4.47 3531.57 3584.77 2276.06 3579.55 3311.10 2233.74 2444.13 6.13 6038812.13 519185.18 N 70.51720717 W 149.84295916 -^ 5648.64 72.62 359.10 3560.83 3614.03 2366.79 3670.32 3374.99 2324.43 2446.95 5.45 6038902.82 519187.79 N 70.51745493 W 149.8429358b 5743.84 74.01 358.28 3588.16 3641.36 2457.90 3761.51 3436.92 2415.60 2444.86 1.68 6038993.97 519185.50 N 70.51770398 W 149.84295271 5838.96 77.52 358.97 3611.54 3664.74 2550.00 3853.70 3500.77 2507.76 2442.65 3.76 6039086.11 519183.08 N 70.51795574 W 149.84297053 5935.30 81.51 358.20 3629.07 3682.27 2644.63 3948.41 3567.60 2602.44 2440.31 4.22 6039180.78 519180.53 N 70.51821440 W 149.84298946 9-5/8" @ 5960'md 6055.77 84.01 0.25 3644.26 3697.46 2764.07 4067.91 3654.60 2721.92 2438.70 2.67 6039300.25 519178.65 N 70.51854081 W 149.84300231 6151.80 86.99 0.15 3651.79 3704.99 2859.78 4163.63 3726.66 2817.64 2439.03 3.10 6039395.96 519178.76 N 70.51880231 W 149.84299932 6248.10 86.67 359.67 3657.11 3710.31 2955.92 4259.78 3799.78 2913.80 2438.88 0.60 6039492.10 519178.40 N 70.51906499 W 149.84300030 6343.73 90.53 359.96 3659.45 3712.65 3051.48 4355.37 3873.37 3009.38 2438.57 4.05 6039587.67 519177.87 N 70.51932611 W 149.84300257 6439.16 91.49 359.72 3657.77 3710.97 3146.87 4450.78 3947.79 3104.79 2438.31 1.04 6039683.08 519177.39 N 70.51958676 W 149.84300449 6533.16 89.52 357.82 3656.94 3710.14 3240.79 4544.77 4020.89 3198.76 2436.29 2.91 6039777.03 519175.16 N 70.51984347 W 149.84302076 6630.79 87.79 356.33 3659.23 3712.43 3338.16 4642.37 4095.90 3296.23 2431.31 2.34 6039874.48 519169.96 N 70.52010974 W 149.84306126 6723.70 87.30 355.14 3663.21 3716.41 3430.59 4735.20 4166.73 3388.79 2424.40 1.38 6039967.02 519162.85 N 70.52036262 W 149.84311752 6819.79 87.59 355.13 3667.50 3720.70 3526.08 4831.19 4240.24 3484.44 2416.26 0.30 6040062.64 519154.50 N 70.52062393 W 149.84318391 6914.93 89.33 355.96 3670.05 3723.25 3620.75 4926.29 4314.37 3579.26 2408.88 2.03 6040157.42 519146.90 N 70.52088295 W 149.84324412 7012.37 88.48 355.34 3671.91 3725.11 3717.75 5023.72 4391.25 3676.40 2401.49 1.08 6040254.54 519139.29 N 70.52114833 W 149.84330435 7107.59 88.73 354.72 3674.23 3727.43 3812.42 5118.91 4466.52 3771.23 2393.24 0.70 6040349.34 519130.83 N 70.52140741 W 149.84337161 7203.60 86.67 355.78 3678.09 3731.29 3907.87 5214.83 4543.35 3866.83 2385.30 2.41 6040444.91 519122.67 N 70.52166857 W 149.84343640 7299.18 86.32 359.04 3683.93 3737.13 4003.07 5310.24 4622.50 3962.12 2380.99 3.42 6040540.18 519118.15 N 70.52192890 W 149.84347144, 7394.65 83.03 359.04 3692.79 3745.99 4098.06 5405.28 4703.40 4057.15 2379.39 3.45 6040635.20 519116.34 N 70.52218851 W 149.8434842;, 7490.89 83.03 359.74 3704.47 3757.67 4193.55 5500.81 4785.54 4152.67 2378.38 0.72 6040730.71 519115.11 N 70.52244947 W 149.84349230 7585.93 85.84 4.22 3713.69 3766.89 4288.09 5595.39 4869.37 4247.17 2381.65 5.55 6040825.21 519118.17 N 70.52270763 W 149.84346523 7681.64 88.22 7.00 3718.65 3771.85 4383.35 5690.97 4957.04 4342.28 2391.00 3.82 6040920.33 519127.30 N 70.52296744 W 149.84338848 7778.26 85.12 5.93 3724.26 3777.46 4479.35 5787.41 5046.36 4438.11 2401.86 3.39 6041016.17 519137.94 N 70.52322922 W 149.84329931 7875.15 80.92 3.46 3736.03 3789.23 4575.29 5883.56 5134.52 4533.93 2409.74 5.02 6041112.00 519145.60 N 70.52349098 W 149.84323455 7971.89 79.59 2.36 3752.41 3805.61 4670.58 5978.90 5221.03 4629.15 2414.58 1.77 6041207.22 519150.23 N 70.52375110 W 149.84319465 8067.01 80.49 2.69 3768.86 3822.06 4764.23 6072.59 5306.07 4722.74 2418.71 1.01 6041300.81 519154.15 N 70.52400678 W 149.84316061 8162.64 84.41 4.13 3781.42 3834.62 4858.93 6167.37 5392.99 4817.35 2424.35 4.36 6041395.43 519159.58 N 70.52426524 W 149.84311416 8257.68 87.96 5.52 3787.75 3840.95 4953.53 6262.18 5481.08 4911.83 2432.33 4.01 6041489.91 519167.34 N 70.52452333 W 149.84304859 8354.01 91.07 6.11 3788.56 3841.76 5049.50 6358.50 5571.38 5007.65 2442.08 3.29 6041585.74 519176.88 N 70.52478508 W 149.84296843 8448.79 88.73 4.41 3788.73 3841.93 5144.01 6453.27 5660.11 5102.02 2450.77 3.05 6041680.12 519185.35 N 70.52504288 W 149.84289704 SurveyEditor Ver SP 2.1 3ld(doc4Ox_100) OP03\OP03-P05\OP03-P05\OP03-P05 Generated 1/15/2009 11:06 AM Page 3 of 5 Comments Measured Inclination Azimuth Sub-SeaN 7yp Vertical Along Hole Closure NS EW OLS Northing Easting Latitude Longitude 5197.58 Depth 2456.34 2.78 6041775.68 Section Departure N 70.52530392 W 149.84285118 8638.88 87.90 IN) d de K X k k X K K 0 iooX huS XOS 2458.31 SurveyEditor Ver SP 2.1 Bid( doc40x_100 ) OP03\OP03-P05\OP03-P05\OP03-P05 Generated 1/15/2009 11:06 AM Page 4 of 5 8544.58 87.16 2.26 3792.16 3845.36 5239.65 6549.00 5748.77 5197.58 2456.34 2.78 6041775.68 519190.71 N 70.52530392 W 149.84285118 8638.88 87.90 0.13 3796.23 3849.43 5333.86 6643.21 5834.90 5291.76 2458.31 2.39 6041869.86 519192.46 N 70.52556122 W 149.84283484 8734.36 89.26 1.19 3798.59 3851.79 5429.30 6738.66 5922.05 5387.20 2459.41 1.81 6041965.30 519193.34 N 70.52582195 W 149.84282558 8829.33 89.90 1.58 3799.29 3852.49 5524.27 6833.63 6009.48 5482.14 2461.70 0.79 6042060.23 519195.43 N 70.52608131 W 149.84280653 8926.31 90.95 1.02 3798.57 3851.77 5621.24 6930.60 6098.94 5579.09 2463.90 1.23 6042157.17 519197.41 N 70.52634616 W 149.84278825 9021.61 89.82 359.40 3797.93 3851.13 5716.53 7025.90 6186.37 5674.38 2464.25 2.07 6042252.46 519197.54 N 70.52660649 W 149.84278513 9117.42 89.45 359.35 3798.54 3851.74 5812.30 7121.71 6273.95 5770.19 2463.21 0.39 6042348.25 519196.28 N 70.52686821 W 149.84279343 9214.09 91.39 359.66 3797.83 3851.03 5908.93 7218.37 6362.64 5866.85 2462.37 2.03 6042444.90 519195.23 N 70.52713226 W 149.84280000 9308.19 93.70 358.66 3793.65 3846.85 6002.88 7312.37 6448.88 5960.84 2460.99 2.67 6042538.87 519193.64 N 70.52738903 W 149.84281102 9405.03 92.25 356.33 3788.63 3841.83 6099.40 7409.08 6536.69 6057.44 2456.77 2.83 6042635.46 519189.19 N 70.52765295 W 149.84284538 9499.37 92.47 357.34 3784.74 3837.94 6193.41 7503.34 6622.07 6151.56 2451.56 1.09 6042729.55 519183.78 N 70.52791007 W 149.84288774 Tie -In Survey 9594.12 88.28 355.83 3784.12 3837.32 6287.85 7598.06 6707.94 6246.11 2445.92 4.70 6042824.09 519177.92 N 70.52816839 W 149.8429337(` MWD+GMAG 9690.40 86.67 355.29 3788.36 3841.56 6383.60 7694.25 6794.65 6342.01 2438.47 1.76 6042919.95 519170.26 N 70.52843036 W 149.8429944-i 9786.71 86.33 356.15 3794.24 3847.44 6479.32 7790.38 6881.67 6437.87 2431.30 0.96 6043015.79 519162.87 N 70.52869225 W 149.84305291 9882.76 88.97 358.95 3798.18 3851.38 6575.10 7886.34 6970.00 6533.73 2427.20 4.00 6043111.63 519158.56 N 70.52895413 W 149.84308622 9978.17 88.18 359.81 3800.55 3853.75 6670.44 7981.72 7059.13 6629.11 2426.17 1.22 6043206.99 519157.31 N 70.52921468 W 149.84309442 10074.47 85.96 359.04 3805.48 3858.68 6766.57 8077.88 7149.18 6725.27 2425.20 2.44 6043303.15 519156.13 N 70.52947738 W 149.84310206 10170.93 85.16 359.55 3812.94 3866.14 6862.70 8174.05 7239.32 6821.43 2424.02 0.98 6043399.29 519154.73 N 70.52974009 W 149.84311150 10265.21 85.61 358.64 3820.53 3873.73 6956.62 8268.03 7327.44 6915.39 2422.53 1.07 6043493.24 519153.03 N 70.52999678 W 149.84312340 10362.44 87.76 358.95 3826.15 3879.35 7053.61 8365.09 7418.42 7012.43 2420.49 2.23 6043590.27 519150.77 N 70.53026188 W 149.84313986 10455.76 90.24 359.61 3827.78 3880.98 7146.86 8458.39 7506.29 7105.72 2419.32 2.75 6043683.55 519149.39 N 70.53051673 W 149.84314921 10553.66 90.28 359.95 3827.34 3880.54 7244.74 8556.29 7598.91 7203.62 2418.94 0.35 6043781.43 519148.79 N 70.53078418 W 149.84315203 10646.62 88.19 357.94 3828.58 3881.78 7337.62 8649.23 7686.52 7296.55 2417.23 3.12 6043874.35 519146.87 N 70.53103804 W 149.84316579 10743.33 87.05 357.39 3832.59 3885.79 7434.08 8745.86 7777.00 7393.09 2413.30 1.31 6043970.87 519142.72 N 70.53130179 W 149.84319777 10838.23 87.36 357.42 3837.22 3890.42 7528.68 8840.65 7865.76 7487.78 2409.01 0.33 6044065.54 519138.21 N 70.53156047 W 149.84323267 10935.61 87.99 357.87 3841.17 3894.37 7625.82 8937.95 7957.15 7585.00 2405.01 0.79 6044162.74 519134.00 N 70.53182606 W 149.84326516 11030.81 87.48 357.94 3844.93 3898.13 7720.80 9033.07 8046.78 7680.06 2401.53 0.54 6044257.78 519130.31 N 70.53208575 W 149.84329339 11125.45 88.62 358.98 3848.15 3901.35 7815.29 9127.65 8136.32 7774.61 2398.99 1.63 6044352.32 519127.55 N 70.53234405 W 149.84331396 11220.65 88.39 0.12 3850.64 3903.84 7910.43 9222.82 8227.08 7869.77 2398.24 1.22 6044447.47 519126.59 N 70.53260402 W 149.84331983.` 11317.58 89.90 1.96 3852.08 3905.28 8007.34 9319.74 8320.32 7966.67 2400.00 2.46 6044544.36 519128.13 N 70.53286872 W 149.843305' 11413.71 87.79 1.58 3854.02 3907.22 8103.44 9415.84 8413.19 8062.73 2402.97 2.23 6044640.41 519130.88 N 70.53313114 W 149.8432805, 11508.56 87.63 1.32 3857.81 3911.01 8198.21 9510.62 8504.71 8157.47 2405.37 0.32 6044735.15 519133.07 N 70.53338996 W 149.84326069 11604.15 87.22 0.88 3862.11 3915.31 8293.70 9606.11 8596.84 8252.95 2407.20 0.63 6044830.62 519134.68 N 70.53365079 W 149.84324542 11698.80 89.84 1.63 3864.53 3917.73 8388.31 9700.72 8688.26 8347.53 2409.27 2.88 6044925.20 519136.54 N 70.53390918 W 149.84322819 11795.11 89.78 1.92 3864.85 3918.05 8484.61 9797.03 8781.61 8443.80 2412.26 0.31 6045021.46 519139.31 N 70.53417216 W 149.84320350 11889.21 89.50 1.73 3865.44 3918.64 8578.70 9891.13 8872.89 8537.85 2415.25 0.36 6045115.51 519142.09 N 70.53442909 W 149.84317870 11988.55 87.25 358.91 3868.26 3921.46 8677.97 9990.42 8968.62 8637.13 2415.81 3.63 6045214.78 519142.43 N 70.53470031 W 149.84317388 12084.50 87.33 359.04 3872.80 3926.00 8773.76 10086.27 9060.48 8732.96 2414.09 0.16 6045310.60 519140.49 N 70.53496210 W 149.84318767 12179.76 86.62 358.77 3877.83 3931.03 8868.82 10181.39 9151.71 8828.06 2412.28 0.80 6045405.69 519138.46 N 70.53522192 W 149.84320231 12275.82 89.10 0.20 3881.41 3934.61 8964.77 10277.38 9244.11 8924.04 2411.41 2.98 6045501.66 519137.38 N 70.53548412 W 149.84320911 Last survey 12324.11 90.14 0.72 3881.73 3934.93 9013.06 10325.67 9290.83 8972.33 2411.80 2.41 6045549.94 519137.66 N 70.53561603 W 149.84320581 TD (Projected) 12384.00 90.14 0.72 3881.59 3934.79 . 9072.94 10385.56 9348.87 9032.22 2412.56 0.00 6045609.82 • 519138.28 N 70.53577963 W 149.84319948 SurveyEditor Ver SP 2.1 Bid( doc40x_100 ) OP03\OP03-P05\OP03-P05\OP03-P05 Generated 1/15/2009 11:06 AM Page 4 of 5 Comments Measured Inclination Azimuth Sub�Sea TV ND Vertical Along Hureole Closure NS EW DLS Northing Easting Latitude Longitude Depth I I Section Depart I N deg de N N N N N N N) (delilloo NUS NUS Survey Type: Definitive Survey NOTES: NSG+SSHOT - ( NorthSeeking Gyro Singleshots -- Northseeking gyro in gyrocompassing or stationing mode with larger. misalignment errors as a result of landing in a UBHO sub. Not to be run above 70 degrees inclination. ) MWD+GMAG - ( MWD+ IFR+ SLB Multi -station correction + Sag correction -- Standard SLB MWD error model where the surveys have been geomagnetically reference (declination) corrected using a local crustal magnetic model and the SLB multistation drillstring magnetic interference correction GMAG (GeoMAGnetic Correction) under survey specialist supervision - and where the inclinations have then been corrected for BHA sag. Legal Description: Surface : 3220 FSL 1534 FEL S5 T13N R9E UM BHL : 1692 FSL 4373 FEL S28 T14N R9E UM Northing (Y) rftUS] Easting 1X1 fftUS] 6036573.11 516746.34. 6045609.82 519138.28. SurveyEditor Ver SP 2.1 Bid( doc40x_100 ) OP03\OP03-PO5\OP03-P05\OP03-PO5 Generated 1/15/2009 11:06 AM Page 5 of 5 JL En i Pelirolle ui nnn OP03-P05PB2 Su Client: ENI Field; Nikaimhuq Structure / Slot: Oliktok Point/ OP03 Well: OP03-PO5 Borehole: OP03-P05PB2 UWVAPIa: 500292339671 Survey Name / Date: OP03-P05PB2 / December 20, 2008 Tort / AND / DDI / ERD ratio: 258.641° / 8043.79 X / 6.734 / 2.088 Grid Coordinate System: NAD27 Alaska State Planes, Zone 04, US Feet Location LatlLong: N 70.51110601, W 149.86296360 Location Grid WE Y/R: N 6036573.11011US, E 516746.340 XUS Grid Convergence Angle: +0.129185091 Schlumberger Vertical Section Azimuth: 1.00W Vertical Section Origin: N 0.000 ft, E 0.000 X TO Reference Datum: Rotary Table TO Reference Elevation: 5320 X relative to MSL Sea Bad /Ground Level Elevation: 12.20 X relative to MSL Magnetic Declination: 22.442° Total Field Strength: 57668.808 nT Magnetic Dip: 80.930° Declination Date: December 19, 2008 Magnetic Declination Model: BGGM 2008 North Reference: True North Total Corr Mag North, True North: +22.442° Comments Measured Inclination Azimuth Subsea TO ND Section Depar�re Closure NS EW DLS Northing Basting Latitude W149.86296360 Depth 51.00 0.11 281.67 -2.20 51.00 0.01 0.05 0.05 0.01 I 0.22 6036573.12 516746.29 Longitude W 149.86296399 X de tt tt X h X tt X) (flegnow us XUS 6036573.14 516746.28 RTF nnn nnn nnn 111.00 0.17 94.73 57.80 111.00 0.04 0.13 0.04 0.04 0.00 0.44 6036573.15 --- --- U.W 0.00 O.W 60.6573.il 516/461» N/0.1110507 W149.86296360 NSG+SSHOT 51.00 0.11 281.67 -2.20 51.00 0.01 0.05 0.05 0.01 -0.05 0.22 6036573.12 516746.29 N 70.51110603 W 149.86296399 81.00 0.08 46.14 27.80 81.00 0.03 0.07 0.07 0.03 .0.06 0.56 6036573.14 516746.28 N 70.51110609 W 149.86296410 111.00 0.17 94.73 57.80 111.00 0.04 0.13 0.04 0.04 0.00 0.44 6036573.15 516746.34 N 70.51110612 W 149.86296361 141.00 0.17 134.04 87.80 141.00 0.01 0.22 0.08 0.01 0.07 0.38 6036573.12 516746.41 N 70.51110602 W 149.86296299 179.00 0.19 158.18 125.80 179.00 -0.09 0.34 0.17 -0.09 0.14 0.20 6036573.02 516746.48 N 70.51110576 W 149.86296246 241.00 0.15 161.26 187.80 241.00 -0.26 0.52 0.33 -0.26 0.20 0.07 6036572.85 516746.54 N 70.51110529 W 149.86296194 302.00 0.35 89.34 248.80 302.00 -0.33 0.76 0.53 -0.34 0.41 0.55 6036572.77 516746.76 N 70.51110509 W 149.86296020 333.00 0.71 69.17 279.80 333.00 -0.26 1.04 0.74 -0.27 0.69 1.29 6036572.84 516747.03 N 70.51110528 W 149.86295796 364.00 1.03 56.86 310.79 363.99 -0.03 1.51 1.10 -0.05 1.10 1.19 6036573.07 516747.44 N 70.51110588 W 149.86295458 394.00 1.39 55.11 340.79 393.99 0.34 2.14 1.66 0.31 1.63 1.21 6036573.42 516747.97 N 70.51110685 W 149.86295029 425.00 1.69 48.87 371.78 424.98 0.86 2.98 2.42 0.82 2.28 1.11 6036573.94 516748.62 N 70.51110826 W 149.86294 •QS 456.00 2.08 47.70 402.76 455.96 1.56 3.99 3.39 1.50 3.04 1.26 6036574.62 516749.38 N 70.51111011 W 149.8629 487.00 3.09 33.86 433.73 486.93 2.64 5.39 4.69 2.58 3.92 3.81 6036575.69 516750.25 N 70.51111304 W 149.86293152 520.00 3.82 30.92 466.67 519.87 4.34 7.37 6.55 4.26 4.98 2.28 6036577.38 516751.31 N 70.51111764 W 149.86292284 550.00 4.92 29.25 496.58 549.78 6.34 9.66 8.74 6.24 6.12 3.69 6036579.36 516752.45 N 70.51112305 W 149.86291349 593.00 5.45 28.94 539.40 592.60 9.77 13.55 12.53 9.63 8.01 1.23 6036582.76 516754.33 N 70.51113232 W 149.86289804 Last Gyro 643.00 6.60 27.70 589.13 642.33 14.44 18.79 17.70 14.26 10.50 2.31 6036587.39 516756.80 N 70.51114495 W 149.86287771 MWD+GMAG 675.74 6.75 27.81 621.64 674.84 17.83 22.60 21.47 17.62 12.27 0.46 6036590.76 516758.57 N 70.51115415 W 149.86286320 768.13 826 28.84 713.24 766.44 26.55 34.67 33.49 28.24 16.00 1.64 6036601.39 516764.28 N 70.51118315 W 149.86281628 863.79 9.86 30.84 807.70 860.90 41.73 49.73 48.54 41.29 25.52 1.70 6036614.46 516771.76 N 70.51121881 W 149.86275480 959.39 13.95 30.83 901.23 954.43 58.84 69.45 68.26 58.22 35.62 4.28 6036631.41 516781.83 N 70.51126506 W 149.86267211 1055.45 13.29 37.29 994.59 1047.79 77.78 92.04 90.83 76.95 48.25 1.73 6036650.16 516794.41 N 70.51131622 W 149.86256881 SurveyEditor Ver SP 2.1 Bid( doc40x_100 ) OP03\OP03-PO5\OP03-PO5PB2\OP03-PO5PS2 Generated 12/29/2008 4:23 PM Page 1 of 4 Comments Measured Inclination Azimuth Sub -Sea TO TVVertical 11/.33 Along Hole Closure NS EW DLS Northing Fasting Letitutle Longitutle 1247.26 Depth 53.28 1177.85 1231.05 116.62 Section Departure I I 89.30 4.05 6036688.38 516835.37 N 70.51142039 W 149.86223291 1342.33 X tle tle tt k IN n tt k X SDk flus NUS N 70.51147393 W 149.86199918 SurveyEditor Ver SP 2.1 Bld( doc40x_700) OP03\OP03-P05\OP03-P05PB2\OP03-P05PB2 Generated 12/29/2008 4:23 PM Page 2 of 4 .08/.52 1 .40. 72 96.5 11/.33 1 IJJJ 95.40 0145 4.90 6036668.69 5i 66i 1.D/ N 70.S11360/S W 149.88242807 1247.26 20.58 53.28 1177.85 1231.05 116.62 148.24 145.66 115.08 89.30 4.05 6036688.38 516835.37 N 70.51142039 W 149.86223291 1342.33 22.19 57.65 1266.38 1319.58 136.72 182.89 178.97 134.68 117.86 2.38 6036708.04 516863.89 N 70.51147393 W 149.86199918 1439.00 24.00 59.30 1355.30 1408.50 157.08 220.80 215.46 154.49 150.19 1.99 6036727.92 516896.17 N 70.51152804 W 149.86173465 1485.63 24.31 59.06 1397.84 1451.04 167.14 239.89 233.95 164.26 166.58 0.70 6036737.73 516912.53 N 70.51155474 W 149.86160057 1532.89 24.77 59.66 1440.83 1494.03 177.44 259.51 253.04 174.27 183.47 1.11 6036747.77 516929.40 N 70.51158207 W 149.86146238 1628.19 24.76 60.43 1527.37 1580.57 197.97 299.43 292.00 194.20 218.06 0.34 6036767.78 516963.94 N 70.51163652 W 149.86117937 1723.85 26.67 62.34 1613.55 1666.75 218.46 340.94 332.55 214.05 254.50 2.18 6036787.71 517000.33 N 70.51169075 W 149.86088118 1820.50 29.22 62.28 1698.93 1752.13 240.20 386.22 376.91 235.10 294.60 2.64 6036808.85 517040.38 N 70.51174825 W 149.86055304 1915.77 32.88 62.44 1780.53 1833.73 263.75 435.35 425.25 257.89 338.13 3.84 6036831.73 517083.85 N 70.51181050 W 149.86019688 2011.43 36.93 62.27 1858.97 1912.17 289.99 490.08 479.28 283.28 386.60 4.23 6036857.24 517132.26 N 70.51187987 W 149.85980021 2107.31 42.53 63.06 1932.68 1985.88 319.04 551.34 539.88 311.39 441.03 5.86 6036885.46 517186.62 N 70.51195665 W 149.8593541$2 2202.72 44.14 64.83 2002.07 2055.27 348.81 616.81 604.60 340.13 499.85 2.11 6036914.34 517245.37 N 70.51203516 W 149.8588,...9 2289.22 46.70 67.27 2062.79 2115.99 374.76 678.41 665.30 365.11 556.16 3.58 6036939.44 517301.62 N 70.51210338 W 149.85841275 13-3/8" @ 2351'md 2416.08 49.99 67.89 2147.09 2200.29 412.42 773.19 758.58 401.24 643.77 2.62 6036975.76 517389.14 N 70.51220207 W 149.85769583 2512.29 52.61 70.38 2207.25 2260.45 440.35 848.26 832.37 427.95 713.93 3.39 6037002.63 517459.23 N 70.51227502 W 149.85712174 2607.91 54.14 71.93 2264.29 2317.49 466.39 925.00 907.54 452.73 786.55 2.06 6037027.57 517531.79 N 70.51234269 W 149.85652746 2703.27 59.45 73.10 2316.50 2369.70 491.65 1004.76 985.57 476.67 862.63 5.66 6037051.68 517607.81 N 70.51240806 W 149.85590489 2799.58 61.55 74.35 2363.92 2417.12 516.53 1088.57 1067.51 500.15 943.09 2.46 6037075.33 517688.21 N 70.51247218 W 149.85524648 2894.25 65.66 73.35 2406.00 2459.20 541.55 1173.36 1150.63 523.75 1024.53 4.44 6037099.11 517769.58 N 70.51253661 W 149.85458011 2990.61 67.91 73.03 2443.98 2497.18 568.63 1261.91 1237.87 549.36 1109.29 2.35 6037124.91 517854.28 N 70.51260654 W 149.85388644 3086.28 67.62 72.12 2480.18 2533.38 596.62 1350.46 1325.42 575.87 1193.78 0.93 6037151.62 517938.70 N 70.51267895 W 149.85319503 3181.28 67.80 72.25 2516.22 2569.42 624.97 1438.37 1412.54 602.77 1277.47 0.23 6037178.69 518022.32 N 70.51275238 W 149.85251020 3276.99 67.63 70.31 2552.51 2605.71 654.85 1526.93 1500.55 631.19 1361.34 1.88 6037207.30 518106.12 N 70.51282998 W 149.85182385 3373.28 67.47 67.26 2589.29 2642.49 688.49 1615.91 1589.36 663.38 1444.29 2.93 6037239.68 518188.98 N 70.51291790 W 149.85114503 3469.07 66.53 65.02 2626.72 2679.92 725.55 1704.09 1677.52 699.04 1524.92 2.37 6037275.52 518269.53 N 70.51301527 W 149.85048515 3564.54 66.33 63.39 2664.90 2718.10 764.99 1791.59 1765.00 737.12 1603.71 1.58 6037313.77 518348.22 N 70.51311924 W 149.84984040 3661.47 64.98 58.37 2704.88 2758.08 809.27 1879.89 1853.02 780.06 1680.83 4.92 6037356.87 518425.24 N 70.51323649 W 149.84920921 3757.78 63.04 52.93 2747.11 2800.31 859.30 1966.44 1938.42 828.85 1752.28 5.46 6037405.82 518496.57 N 70.51336974 W 149.84862443 3653.53 63.58 49.59 2790.12 2843.32 913.99 2051.99 2021.71 882.38 1818.99 3.17 6037459.50 518563.15 N 70.51351593 W 149.8480' 3950.54 63.41 46.87 2833.42 2886.62 972.93 2138.80 2105.33 940.20 1883.73 2.52 6037517.46 518627.76 N 70.51367384 W 149.8475- 49.84754046.70 4046.70 62.46 43.33 2877.19 2930.39 1034.40 2224.42 2186.75 1000.62 1944.38 3.42 6037578.01 518688.26 N 70.51383886 W 149.84705209 4141.64 62.01 40.30 2921.42 2974.62 1097.97 2308.42 2265.39 1063.22 2000.39 2.86 6037640.73 518744.12 N 70.51400983 W 149.84659364 4236.81 62.15 37.36 2965.99 3019.19 1164.38 2392.51 2342.91 1128.72 2053.10 2.73 6037706.34 518796.69 N 70.51418873 W 149.84616209 4330.40 62.49 34.16 3009.48 3062.68 1232.46 2475.39 2418.00 1195.96 2101.53 3.05 6037773.68 518844.95 N 70.51437239 W 149.84576567 4427.15 62.75 31.02 3053.98 3107.18 1305.62 2561.29 2494.33 1268.33 2147.79 2.89 6037846.15 518891.05 N 70.51457007 W 149.84538690 4523.33 62.48 27.20 3098.23 3151.43 1380.93 2646.69 2568.39 1342.93 2189.33 3.54 6037920.83 518932.41 N 70.51477381 W 149.84504678 4618.58 62.22 24.86 3142.44 3195.64 1457.37 2731.06 2639.97 1418.73 2226.35 2.19 6037996.71 518969.26 N 70.51498087 W 149.84474360 4714.49 61.60 23.50 3187.60 3240.80 1535.15 2815.67 2711.08 1495.92 2261.01 1.41 6038073.97 519003.74 N 70.51519170 W 149.84445977 4811.08 61.02 22.60 3233.97 3287.17 1613.68 2900.40 2782.16 1573.88 2294.19 1.01 6038152.00 519036.74 N 70.51540466 W 149.84418806 4907.50 62.79 20.67 3279.38 3332.58 1693.28 2985.46 2853.13 1652.94 2325.53 2.55 6038231.12 519067.90 N 70.51562062 W 149.84393132 SurveyEditor Ver SP 2.1 Bld( doc40x_700) OP03\OP03-P05\OP03-P05PB2\OP03-P05PB2 Generated 12/29/2008 4:23 PM Page 2 of 4 Comments ------ -- •- •- ....-. •3 hkssured Inclination Aamuth Sul -Sea ND TO genial Along Hole Closure NS EW DIS Northing Easting Latitude 5099.36 Depth 13.28 3360.94 3414.14 1860.34 Section Depanure 1819.17 2375.28 3.20 6038397.44 519117.27 N 70.51607468 W 149.84352377 Te -In Survey Lon itude !n 67.79 tt tle de X tt tt X X ft N tle DDtt flOS XUS 5259.92 68.26 9.73 5002 C9 e5 ii 15 no 3321. 3104.48 1964.64 2403.75 1.10 6038542.96 519145.41 N70.51647205 W149.84329040 5319.20 67.13 9.62 SurveyEditor Ver SP 2.1 Bid( doc40x_100 ) OP03\OP03-P05\OP03-P05P82\OP03-P05PB2 Generated 12/29/2008 4:23 PM Page 3 of 4 ....•-..... 11 v.,, v. v. 1;. .vi 2352.70 v✓u 60363i2.24 51WE4.6F! N Mbib64206 W 149.84370876 5099.36 66.29 13.28 3360.94 3414.14 1860.34 3159.08 2991.88 1819.17 2375.28 3.20 6038397.44 519117.27 N 70.51607468 W 149.84352377 Te -In Survey 5195.77 67.79 10.30 3398.56 3451.76 1947.53 3247.85 3059.64 1906.05 2393.40 3.24 6038464.36 519135.20 N 70.51631202 W 149.84337522 MWD+GMAG 5259.92 68.26 9.73 3422.56 3475.76 2006.29 3307.34 3104.48 1964.64 2403.75 1.10 6038542.96 519145.41 N70.51647205 W149.84329040 5319.20 67.13 9.62 3445.06 3498.26 2060.51 3362.18 3146.04 2018.70 2412.96 1.91 6038597.04 519154.50 N 70.51661974 W 149.84321482 5362.87 65.95 10.13 3462.44 3515.64 2100.08 3402.24 3176.73 2058.17 2419.83 2.91 6038636.52 519161.28 N 70.51672755 W 149.84315849 5397.42 66.32 9.51 3476.42 3529.62 2131.31 3433.84 3201.07 2089.30 2425.22 1.96 6038667.66 519166.60 N 70.51681259 W 149.84311430 5428.29 67.74 8.62 3488.47 3541.67 2159.45 3462.26 3222.84 2117.37 2429.70 5.31 6038695.73 519171.01 N 70.51688926 W 149.84307759 5458.27 69.15 8.16 3499.48 3552.68 2187.10 3490.14 3244.08 2144.95 2433.77 4.91 6038723.32 519175.02 N 70.51696461 W 149.84304422 5492.34 69.91 7.49 3511.40 3564.60 2218.79 3522.06 3268.31 2176.57 2438.11 2.89 6038754.95 519179.29 N 70.51705099 W 149.84300857 5523.36 70.57 6.02 3521.89 3575.09 2247.84 3551.25 3290.23 2205.56 2441.54 4.94 6038783.94 519182.66 N 70.51713019 W 149.84298040 5553.27 71.67 4.47 3531.57 3584.77 2276.06 3579.55 3311.10 2233.74 2444.13 6.13 6038812.13 519185.18 N 70.51720717 W 149.842£ 5648.64 72.62 359.10 3560.83 3614.03 2366.79 3670.32 3374.99 2324.43 2446.95 5.45 6038902.82 519187.79 N 70.51745493 W 149.8429a..,.d 5743.84 74.01 358.28 3588.16 3641.36 2457.90 3761.51 3436.92 2415.60 2444.86 1.68 6038993.97 519185.50 N 70.51770398 W 149.84295271 5838.96 77.52 358.97 3611.54 3664.74 2550.00 3853.70 3500.77 2507.76 2442.65 3.76 6039086.11 519183.08 N 70.51795574 W 149.84297053 5935.30 81.51 358.20 3629.07 3682.27 2644.63 3948.41 3567.60 2602.44 2440.31 4.22 6039180.78 519180.53 N 70.51821440 W 149.84298946 9-5(8" @ 5960'md 6055.77 84.01 0.25 3644.26 3697.46 2764.07 4067.91 3654.60 2721.92 2438.70 2.67 6039300.25 519178.65 N 70.51854081 W 149.84300231 6151.80 86.99 0.15 3651.79 3704.99 2859.78 4163.63 3726.66 2817.64 2439.03 3.10 6039395.96 519178.76 N 70.51880231 W 149.84299932 6248.10 86.67 359.67 3657.11 3710.31 2955.92 4259.78 3799.78 2913.80 2438.88 0.60 6039492.10 519178.40 N 70.51906499 W 149.84300030 6343.73 90.53 359.96 3659.45 3712.65 3051.48 4355.37 3873.37 3009.38 2438.57 4.05 6039587.67 519177.87 N 70.51932611 W 149.84300257 6439.16 91.49 359.72 3657.77 3710.97 3146.87 4450.78 3947.79 3104.79 2438.31 1.04 6039683.08 519177.39 N 70.51958676 W 149.84300449 6533.16 89.52 357.82 3656.94 3710.14 3240.79 4544.77 4020.89 3198.76 2436.29 2.91 6039777.03 519175.16 N 70.51984346 W 149.84302076 6630.79 87.79 356.33 3659.23 3712.43 3338.16 4642.37 4095.90 3296.23 2431.31 2.34 6039874.48 519169.96 N 70.52010974 W 149.84306126 6723.70 87.30 355.14 3663.21 3716.41 3430.59 4735.20 4166.73 3388.79 2424.40 1.38 6039967.02 519162.85 N 70.52036262 W 149.84311752 6819.79 87.59 355.13 3667.50 3720.70 3526.08 4831.19 4240.24 3484.44 2416.26 0.30 6040062.64 519154.50 N 70.52062393 W 149.84318391 6914.93 89.33 355.96 3670.05 3723.25 3620.75 4926.29 4314.37 3579.26 2408.88 2.03 6040157.42 519146.90 N 70.52088295 W 149.64324412 7012.37 88.48 355.34 3671.91 3725.11 3717.75 5023.72 4391.25 3676.40 2401.49 1.08 6040254.54 519139.29 N 70.52114833 W 149.84330435 7107.59 88.73 354.72 3674.23 3727.43 3812.42 5118.91 4466.52 3771.23 2393.24 0.70 6040349.34 519130.83 N 70.52140741 W 149.84337162 7203.60 86.67 355.78 3678.09 3731.29 3907.87 5214.83 4543.35 3866.83 2385.30 2.41 6040444.91 519122.67 N 70.52166857 W 149.84343640 7299.18 86.32 359.04 3683.93 3737.13 4003.07 5310.24 4622.50 3962.12 2380.99 3.42 6040540.18 519118.15 N 70.52192890 W 149.8434" ^' 7394.65 83.03 359.04 3692.79 3745.99 4098.06 5405.28 4703.40 4057.15 2379.39 3.45 6040635.20 519116.34 N 70.52218851 W 149.8434. ., 7490.89 83.03 359.74 3704.47 3757.67 4193.55 5500.81 4785.54 4152.67 2378.38 0.72 6040730.71 519115.11 N 70.52244947 W 149.84349230 7585.93 85.84 4.22 3713.69 3766.89 4288.09 5595.39 4869.37 4247.17 2381.65 5.55 6040825.21 519118.17 N 70.52270763 W 149.84346523 7681.64 88.22 7.00 3718.65 3771.85 4383.35 5690.97 4957.04 4342.28 2391.00 3.82 6040920.33 519127.30 N 70.52296744 W 149.84338848 7778.26 85.12 5.93 3724.26 3777.46 4479.35 5787.41 5046.36 4438.11 2401.86 3.39 6041016.17 519137.94 N 70.52322922 W 149.84329931 7875.15 80.92 3.46 3736.03 3789.23 4575.29 5883.56 5134.52 4533.93 2409.74 5.02 6041112.00 519145.60 N 70.52349098 W 149.84323455 7971.89 79.59 2.36 3752.41 3805.61 4670.58 5978.90 5221.03 4629.15 2414.58 1.77 6041207.22 519150.23 N 70.52375110 W 149.84319465 8067.01 80.49 2.69 3768.86 3822.06 4764.23 6072.59 5306.07 4722.74 2418.71 1.01 6041300.81 519154.15 N 70.52400678 W 149.84316061 8162.64 84.41 4.13 3781.42 3834.62 4858.93 6167.37 5392.99 4817.35 2424.35 4.36 6041395.43 519159.58 N 70.52426524 W 149.84311416 8257.68 87.96 5.52 3787.75 3840.95 4953.53 6262.18 5481.08 4911.83 2432.33 4.01 6041489.91 519167.34 N 70.52452333 W 149.84304859 8354.01 91.07 6.11 3788.56 3841.76 5049.50 6358.50 5571.38 5007.65 2442.08 3.29 6041585.74 519176.88 N 70.52478508 W 149.84296843 SurveyEditor Ver SP 2.1 Bid( doc40x_100 ) OP03\OP03-P05\OP03-P05P82\OP03-P05PB2 Generated 12/29/2008 4:23 PM Page 3 of 4 Comments Measured Inclination Azimuth Sub -Sea ND TVD Verti6al Along Hole Closure NS EW DLS Northing Fasting Latitutle Longitude W 149.84289704 Depth 87.16 2.26 3792.16 3845.36 Section I Departure 6549.00 5748.77 5197.58 2456.34 2.78 6041775.68 519190.71 N 70.52530392 tt tle de X tt tt X X h X de ooftthus) M)S 2.39 6041869.86 8448.79 88.73 4.41 3788.73 3841.93 5144.01 6453.27 5660.11 5102.02 2450.77 3.05 6041680.12 519185.35 N 70.52504288 W 149.84289704 8544.58 87.16 2.26 3792.16 3845.36 5239.65 6549.00 5748.77 5197.58 2456.34 2.78 6041775.68 519190.71 N 70.52530392 W 149.84285118 8638.88 87.90 0.13 3796.23 3849.43 5333.86 6643.21 5834.90 5291.76 2458.31 2.39 6041869.86 519192.46 N 70.52556122 W 149.84283484 8734.36 89.26 1.19 3798.59 3851.79 5429.30 6738.66 5922.05 5387.20 2459.41 1.81 6041965.30 519193.34 N 70.52582195 W 149.84282558 8829.33 89.90 1.58 3799.29 3852.49 5524.27 6833.63 6009.48 5482.14 2461.70 0.79 6042060.23 519195.43 N 70.52608131 W 149.84280653 8926.31 90.95 1.02 3798.57 3851.77 5621.24 6930.60 6098.94 5579.09 2463.90 1.23 6042157.18 519197.41 N 70.52634616 W 149.84278825 9021.61 89.82 359.40 3797.93 3851.13 5716.53 7025.90 6186.37 5674.38 2464.25 2.07 6042252.46 519197.54 N 70.52660649 W 149.84278513 9117.42 89.45 359.35 3798.54 3851.74 5812.30 7121.71 6273.95 5770.19 2463.21 0.39 6042348.25 519196.28 N 70.52686821 W 149.84279343 9214.09 91.39 359.66 3797.83 3851.03 5908.93 7218.37 6362.64 5866.85 2462.37 2.03 6042444.90 519195.23 N 70.52713227 W 149.84280000 9308.19 93.70 358.66 3793.65 3846.85 6002.88 7312.37 6448.88 5960.83 2460.99 2.67 6042538.87 519193.64 N 70.52738903 W 149.84281102 9405.03 92.25 356.33 3788.63 3841.83 6099.40 7409.08 6536.69 6057.44 2456.77 2.83 6042635.46 519189.19 N 70.52765295 W 149.84284538 9499.37 92.47 357.34 3784.74 3837.94 6193.41 7503.34 6622.07 6151.56 2451.56 1.09 6042729.55 519183.78 N 70.52791007 W 149.842£ 9594.12 88.28 355.83 3784.12 3837.32 6287.85 7598.06 6707.94 6246.11 2445.92 4.70 6042824.09 519177.92 N 70.52816838 W 149.8429, J 9690.65 88.62 355.38 3786.73 3839.93 6383.92 7694.56 6794.96 6342.32 2438.52 0.58 6042920.27 519170.31 N 70.52843122 W 149.84299399 9785.25 89.84 354.63 3788.00 3841.20 6477.99 7789.15 6880.08 6436.55 2430.29 1.51 6043014.47 519161.86 N 70.52868865 W 149.84306119 9881.23 90.42 357.22 3787.79 3840.99 6573.58 7885.13 6967.35 6532.28 2423.47 2.77 6043110.18 519154.83 N 70.52895018 W 149.84311678 Last Survey 9980.36 92.61 358.88 3785.16 3838.36 6672.54 7984.22 7059.12 6631.31 2420.10 2.77 6043209.19 519151.23 N 70.52922071 W 149.84314413 TD (Projected) 10040.00 92.61 358.88 3782.45 3835.65 6732.07 8043.79 7114.71 6690.88 2418.93 0.00 6043268.74 519149.93 N 70.52938344 W 149.84315351 Survey Type: Definitive Survey NOTES: NSG+SSHOT - (NorlhSeeking Gyro Singleshots -- Northseeking gyro in gyrocompassing or stationing mode with larger. misalignment errors as a result of landing in a UBHO sub. Not to be run above 70 degrees inclination. ) MWD+GMAG - (MWD + IFR + SLB Multi -station correction + Sag cortection - Standard SLB MWD error model where the surveys have been geomagnetically reference (declination) corrected using a local crustal magnetic model and the SLB multistation drillstring magnetic interference correction GMAG (GwMAGnetic Correction) under survey specialist supervision - and where the inclinations have then been corrected for BHA sag. Legal Description: Northing tYt fftUSI Fasting W fftUS1 Surface: 3220 FSL 1534 FEL S5 T73N R9E UM 6036573.11 516746.34 BHL : 4630 FSL 4374 FEL S33 T14N R9E UM 6043268.74 519149.93 SurveyEditor Ver SP 2.1 Bid( doc40x_100) OP03\OP03-P05\OP03-P05PB2\OP03-P05PB2 Generated 12/29/2008 4:23 PM Page 4 of 4 E s� nli Pairdeulf��l OP03-P05PB1 S Client: ENI Field: Nikaftchuq Structure / Slot: Oliklok Point / OP03 Well: OP03-P05 Borehole: OP03-P05PBt U WIIAPIB: 500292339670 Survey Name / Date: OP03-P05PB1 / December 03, 2008 Ton / AND / DDI / ERD ratio: 145.055° 14032.09 It / 5.971 / 1.067 Grid Coordinate System: NAD27 Alaska State Planes, Zone 04, US Feet Location Lztli-ong: N 70.51110601, W 149.66296360 Location Grid WE Y!%: N 6036573.110 ftUS, E 516746.340 ftUS Grid Convergence Angle: +0.12918509° Comments Schlumberger Vertical Section Azimuth: 1.000° Vertical Section Origin: N 0.000 ft, E 0.000 ft TVD Reference Datum: Rotary Table TO Reference Elevation: 53.20 ft relative to MSL Sea Bed/ Ground Level Elevation: 12.20 ft relative to MSL Magnetic Declination: 22.488° Total Field Strength: 57665.071 nT Magnetic Up: 80.930° Declination Data: November 15, 2008 Magnetic Declination Model: BGGM 2008 North Reference: Tflle North Total Corr Mag North -> True North: +22.488° assured Vertical Along Hole Depth Inclination Azimuth Sub -So ND ND Secilun Departure Closure NS EW NSG+SSHOT 51.00 0.11 281.67 -2.20 51.00 0.01 0.05 0.05 0.01 -0.05 81.00 0.08 46.14 27.80 81.00 0.03 0.07 0.07 0.03 -0.06 111.00 0.17 94.73 57.80 111.00 0.04 0.13 0.04 0.04 0.00 141.00 0.17 134.04 87.80 141.00 0.01 0.22 0.08 0.01 0.07 179.00 0.19 158.18 125.80 179.00 -0.09 0.34 0.17 -0.09 0.14 241.00 0.15 161.26 187.80 241.00 -0.26 0.52 0.33 -0.26 0.20 302.00 0.35 89.34 248.80 302.00 -0.33 0.76 0.53 -0.34 0.41 333.00 0.71 69.17 279.80 333.00 -0.26 1.04 0.74 -0.27 0.69 364.00 1.03 56.86 310.79 363.99 -0.03 1.51 1.10 -0.05 1.10 394.00 1.39 55.11 340.79 393.99 0.34 2.14 1.66 0.31 1.63 425.00 1.69 48.87 371.78 424.98 0.86 2.98 2.42 0.82 2.28 456.00 2.08 47.70 402.76 455.96 1.56 3.99 3.39 1.50 3.04 487.00 3.09 33.86 433.73 486.93 2.64 5.39 4.69 2.58 3.92 520.00 3.82 30.92 466.67 519.87 4.34 7.37 6.55 4.26 4.98 550.00 4.92 29.25 496.58 549.78 6.34 9.66 8.74 6.24 6.12 593.00 5.45 28.94 539.40 592.60 9.77 13.55 12.53 9.63 8.01 Last Gyro 643.00 6.60 27.70 589.13 642.33 14.44 18.79 17.70 14.26 10.50 MWD+GMAG 675.74 6.75 27.81 621.64 674.84 17.83 22.60 21.47 17.62 12.27 768.13 8.26 28.84 713.24 766.44 28.55 34.67 33.49 28.24 18.00 863.79 9.86 30.84 807.70 860.90 41.73 49.73 48.54 41.29 25.52 959.39 13.95 30.83 901.23 954.43 58.84 69.45 68.26 58.22 35.62 DLS I Northing 0.22 6036573.12 0.56 6036573.14 0.44 6036573.15 0.38 6036573.12 0.20 6036573.02 0.07 6036572.85 0.55 6036572.77 1.29 6036572.84 1.19 6036573.07 1.21 6036573.42 1.11 6036573.94 1.26 6036574.62 3.81 6036575.69 2.28 6036577.38 3.69 6036579.36 1.23 6036582.76 2.31 6036587.39 0.46 6036590.76 1.64 6036601.39 1.70 6036614.46 4.28 6036631.41 Fasting I Latilude I Longitude 516746.34 N 70.51110601 W 149.86296360 516746.29 N 70.51110603 W 149.86296399 516746.28 N 70.51110609 W 149.86296410 516746.34 N 70.51110612 W 149.86296361 516746.41 N 70.51110602 W 149.86296299 516746.48 N 70.51110576 W 149.86296246 516746.54 N 70.51110529 W 149.86296194 516746.76 N 70.51110509 W 149.86296020 516747.03 N 70.51110528 W 149.86295796 516747.44 N 70.51110588 W 149.86295458 516747.97 N 70.51110685 W 149.8629ry029 516748.62 N 70.51110826 W 149.8E 95 516749.38 N 70.51111011 W 149.86eeo873 516750.25 N 70.51111304 W 149.86293152 516751.31 N 70.51111764 W 149.86292284 516752.45 N 70.51112305 W 149.86291349 516754.33 N 70.51113232 W 149.86289804 516756.80 N 70.51114495 W 149.86287771 516758.57 N 70.51115415 W 149.86286320 516764.28 N 70.51118315 W 149.86281628 516771.76 N 70.51121881 W 149.86275480 516781.83 N 70.51126506 W 149.86267211 SuweyEdilor Ver SP 2.1 Bld(doc40x_100) OP03\OP03-POS\OP03-P05PB7\OP03-P05PB1 Generated 12/29/2008 4:22 PM Page 1 of 3 Comments nteasuretl Depth (N) Inclination (deal Azimuth deal Subsea TVD INI TO INI Vertical Section (ft) Along Hole Departure (It) Closure I (ft) NS I (N) EW (ft) DLS degilDON) Northing (NOS) Fasting (Nus) latitude Longitude 1055.45 13.29 37.29 994.59 1047.79 77.78 92.04 90.83 76.95 48.25 1.73 6036650.16 516794.41 N 70.51131622 W 149.86256881 1151.78 17.23 47.29 1087.52 1140.72 96.57 117.33 115.73 95.45 65.45 4.90 6036668.69 516811.57 N 70.51136675 W 149.86242807 1247.26 20.58 53.28 1177.85 1231.05 116.62 148.24 145.66 115.08 89.30 4.05 6036688.38 516835.37 N 70.51142039 W 149.86223291 1342.33 22.19 57.65 1266.38 1319.58 136.72 182.89 178.97 134.68 117.86 2.38 6036708.04 516863.89 N 70.51147393 W 149.86199918 1439.00 24.00 59.30 1355.30 1408.50 157.08 220.80 215.46 154.49 150.19 1.99 6036727.92 516896.17 N 70.51152804 W 149.86173465 1485.63 24.31 59.06 1397.84 1451.04 167.14 239.89 233.95 164.26 166.58 0.70 6036737.73 516912.53 N 70.51155474 W 149.86160057 1532.89 24.77 59.66 1440.83 1494.03 177.44 259.51 253.04 174.27 183.47 1.11 6036747.77 516929.40 N 70.51158207 W 149.86146238 1628.19 24.76 60.43 1527.37 1580.57 197.97 299.43 292.00 194.20 218.06 0.34 6036767.78 516963.94 N 70.51163652 W 149.86117937 1723.85 26.67 62.34 1613.55 1666.75 218.46 340.94 332.55 214.05 254.50 2.18 6036787.71 517000.33 N 70.51169075 W 149.86088118 1820.50 29.22 62.28 1698.93 1752.13 240.20 386.22 376.91 235.10 294.60 2.64 6036808.85 517040.38 N 70.51174825 W 149.86055304 1915.77 32.88 62.44 1780.53 1833.73 263.75 435.35 425.25 257.89 338.13 3.84 6036831.73 517083.85 N 70.51181050 W 149.86019688 2011.43 36.93 62.27 1858.97 1912.17 289.99 490.08 479.28 283.28 386.60 4.23 6036857.24 517132.26 N 70.51187987 W 149.859P1021 2107.31 42.53 63.06 1932.68 1985.88 319.04 551.34 539.88 311.39 441.03 5.86 6036885.46 517186.62 N 70.51195665 W 149.8' '82 2202.72 44.14 64.83 2002.07 2055.27 348.81 616.81 604.60 340.13 499.85 2.11 6036914.34 517245.37 N 70.51203516 W 149.85887349 2289.22 46.70 67.27 2062.79 2115.99 374.76 678.41 665.30 365.11 556.16 3.58 6036939.44 517301.62 N 70.51210338 W 149.85841275 13-3/8" @ 2351'md 2416.08 49.99 67.89 2147.09 2200.29 412.42 773.19 758.58 401.24 643.77 2.62 6036975.76 517389.14 N 70.51220207 W 149.85769583 2512.29 52.61 70.38 2207.25 2260.45 440.35 848.26 832.37 427.95 713.93 3.39 6037002.63 517459.23 N 70.51227502 W 149.85712174 2607.91 54.14 71.93 2264.29 2317.49 466.39 925.00 907.54 452.73 786.55 2.06 6037027.57 517531.79 N 70.51234269 W 149.85652746 2703.27 59.45 73.10 2316.50 2369.70 491.65 1004.76 985.57 476.67 862.63 5.66 6037051.68 517607.81 N 70.51240806 W 149.85590489 2799.58 61.55 74.35 2363.92 2417.12 516.53 1088.57 1067.51 500.15 943.09 2.46 6037075.33 517688.21 N 70.51247218 W 149.85524648 2894.25 65.66 73.35 2406.00 2459.20 541.55 1173.36 1150.63 523.75 1024.53 4.44 6037099.11 517769.58 N 70.51253661 W 149.85458011 2990.61 67.91 73.03 2443.98 2497.18 568.63 1261.91 1237.87 549.36 1109.29 2.35 6037124.91 517854.28 N 70.51260654 W 149.85388644 3086.28 67.62 72.12 2480.18 2533.38 596.62 1350.46 1325.42 575.87 1193.78 0.93 6037151.62 517938.70 N 70.51267895 W 149.85319503 3181.28 67.80 72.25 2516.22 2569.42 624.97 1438.37 1412.54 602.77 1277.47 0.23 6037178.69 518022.32 N 70.51275238 W 149.85251020 3276.99 67.63 70.31 2552.51 2605.71 654.85 1526.93 1500.55 631.19 1361.34 1.88 6037207.30 518106.12 N 70.51282998 W 149.85182385 3373.28 67.47 67.26 2589.29 2642.49 688.49 1615.91 1589.36 663.38 1444.29 2.93 6037239.68 518188.98 N 70.51291790 W 149.85114503 3469.07 66.53 65.02 2626.72 2679.92 725.55 1704.09 1677.52 699.04 1524.92 2.37 6037275.52 518269.53 N 70.51301527 W 149.85048515 3564.54 66.33 63.39 2664.90 2718.10 764.99 1791.59 1765.00 737.12 1603.71 1.58 6037313.77 518348.22 N 70.51311924 W 149.84984040 3661.47 64.98 58.37 2704.88 2758.08 809.27 1879.89 1853.02 780.06 1680.83 4.92 6037356.87 518425.24 N 70.51323649 W 149.841-121 3757.78 63.04 52.93 2747.11 2800.31 859.30 1966.44 1938.42 828.85 1752.28 5.46 6037405.82 518496.57 N 70.51336974 W 149.84 43 3853.53 63.58 49.59 2790.12 2843.32 913.99 2051.99 2021.71 882.38 1818.99 3.17 6037459.50 518563.15 N 70.51351593 W 149.84807843 3950.54 63.41 46.87 2833.42 2886.62 972.93 2138.80 2105.33 940.20 1883.73 2.52 6037517.46 518627.76 N 70.51367384 W 149.84754852 4046.70 62.46 43.33 2877.19 2930.39 1034.40 2224.42 2186.75 1000.62 1944.38 3.42 6037578.01 518688.26 N 70.51383886 W 149.84705209 4141.64 62.01 40.30 2921.42 2974.62 1097.97 2308.42 2265.39 1063.22 2000.39 2.86 6037640.73 518744.12 N 70.51400983 W 149.84659364 4236.81 62.15 37.36 2965.99 3019.19 1164.38 2392.51 2342.91 1128.72 2053.10 2.73 6037706.34 518796.69 N 70.51418873 W 149.84616209 4330.40 62.49 34.16 3009.48 3062.68 1232.46 2475.39 2418.00 1195.96 2101.53 3.05 6037773.68 518844.95 N 70.51437239 W 149.84576567 4427.15 62.75 31.02 3053.98 3107.18 1305.62 2561.29 2494.33 1268.33 2147.79 2.89 6037846.15 518891.05 N 70.51457007 W 149.84538690 4523.33 62.48 27.20 3098.23 3151.43 1380.93 2646.69 2568.39 1342.93 2189.33 3.54 6037920.83 518932.41 N 70.51477381 W 149.84504678 4618.58 62.22 24.86 3142.44 3195.64 1457.37 2731.06 2639.97 1418.73 2226.35 2.19 6037996.71 518969.26 N 70.51498087 W 149.84474360 4714.49 61.60 23.50 3187.60 3240.80 1535.15 2815.67 2711.08 1495.92 2261.01 1.41 6038073.97 519003.74 N 70.51519170 W 149.84445977 SurveyEditor Ver SP 2.1 Bid( doc40x_700 ) OP03\OP03-P05\OP03-P05PB7\OP03-P05PB1 Generated 12/29/2008 4:22 PM Page 2 of 3 Comments Measures Inclinegon Azimuth Subsea ND ND Vertical Along Hole S Closure NS EW USNorthingFasting Latitude Longitude Depth Section Departure Iftl (deg) (deg) (ft) (ft) (ft) (ft) (ft) (ft) (it) (deal100ft) (DUs) (ftus) 4811.08 61.02 22.60 3233.97 3287.17 1613.68 2900.40 2782.16 1573.88 2294.19 1.01 6038152.00 519036.74 N 70.51540466 W 149.84418806 4907.50 62.79 20.67 3279.38 3332.58 1693.28 2985.46 2853.13 1652.94 2325.53 2.55 6038231.12 519067.90 N 70.51562062 W 149.84393132 5002.69 65.14 16.43 3321.18 3374.38 1774.81 3070.97 2922.67 1734.01 2352.70 4.70 6038312.24 519094.89 N 70.51584206 W 149.84370876 5099.36 66.29 13.28 3360.94 3414.14 1860.34 3159.08 2991.88 1819.17 2375.28 3.20 6038397.44 519117.27 N 70.51607468 W 149.84352377 5195.77 67.79 10.30 3398.56 3451.76 1947.53 3247.85 3059.64 1906.05 2393.40 3.24 6038484.36 519135.20 N 70.51631202 W 149.84337522 5290.95 68.39 8.67 3434.07 3487.27 2034.87 3336.15 3125.84 1993.15 2407.95 1.71 6038571.48 519149.55 N 70.51654994 W 149.84325592 5386.32 68.20 8.74 3469.34 3522.54 2122.68 3424.76 3192.56 2080.74 2421.36 0.21 6038659.09 519162.76 N 70.51678920 W 149.84314593 5481.89 68.67 9.93 3504.47 3557.67 2210.62 3513.64 3261.16 2168.44 2435.78 1.26 6038746.81 519176.98 N 70.51702878 W 149.84302769 5576.96 68.38 9.56 3539.28 3592.48 2298.06 3602.11 3330.77 2255.63 2450.75 0.47 6038834.03 519191.75 N 70.51726696 W 149.84290489 5671.97 67.90 8.47 3574.65 3627.85 2385.37 3690.29 3400.36 2342.72 2464.57 1.18 6038921.14 519205.37 N 70.51750486 W 149.84279155 5767.66 66.76 6.77 3611.54 3664.74 2473.08 3778.58 3469.58 2430.23 2476.28 2.03 6039008.67 519216.89 N 70.51774391 W 149.84269545 5864.40 66.07 5.78 3650.24 3703.44 2561.36 3867.24 3538.67 2518.35 2485.98 1.18 6039096.81 519226.38 N 70.51798465 W 149.849x'-+587 Last Survey 5959.79 65.83 5.07 3689.12 3742.32 2648.21 3954.35 3606.59 2605.07 2494.21 0.72 6039183.53 519234.42 N 70.51822155 W 149.85 22 TD ( Projected) 6045.00 65.83 5.07 3724.01 3777.21 2725.75 4032.09 3667.60 2682.51 2501.08 0.00 6039260.98 519241.11 N 70.51843308 W 149.84249178 Survey Type: Definitive Survey NOTES: NSG+SSHOT - (NorthSeeking Gyro Singleshots -- Northseeking gyro in gyrocompassing or stationing mode with larger. misalignment errors as a result of landing in a UBHO sub. Not to be run above 70 degrees inclination. ) MWD+GMAG - (MWD + IFR + SLB Multi -station correction + Sag correction -- Standard SLB MWD error model where the surveys have been geomagnetically reference (declination) corrected using a local crustal magnetic model and the SLB multistation drillstring magnetic interference correction GMAG (GeoMAGnetic Correction) under survey specialist supervision - and where the inclinations have then been corrected for BHA sag. Legal Description: Northing (Y) fftUSl Eastinct (X) INS] Surface : 3220 FSL 1534 FEL S5 T13N R9E UM 6036573.11 516746.34 BHL : 622 FSL 4304 FEL S33 T14N R9E UM 6039260.98 519241.11 SurveyEditor Ver SP 2.1 Bid( doc40x_100) OP03\OP03-PO5\OP03-P05PB7\OP03-P05PB1 Generated 12/29/2008 4:22 PM Page 3 of 3 Eni End Pell�raleuinn Schlumberger 0P03-P05 Survev Report Report Date: December 22, 2008 Survey / DLS Computation Method: Minimum Curvature / Lubinski Client: ENI Vertical Section Azimuth: 1.000° Field: Nikakchuq Vertical Section Origin: N 0.000 ft, E 0.000 tt Structure/Slot: Oliktok Point /OP03 ND Reference Datum: Rotary Table Well: OP03-P05 ND Reference Elevation: 53.20 N relative to MSL Borehole: OP03-P05 Sea Bed/ Ground Level Elevation: 12.20 ft relative to MSL UWYAPI#: 500292339600 Magnetic Declination: 22.447° Survey Name/ Date: OP03-P05 / December 22, 2008 Total Field Strength: 57668.368 nT Tort / AND / DDI / ERD ratio: 294.073° / 10385.56 ft / 6.983 12.639 Magnetic Dip: 80.930° Grid Coordinate System: NAD27 Alaska State Planes, Zone 04, US Feet Declination Date: December 15, 2008 Location Lat(Long: N 70.51110601, W 149.86296360 Magnetic Declination Model: BGGM 2008 Location Gntl WE Y/X: N 6036573.110 flUS, E 516746.340 f US North Reference: True North Grid Convergence Angle: +0.129185091 Total Corr Mag North -> Tree North: +22.017 - Grid Scale Factor: 0.99990032 Local Coordinates Referenced To- Wnll Head Comments Messure0 Depth (B) Inclination (deo) Azimuth (deg) Sub9ea ND (f) ND (ft) Vertical Section (ft) Alon Nolo 9 Departure (ft) Closure (ft) NS (ft) EW (ft) DLS (dea/100ft) Northing (1tus) Easting OtisI Latitude Longitude RTE 0.00 0.00 0.00 -53.20 0.00 0.00 0.00 0.00 0.00 0.00 0.00 6036573.11 516746.34 N 70.51110601 W 149.86296360 NSG+SSHOT 51.00 0.11 281.67 -2.20 51.00 0.01 0.05 0.05 0.01 -0.05 0.22 6036573.12 516746.29 N 70.51110603 W 149.86296399 81.00 0.08 46.14 27.80 81.00 0.03 0.07 0.07 0.03 -0.06 0.56 6036573.14 516746.28 N 70.51110609 W 149.86296410 111.00 0.17 94.73 57.80 111.00 0.04 0.13 0.04 0.04 0.00 0.44 6036573.15 516746.34 N 70.51110612 W 149.86296361 141.00 0.17 134.04 87.80 141.00 0.01 0.22 0.08 0.01 0.07 0.38 6036573.12 516746.41 N 70.51110602 W 149.86296299 179.00 0.19 158.18 125.80 179.00 -0.09 0.34 0.17 -0.09 0.14 0.20 6036573.02 516746.48 N 70.51110576 W 149.86296246 241.00 0.15 161.26 187.80 241.00 -0.26 0.52 0.33 -0.26 0.20 0.07 6036572.85 516746.54 N 70.51110529 W 149.86296194 302.00 0.35 89.34 248.80 302.00 -0.33 0.76 0.53 -0.34 0.41 0.55 6036572.77 516746.76 N 70.51110509 W 149.86296020 333.00 0.71 69.17 279.80 333.00 -0.26 1.04 0.74 -0.27 0.69 1.29 6036572.84 516747.03 N 70.51110528 W 149.86295796 364.00 1.03 56.86 310.79 363.99 -0.03 1.51 1.10 -0.05 1.10 1.19 6036573.07 516747.44 N 70.51110588 W 149.86295458 394.00 1.39 55.11 340.79 393.99 0.34 2.14 1.66 0.31 1.63 1.21 6036573.42 516747.97 N 70.51110685 W 149.862OWsD29 425.00 1.69 48.87 371.78 424.98 0.86 2.98 2.42 0.82 2.28 1.11 6036573.94 516748.62 N 70.51110826 W 149.86 '95 456.00 2.08 47.70 402.76 455.96 1.56 3.99 3.39 1.50 3.04 1.26 6036574.62 516749.38 N 70.51111011 W 149.8629x873 487.00 3.09 33.86 433.73 486.93 2.64 5.39 4.69 2.58 3.92 3.81 6036575.69 516750.25 N 70.51111304 W 149.86293152 520.00 3.82 30.92 466.67 519.87 4.34 7.37 6.55 4.26 4.98 2.28 6036577.38 516751.31 N 70.51111764 W 149.86292284 550.00 4.92 29.25 496.58 549.78 6.34 9.66 8.74 6.24 6.12 3.69 6036579.36 516752.45 N 70.51112305 W 149.86291349 593.00 5.45 28.94 539.40 592.60 9.77 13.55 12.53 9.63 8.01 1.23 6036582.76 516754.33 N 70.51113232 W 149.86289804 Last Gyro 643.00 6.60 27.70 589.13 642.33 14.44 18.79 17.70 14.26 10.50 2.31 6036587.39 516756.80 N 70.51114495 W 149.86287771 MWD+GMAG 675.74 6.75 27.81 621.64 674.84 17.83 22.60 21.47 17.62 12.27 0.46 6036590.76 516758.57 N 70.51115415 W 149.86286320 766.13 8.26 28.84 713.24 766.44 28.55 34.67 33.49 28.24 18.00 1.64 6036601.39 516764.28 N 70.51118315 W 149.86281628 863.79 9.86 30.84 807.70 860.90 41.73 49.73 48.54 41.29 25.52 1.70 6036614.46 516771.76 N 70.51121881 W 149.86275480 959.39 13.95 30.83 901.23 954.43 58.84 69.45 68.26 58.22 35.62 4.28 6036631.41 516781.83 N 70.51126506 W 149.86267211 SuweyEditor Ver SP 2.1 Bld( doc40x_100) OP03\OP03-P05\OP03-PO5\OP03-P05 Generated 12/29/2008 4:21 PM Page 1 of 5 Comments '""`"" Depth In) Inclination Idegl Azimuth (deg) Subsea TO (n) TO (n) YC1YO SecBon (n) Depenure In) Closure (nl NS (n) EW (n) OLS (de UOn) Nonhln 9 (ttus) Easun 9 I (nus) Latitude Lon itude 9 1055.45 13.29 37.29 994.59 1047.79 77.78 92.04 90.83 76.95 48.25 1.73 6036650.16 516794.41 N 70.51131622 W 149.86256881 1151.78 17.23 47.29 1087.52 1140.72 96.57 117.33 115.73 95.45 65.45 4.90 6036668.69 516811.57 N 70.51136675 W 149.86242807 1247.26 20.58 53.28 1177.85 1231.05 116.62 148.24 145.66 115.08 89.30 4.05 6036688.38 516835.37 N 70.51142039 W 149.86223291 1342.33 22.19 57.65 1266.38 1319.58 136.72 182.89 178.97 134.68 117.86 2.38 6036708.04 516863.89 N 70.51147393 W 149.86199918 1439.00 24.00 59.30 1355.30 1408.50 157.08 220.80 215.46 154.49 150.19 1.99 6036727.92 516896.17 N 70.51152804 W 149.86173465 1485.63 24.31 59.06 1397.84 1451.04 167.14 239.89 233.95 164.26 166.58 0.70 6036737.73 516912.53 N 70.51155474 W 149.86160057 1532.89 24.77 59.66 1440.83 1494.03 177.44 259.51 253.04 174.27 183.47 1.11 6036747.77 516929.40 N 70.51158207 W 149.86146238 1628.19 24.76 60.43 1527.37 1580.57 197.97 299.43 292.00 194.20 218.06 0.34 6036767.78 516963.94 N 70.51163652 W 149.86117937 1723.85 26.67 62.34 1613.55 1666.75 218.46 340.94 332.55 214.05 254.50 2.18 6036787.71 517000.33 N 70.51169075 W 149.86088118 1820.50 29.22 62.28 1698.93 1752.13 240.20 386.22 376.91 235.10 294.60 2.64 6036808.85 517040.38 N 70.51174825 W 149.86055304 1915.77 32.88 62.44 1780.53 1833.73 263.75 435.35 425.25 257.89 338.13 3.84 6036831.73 517083.85 N 70.51181050 W 149.86019689 2011.43 36.93 62.27 1858.97 1912.17 289.99 490.08 479.28 283.28 386.60 4.23 6036857.24 517132.26 N 70.51187987 W 149.8598Q021 2107.31 42.53 63.06 1932.68 1985.88 319.04 551.34 539.88 311.39 441.03 5.86 6036885.46 517186.62 N 70.51195665 W 149.85 92 2202.72 44.14 64.83 2002.07 2055.27 348.81 616.81 604.60 340.13 499.85 2.11 6036914.34 517245.37 N 70.51203516 W 149.85887349 2289.22 46.70 67.27 2062.79 2115.99 374.76 678.41 665.30 365.11 556.16 3.58 6036939.44 517301.62 N 70.51210338 W 149.85841275 13-3/8" @ 2351'md 2416.08 49.99 67.89 2147.09 2200.29 412.42 773.19 758.58 401.24 643.77 2.62 6036975.76 517389.14 N 70.51220207 W 149.85769583 2512.29 52.61 70.38 2207.25 2260.45 440.35 848.26 832.37 427.95 713.93 3.39 6037002.63 517459.23 N 70.51227502 W 149.85712174 2607.91 54.14 71.93 2264.29 2317.49 466.39 925.00 907.54 452.73 786.55 2.06 6037027.57 517531.79 N 70.51234269 W 149.85652746 2703.27 59.45 73.10 2316.50 2369.70 491.65 1004.76 985.57 476.67 862.63 5.66 6037051.68 517607.81 N 70.51240806 W 149.85590489 2799.58 61.55 74.35 2363.92 2417.12 516.53 1088.57 1067.51 500.15 943.09 2.46 6037075.33 517688.21 N 70.51247218 W 149.85524648 2894.25 65.66 73.35 2406.00 2459.20 541.55 1173.36 1150.63 523.75 1024.53 4.44 6037099.11 517769.58 N 70.51253661 W 149.85458011 2990.61 67.91 73.03 2443.98 2497.18 568.63 1261.91 1237.87 549.36 1109.29 2.35 6037124.91 517854.28 N 70.51260654 W 149.85388644 3086.28 67.62 72.12 2480.18 2533.38 596.62 1350.46 1325.42 575.87 1193.78 0.93 6037151.62 517938.70 N 70.51267895 W 149.85319503 3181.28 67.80 72.25 2516.22 2569.42 624.97 1438.37 1412.54 602.77 1277.47 0.23 6037178.69 518022.32 N 70.51275238 W 149.85251020 3276.99 67.63 70.31 2552.51 2605.71 654.85 1526.93 1500.55 631.19 1361.34 1.88 6037207.30 518106.12 N 70.51282998 W 149.85182385 3373.28 67.47 67.26 2589.29 2642.49 688.49 1615.91 1589.36 663.38 1444.29 2.93 6037239.68 518188.98 N 70.51291790 W 149.85114503 3469.07 66.53 65.02 2626.72 2679.92 725.55 1704.09 1677.52 699.04 1524.92 2.37 6037275.52 518269.53 N 70.51301527 W 149.85048515 3564.54 66.33 63.39 2664.90 2718.10 764.99 1791.59 1765.00 737.12 1603.71 1.58 6037313.77 518348.22 N 70.51311924 W 149.84984040 3661.47 64.98 58.37 2704.88 2758.08 809.27 1879.89 1853.02 780.06 1680.83 4.92 6037356.87 518425.24 N 70.51323649 W 149.84P^ 922 3757.78 63.04 52.93 2747.11 2800.31 859.30 1966.44 1938.42 828.85 1752.28 5.46 6037405.82 518496.57 N 70.51336974 W 149.84 X43 3853.53 63.58 49.59 2790.12 2843.32 913.99 2051.99 2021.71 882.38 1818.99 3.17 6037459.50 518563.15 N 70.51351593 W 149.848U/843 3950.54 63.41 46.87 2833.42 2886.62 972.93 2138.80 2105.33 940.20 1883.73 2.52 6037517.46 518627.76 N 70.51367384 W 149.84754852 4046.70 62.46 43.33 2877.19 2930.39 1034.40 2224.42 2186.75 1000.62 1944.38 3.42 6037578.01 518688.26 N 70.51383886 W 149.84705209 4141.64 62.01 40.30 2921.42 2974.62 1097.97 2308.43 2265.39 1063.22 2000.39 2.86 6037640.73 518744.12 N 70.51400983 W 149.84659364 4236.81 62.15 37.36 2965.99 3019.19 1164.38 2392.51 2342.91 1128.72 2053.10 2.73 6037706.34 518796.69 N 70.51418873 W 149.84616209 4330.40 62.49 34.16 3009.48 3062.68 1232.46 2475.39 2418.00 1195.96 2101.53 3.05 6037773.68 518844.95 N 70.51437239 W 149.84576567 4427.15 62.75 31.02 3053.98 3107.18 1305.62 2561.29 2494.33 1268.33 2147.79 2.89 6037846.15 518891.05 N 70.51457007 W 149.84538690 4523.33 62.48 27.20 3098.23 3151.43 1380.93 2646.69 2568.39 1342.93 2189.33 3.54 6037920.83 518932.41 N 70.51477381 W 149.84504678 4618.58 62.22 24.86 3142.44 3195.64 1457.37 2731.06 2639.97 1418.73 2226.35 2.19 6037996.71 518969.26 N 70.51498087 W 149.84474360 4714.49 61.60 23.50 3187.60 3240.80 1535.15 2815.67 2711.08 1495.92 2261.01 1.41 6038073.97 519003.74 N 70.51519170 W 149.84445977 SurveyEdnor Ver SP 2.1 Bld(doc40x_100) OP03\OP03-P05\OP03-P05\OP03-P05 Generated 12/29/2008 4:21 PM Page 2 of 5 • Comments Measured Depth (ft) Inclination (deg) Azimuth (deal SubVD sea T 1X1 TO (X) Vertical Section (X) Along Hole Departure (ft) Closure (ft) NS (XI EW (X) DLS IdeallgOXI Northing (X85) Eesting Ih031 Latitude Longitude 4811.08 61.02 22.60 3233.97 3287.17 1613.68 2900.40 2782.16 1573.88 2294.19 1.01 6038152.00 519036.74 N 70.51540466 W 149.84418806 4907.50 62.79 20.67 3279.38 3332.58 1693.28 2985.46 2853.13 1652.94 2325.53 2.55 6038231.12 519067.90 N 70.51562062 W 149.84393132 5002.69 65.14 16.43 3321.18 3374.38 1774.81 3070.97 2922.67 1734.01 2352.70 4.70 6038312.24 519094.89 N 70.51584206 W 149.84370876 5099.36 66.29 13.28 3360.94 3414.14 1860.34 3159.08 2991.88 1819.17 2375.28 3.20 6038397.44 519117.27 N 70.51607468 W 149.84352377 5195.77 67.79 10.30 3398.56 3451.76 1947.53 3247.85 3059.64 1906.05 2393.40 3.24 6038484.36 519135.20 N 70.51631202 W 149.84337522 Tie -In Survey 5195.77 67.79 10.30 3398.56 3451.76 1947.53 3247.85 3059.64 1906.05 2393.40 1.44 6038484.36 519135.20 N 70.51631202 W 149.84337522 MWD+GMAG 5259.92 68.26 9.73 3422.56 3475.76 2006.29 3307.34 3104.48 1964.64 2403.75 1.10 6038542.96 519145.41 N 70.51647205 W 149.84329040 5319.20 67.13 9.62 3445.06 3498.26 2060.51 3362.18 3146.04 2018.70 2412.96 1.91 6038597.04 519154.50 N 70.51661974 W 149.84321482 5362.87 65.95 10.13 3462.44 3515.64 2100.08 3402.24 3176.73 2058.17 2419.83 2.91 6038636.52 519161.28 N 70.51672755 W 149.84315849 5397.42 66.32 9.51 3476.42 3529.62 2131.31 3433.84 3201.07 2089.30 2425.22 1.96 6038667.66 519166.60 N 70.51681259 W 149.84311430 5428.29 67.74 8.62 3488.47 3541.67 2159.45 3462.26 3222.64 2117.37 2429.70 5.31 6038695.73 519171.01 N 70.51688926 W 149.84307759 5458.27 69.15 8.16 3499.48 3552.68 2187.10 3490.14 3244.08 2144.95 2433.77 4.91 6038723.32 519175.02 N 70.51696461 W 149.843n4422 5492.34 69.91 7.49 3511.40 3564.60 2218.79 3522.06 3268.31 2176.57 2438.11 2.89 6038754.95 519179.29 N 70.51705099 W 149.84 57 5523.36 70.57 6.02 3521.89 3575.09 2247.84 3551.25 3290.23 2205.56 2441.54 4.94 6038783.95 519182.66 N 70.51713019 W 149.84298040 5553.27 71.67 4.47 3531.57 3584.77 2276.06 3579.55 3311.10 2233.74 2444.13 6.13 6038812.13 519185.18 N 70.51720717 W 149.84295916 5648.64 72.62 359.10 3560.83 3614.03 2366.79 3670.32 3374.99 2324.43 2446.95 5.45 6036902.82 519187.79 N 70.51745493 W 149.84293588 5743.84 74.01 358.28 3588.16 3641.36 2457.90 3761.51 3436.92 2415.60 2444.86 1.68 6038993.97 519185.50 N 70.51770398 W 149.84295271 5838.96 77.52 358.97 3611.54 3664.74 2550.00 3853.70 3500.77 2507.76 2442.65 3.76 6039086.11 519183.08 N 70.51795574 W 149.84297053 5935.30 81.51 358.20 3629.07 3682.27 2644.63 3948.41 3567.60 2602.44 2440.31 4.22 6039180.78 519180.53 N 70.51821440 W 149.84298946 9-5/8" @ 5960'md 6055.77 84.01 0.25 3644.26 3697.46 2764.07 4067.91 3654.60 2721.92 2438.70 2.67 6039300.25 519178.65 N 70.51854081 W 149.84300231 6151.80 86.99 0.15 3651.79 3704.99 2859.78 4163.63 3726.66 2817.64 2439.03 3.10 6039395.96 519178.76 N 70.51880231 W 149.84299932 6248.10 86.67 359.67 3657.11 3710.31 2955.92 4259.78 3799.78 2913.60 2438.88 0.60 6039492.10 519178.40 N 70.51906499 W 149.84300030 6343.73 90.53 359.96 3659.45 3712.65 3051.48 4355.37 3873.37 3009.38 2438.57 4.05 6039587.67 519177.87 N 70.51932611 W 149.84300257 6439.16 91.49 359.72 3657.77 3710.97 3146.87 4450.78 3947.79 3104.79 2438.31 1.D4 6039683.08 519177.39 N 70.51958676 W 149.84300449 6533.16 89.52 357.82 3656.94 3710.14 3240.79 4544.77 4020.89 3198.76 2436.29 2.91 6039777.03 519175.16 N 70.51984347 W 149.84302076 6630.79 67.79 356.33 3659.23 3712.43 3338.16 4642.37 4095.90 3296.23 2431.31 2.34 6039874.48 519169.96 N 70.52010974 W 149.64306126 6723.70 87.30 355.14 3663.21 3716.41 3430.59 4735.20 4166.73 3388.79 2424.40 1.38 6039967.02 519162.85 N 70.52036262 W 149.84311752 6819.79 87.59 355.13 3667.50 3720.70 3526.08 4831.19 4240.24 3484.44 2416.26 0.30 6040062.64 519154.50 N 70.52062393 W 149.84318391 6914.93 89.33 355.96 3670.05 3723.25 3620.75 4926.29 4314.37 3579.26 2408.88 2.03 6040157.42 519146.90 N 70.52088295 W 149.841•"412 7012.37 88.48 355.34 3671.91 3725.11 3717.75 5023.72 4391.25 3676.40 2401.49 1.08 6040254.54 519139.29 N 70.52114633 W 149.84, 35 7107.59 88.73 354.72 3674.23 3727.43 3812.42 5118.91 4466.52 3771.23 2393.24 0.70 6040349.34 519130.83 N 70.52140741 W 149.84337161 7203.60 86.67 355.78 3678.09 3731.29 3907.87 5214.83 4543.35 3866.83 2385.30 2.41 6040444.91 519122.67 N 70.52166857 W 149.84343640 7299.18 86.32 359.04 3683.93 3737.13 4003.07 5310.24 4622.50 3962.12 2380.99 3.42 6040540.18 519118.15 N 70.52192890 W 149.84347144 7394.65 83.03 359.04 3692.79 3745.99 4098.06 5405.28 4703.40 4057.15 2379.39 3.45 6040635.20 519116.34 N 70.52218851 W 149.84348423 7490.89 83.03 359.74 3704.47 3757.67 4193.55 5500.81 4785.54 4152.67 2378.38 0.72 6040730.71 519115.11 N 70.52244947 W 149.84349230 7585.93 85.84 4.22 3713.69 3766.89 4288.09 5595.39 4869.37 4247.17 2381.65 5.55 6040825.21 519118.17 N 70.52270763 W 149.84346523 7681.64 88.22 7.00 3718.65 3771.85 4383.35 5690.97 4957.04 4342.28 2391.00 3.82 6040920.33 519127.30 N 70.52296744 W 149.84338848 7778.26 85.12 5.93 3724.26 3777.46 4479.35 5787.41 5046.36 4438.11 2401.86 3.39 6041016.17 519137.94 N 70.52322922 W 149.84329931 7875.15 80.92 3.46 3736.03 3789.23 4575.29 5883.56 5134.52 4533.93 2409.74 5.02 6041112.00 519145.60 N 70.52349098 W 149.84323455 7971.89 79.59 2.36 3752.41 3805.61 4670.58 5978.90 5221.03 4629.15 2414.58 1.77 6041207.22 519150.23 N 70.52375110 W 149.84319465 SurveyEditor Ver SP 2.1 Bid( doc40x_100 ) OP03\OP03-P05\OP03-P05\OP03-P05 Generated 12/29/2008 4:21 PM Page 3 of 5 Comments Measured Depth (M) Inclination Idea) Azimuth Idea) Sub -Sea TVD (h) TVD (ft) Vertical Section (f) Along Hak Departure (h) Closure I (8) NS I (8) EW (ft) US (dealloofll Northing OUS) Easdng (alts) Latitude Longitude 9 8067.01 80.49 2.69 3768.86 3822.06 4764.23 6072.59 5306.07 4722.74 2418.71 1.01 6041300.81 519154.15 N 70.52400678 W 149.84316061 8162.64 84.41 4.13 3781.42 3834.62 4858.93 6167.37 5392.99 4817.35 2424.35 4.36 6041395.43 519159.58 N 70.52426524 W 149.84311416 8257.68 87.96 5.52 3787.75 3840.95 4953.53 6262.18 5481.08 4911.83 2432.33 4.01 6041489.91 519167.34 N 70.52452333 W 149.84304859 8354.01 91.07 6.11 3788.56 3841.76 5049.50 6358.50 5571.38 5007.65 2442.08 3.29 6041585.74 519176.88 N 70.52478508 W 149.84296843 8448.79 88.73 4.41 3788.73 3841.93 5144.01 6453.27 5660.11 5102.02 2450.77 3.05 6041680.12 519185.35 N 70.52504288 W 149.84289704 8544.58 87.16 2.26 3792.16 3845.36 5239.65 6549.00 5748.77 5197.58 2456.34 2.78 6041775.68 519190.71 N 70.52530392 W 149.84285118 8638.88 87.90 0.13 3796.23 3849.43 5333.86 6643.21 5834.90 5291.76 2458.31 2.39 6041869.86 519192.46 N 70.52556122 W 149.84283484 8734.36 89.26 1.19 3798.59 3851.79 5429.30 6738.66 5922.05 5387.20 2459.41 1.81 6041965.30 519193.34 N 70.52582195 W 149.84282558 8829.33 89.90 1.58 3799.29 3852.49 5524.27 6633.63 6009.48 5482.14 2461.70 0.79 6042060.23 519195.43 N 70.52608131 W 149.84280653 8926.31 90.95 1.02 3798.57 3851.77 5621.24 6930.60 6098.94 5579.09 2463.90 1.23 6042157.17 519197.41 N 70.52634616 W 149.84278825 9021.61 89.82 359.40 3797.93 3851.13 5716.53 7025.90 6186.37 5674.38 2464.25 2.07 6042252.46 519197.54 N 70.52660649 W 149.84278513 9117.42 89.45 359.35 3798.54 3851.74 5812.30 7121.71 6273.95 5770.19 2463.21 0.39 6042348.25 519196.28 N 70.52686821 W 149.84279343 9214.09 91.39 359.66 3797.83 3851.03 5908.93 7218.37 6362.64 5866.85 2462.37 2.03 6042444.90 519195.23 N 70.52713226 W 149.84 '00 9308.19 93.70 358.66 3793.65 3846.85 6002.88 7312.37 6448.88 5960.84 2460.99 2.67 6042538.87 519193.64 N 70.52738903 W 149.84281102 9405.03 92.25 356.33 3788.63 3841.83 6099.40 7409.08 6536.69 6057.44 2456.77 2.83 6042635.46 519169.19 N 70.52765295 W 149.84284538 9499.37 92.47 357.34 3784.74 3837.94 6193.41 7503.34 6622.07 6151.56 2451.56 1.09 6042729.55 519183.78 N 70.52791007 W 149.84288774 Tie -In Survey 9594.12 88.28 355.83 3784.12 3837.32 6287.85 7598.06 6707.94 6246.11 2445.92 4.70 6042824.09 519177.92 N 70.52816839 W 149.84293370 MWD+GMAG 9690.40 86.67 355.29 3788.36 3841.56 6383.60 7694.25 6794.65 6342.01 2438.47 1.76 6042919.95 519170.26 N70.52843036 W 149.84299441 9786.71 86.33 356.15 3794.24 3847.44 6479.32 7790.38 6881.67 6437.87 2431.30 0.96 6043015.79 519162.87 N 70.52869225 W 149.84305291 9882.76 88.97 358.95 3798.18 3851.38 6575.10 7886.34 6970.00 6533.73 2427.20 4.00 6043111.63 519158.56 N 70.52895413 W 149.84308622 9978.17 88.18 359.81 3800.55 3853.75 6670.44 7981.72 7059.13 6629.11 2426.17 1.22 6043206.99 519157.31 N 70.52921468 W 149.84309442 10074.47 85.96 359.04 3805.48 3858.68 6766.57 8077.88 7149.18 6725.27 2425.20 2.44 6043303.15 519156.13 N 70.52947738 W 149.84310206 10170.93 85.16 359.55 3812.94 3866.14 6862.70 8174.05 7239.32 6821.43 2424.02 0.98 6043399.29 519154.73 N 70.52974009 W 149.84311150 10265.21 85.61 358.64 3820.53 3873.73 6956.62 8268.03 7327.44 6915.39 2422.53 1.07 6043493.24 519153.03 N 70.52999678 W 149.84312340 10362.44 87.76 358.95 3826.15 3879.35 7053.61 8365.09 7418.42 7012.43 2420.49 2.23 6043590.27 519150.77 N 70.53026188 W 149.84313986 10455.76 90.24 359.61 3827.78 3880.98 7146.86 8458.39 7506.29 7105.72 2419.32 2.75 6043683.55 519149.39 N 70.53051673 W 149.84314921 10553.66 90.28 359.95 3827.34 3880.54 7244.74 8556.29 7598.91 7203.62 2418.94 0.35 6043781.43 519148.79 N 70.53078418 W 149.84315203 10646.62 88.19 357.94 3828.58 3881.78 7337.62 8649.23 7686.52 7296.55 2417.23 3.12 6043874.35 519146.87 N 70.53103804 W 149.84316579 10743.33 87.05 357.39 3832.59 3885.79 7434.08 8745.86 7777.00 7393.09 2413.30 1.31 6043970.87 519142.72 N 70.53130179 W 149.84P X777 10838.23 87.36 357.42 3837.22 3890.42 7528.68 8840.65 7865.76 7487.78 2409.01 0.33 6044065.54 519138.21 N 70.53156047 W 149.84 ,07 10935.61 87.99 357.87 3841.17 3894.37 7625.82 8937.95 7957.15 7585.00 2405.01 0.79 6044162.74 519134.00 N 70.53182606 W 149.84326516 11030.81 87.48 357.94 3844.93 3898.13 7720.80 9033.07 8046.78 7680.06 2401.53 0.54 6044257.78 519130.31 N 70.53208575 W 149.84329339 11125.45 88.62 358.98 3848.15 3901.35 7815.29 9127.65 8136.32 7774.61 2398.99 1.63 6044352.32 519127.55 N 70.53234405 W 149.84331396 11220.65 88.39 0.12 3850.64 3903.84 7910.43 9222.82 8227.08 7869.77 2398.24 1.22 6044447.47 519126.59 N 70.53260402 W 149.84331983 11317.58 89.90 1.96 3852.08 3905.28 8007.34 9319.74 8320.32 7966.67 2400.00 2.46 6044544.36 519128.13 N 70.53286872 W 149.84330516 11413.71 87.79 1.58 3854.02 3907.22 8103.44 9415.84 8413.19 8062.73 2402.97 2.23 6044640.41 519130.88 N 70.53313114 W 149.84328059 11508.56 87.63 1.32 3857.81 3911.01 8198.21 9510.62 8504.71 8157.47 2405.37 0.32 6044735.15 519133.07 N 70.53338996 W 149.84326069 11604.15 87.22 0.88 3862.11 3915.31 8293.70 9606.11 8596.84 8252.95 2407.20 0.63 6044830.62 519134.68 N 70.53365079 W 149.84324542 11698.80 89.84 1.63 3864.53 3917.73 8388.31 9700.72 8688.26 8347.53 2409.27 2.88 6044925.20 519136.54 N 70.53390918 W 149.84322819 11795.11 89.78 1.92 3864.85 3918.05 8484.61 9797.03 8781.61 8443.80 2412.26 0.31 6045021.46 519139.31 N 70.53417216 W 149.84320350 SurveyEditor Ver SP 2.1 Bid( doC40x_100) OP03\OP03-P05\OP03-P05\OP03-P05 Generated 12/29/2008 4:21 PM Page 4 of 5 commentsI Measured I Inclination I Azimuth ISub-Sea NDI ND I vertical I Along Hole I Closure I NS I EW I DLS I Northing I Easting I Latitude I Longitude Depth Section De arture I Iooa.zI MW 1.r8 88po.44 3916.54 6b/8.N 9891.13 8872.89 8537.85 2415.25 0.36 6045115.51 519142.09 N70.53442909 W149.84317870 11988.55 87.25 358.91 3868.26 3921.46 8677.97 9990.42 8968.62 8637.13 2415.81 3.63 6045214.78 519142.43 N 70.53470031 W 149.84317388 12084.50 87.33 359.04 3872.80 3926.00 8773.76 10086.27 9060.48 8732.96 2414.09 0.16 6045310.60 519140.49 N 70.53496210 W 149.84318767 12179.76 86.62 358.77 3877.83 3931.03 8868.82 10181.39 9151.71 8828.06 2412.28 0.80 6045405.69 519138.46 N 70.53522192 W 149.84320231 12275.82 89.10 0.20 3881.41 3934.61 8964.77 10277.38 9244.11 8924.04 2411.41 2.98 6045501.66 519137.38 N 70.53548412 W 149.84320911 Last survey 12324.11 90.14 0.72 3881.73 3934.93 9013.06 10325.67 9290.83 8972.33 2411.80 2.41 6045549.94 519137.66 N 70.53561603 W 149.84320581 TO (Projected) 12384.00 90.14 0.72 3881.59 3934.79 9072.94 10385.56 9348.87 9032.22 2412.56 0.00 6045609.82 519138.28 N 70.53577963 W 149.84319948 Survey Type: Definitive Survey NOTES: NSG+SSHOT - (NorthSeeking Gyro Singleshots -- Northseeking gyro in gyrocompassing or stationing mode with larger. misalignment errors as a result of landing in a UBHO sub. Not to be run above 70 degrees inclination. ) MWD+GMAG - (MWD + IFR + SLB Multi -station correction + Sag correction - Standard SLB MWD error model where the surveys have been geomagnetically reference (declination) corrected using a local crustal magnetic model and the SLB multistation drillstring magnetic interference correction GMAG (GeoMAGnetic Correction) under survey specialist supervision - and where the inclinations have then been corrected for BHA sag. Legal Description: Northing (Y) fftUSl Easting W MUST Surface: 3220 FSL 1534 FEL S5 T13N R9E UM 6036573.11 516746.34 BHL : 1692 FSL 4373 FEL S28 T14N R9E UM 6045609.82 519138.28 SurveyEdhor Ver SP 2.1 Bid( dcc40x_700 ) OP03\OP03-P05\OP03-P05\0P03-P05 Generated 12/29/2008 4:21 PM Page 5 of 5 r Complete Well Summary 2281Cpde 22827 1 Operator ENI PETROLEUM OP03-P05 RKB (fl) 41.00 KB -Ground Distance (ft) 2860 Spud Date Rig 11/16/2008 Release Date Surface Legal Location Latitude (DMS) Longitude (OMS) 70.30' 38.94" N 149' 51' 58.006" W Wall :DIRECTIONAL -Orf nal Hole l/1520099DT34AM Original Hole ftKB MD flK8 Ind DLS Schemalic-Adual De Markers Wellbore APl/UWI BM. Loc. P "a Type KO MD(flKB) VS Dir(') Eatentletl Reach 110.0 100 Proposed Deviation Survey Deviation Survey 0 0 9 LS1 0- - - - - - Surface Surface 32 32 0.1 •- -- - = " Size (in) I AG Top (RKB) Ad Btm `RKB) 20 39.0 154.0 34 34 0.1 35 35 0.1 16 154.0 2,368.0 36 36 0.1 121/4 2,358.0 6,045.0 37 37 0.1 121/4 2,368.0 6,012.0 37 37 0.1 81/2 6,012.0 12,384.0 PBTDs 38 39 40 38 39 40 0.1 0.1 0.1 - ^"""^* Date I Depth(flKS) 1 Method Comment 70 70 0.1 Formations 110 110 0.2 119 119 02 Final Top MD Final Top TVD 119 119 02 Formation Age Element Type H2S I%) (RKB) (RKB) 120 120 0.2 Base Permafrost Base Permafrost 154 154 0.2 Ugnu Ugnu ,24: 2,083 45.3 Lower Ugnu Lower Ugnu ,26:2,099 46.0 Schrader Bluff Schrader Bluff ,261 2,100 460 N Send N Sand ,3k 2,155 48.3 OA Sand OA Sand ,35 ,351 2,157 2,161 48.3 48.5 Deviation Surve s ,39:2184 ,68' 3,227 494 61.8 ArtificialLit Run, 6 7/16.0 Date Description Prop? Definifive? 11/17/2008 Surface No Yes Res irvoirs ,851 ,871 .911 ,SE 3,313 3,317 3,337 3,365 62.0 62.2 630 646 Reservoir Name Depth Top Depth Btm(ItM) es Depth RDatum (R (es 102, 3,383 3,433 65.4 67.1 CONDUCTOR 150.0ffKIS Run Dale Centralizers Scratchers Drift M... ,14f 3,436 67.2 ,15: ,18 : 16: ,241, 3,d38 3,3. 1 3,472 8].3 674 68.1 9/25/2008 OD hh) luem Description arm (RKB) AS ID fin) Wt Grade Top Threatl 20 CSG 154.0 11 15.2501 122544.31X-65 CASING 2350.7ftKB ,25:3,474 662 Run Date Canirdl2ers Scratchers Drift M... ,25 3,474 68.2 ,2e ,26( 3,475 3,476 68.2 68.2 11/22/2008 22 Tandem Rise Centralizers. 3 on float joints and 2 in conductor. Total of 22. OD (in) Item Description I arm (RKB) I Jts I 10 (in) kV! Grade I Top Thread ,2% 3,488 68.2 1 RKB 37.1 1 ,30: 3,492 67.9 ,30! 3,494 67.6 181/8 CSG HGR 37.4 1 12.40521PISA ,311 3,497 67.2 13 3/8 CSG PUP 69.6 5 12.415 9736.803 LBO ABTR ,321 3,500 67.0 13 SB CSG 2,264.9 53 12.415 664044.6 L80 ASTIR ,33: 3,503 BBS 133/8 COLL 2,266.4 112,415 453.7187 L80 BTC ,341 3,506 3,507 666 66.5 133/8 CSG 133/8 SHOE 2,348.8 2,350.7 2 12.415 1 12.415 24915.21 5777351 LBO ABTR LBO BTC CASING 5960.OftKB ,34. 3,506 66.5 ,48' 3,562 69.8 Run Date Centralizers Scratchers Drift M... ,73! 3,638 73.9 12/13/2008 25 Tandem Rise Centralizers. 1 each / 8.525 ,75 3,643 74.4 10' above FC ,751 3,644 74.4 OD (in) Item Description Btm (RKB) Jus I ID (in) W1 Grade Top Thread 1 RKB=VETCO-GRAY 35.3 1 8.681 7472.035 L-80 BTC ,76! 3,646 748 7&3846 74S LANDING JOINT ,8& ,83. 3,662 3,663 7T2 77.3 12 314 Mandrel Vetw Ceg Hgr MR247 36.2 1 8.601 2TPISA ,87: 3,670 78.9 95/8 Jt Csg 9-5/8 PUP 38.4 1 8681 459.9452 LBO BTC ,87:3,671 789 95/8 ACsg 9.5/8 4,866.0 116 8.681 1009275 LBO BTC ,91r ,951 3,678 3,685 S07 82.0 95/8 9-5/8" Joint Casing Pup (Confirm Drifted) 4,875.8 1 8.681 2055.123 LBO BTC ,961 ,013,692 3,885 82.0 83.1 95/8 JI Centralizer Deg 8-518 Last (26 -Total 4,917.9 1 8.681 8803.788 1_80 BTC ,03: 3,694 83.5 ) ,04:3,696836 95/8 ACsg 9-5/8 5,8304 22 8.681 190773.1 L80 BTC ,06'3,69784.2 ,80 ,841 ,63' ,09:3,825 ,BT. ,91! 3,720 3,721 3,]89 3,852 3,852 87.5 88.0 87.0 81.5 90.5 90 9 9518 ADeg Cerltral'aer-1 to 9 5/8 Float 95/8 ACsg 95/8 ACsg Centralizers S 95/8 each / above FC Collar 95/8 95/8 2 each at t. 88 it 5,871.9 5,873.4 5,916.3 5,958.3 1 8.661 1 8.681 1 8.681 18681 8686.711 8979.404 8774.521_80 LBO BTC L80 BTC L80 BTC BTC .741 ,791 3,845 3,847 86.5 86.4 9518 Float Shoe 5,960.0 1 8.681 L80 BTC LINER, 12 368.0(0(6 3,61 3,881 88.9 Run Date Centralizers Scratchers Drift M... 3,85.3,882 88.0 1,45 3,910 87.7 12/25/2008 DO (in) Item Description Btm(ffKB) Jus ID (m) Wt Grade Top Thread 1,523,912 87.5 51/2 ZXP prole, TKC Liner Top Pkr, HR with HD's, 7" 5,753.9 1 4.892 1468.536 L-80 2,3E 2,3E >,38 3,935 3,935 3,935 90.1 90.1 90.1 S 12 RS 512 Flex Nipple, 7" TKC -Lock Hyd Liner 5,755.1 5,765.1 7 4.892 1 4.892 80.74374 756.1978 1_-80 L-80 data last updated on 1/7/2009 2:22 PM grnt www.peloton.com printed on Thursday, January 15, 2009 page 1/ Hanger, - Pin 7" BTC Pin x Summary Well Summa OD(in) Item Description Btm(ftKB) Jts ID (in) RR Grade Top Thread 51/2 Crossover, 7" TKC Box 5,766.5 1 4 892 107.3801 LA0 Complete p X 512" DAC Pin OP03-P05 512 A 51/7' Blank Liner 6,061.4 7 4.892 22299.52 LA0 51/2 A 5 12" Slotted Liner 6,804.1 18 4.892 56165.84 LA0 512 A 512" Blank Liner 6,845.0 1 4.892 3087.556 LA0 512 512 A 512' Slottetl Liner 7,6310 A 512" Blank Liner 8,091.6 19 11 4.892 5943564 4.892 34836.52 LA0 L-80 Welltype:DIRECTIONAL- Original Hole t/ 15/20099.07:34AM 11M RKB MD IrKI DlS Schematic-AcWal De Markers 512 512 A. 512' Slotted Liner 8,8785 A 51/7 Blank Liner 8,918.6 19 1 4.892 59501.42 4.892 3032.353 LA0 LA0 LS :4rCmS'.sPrPr61K 0 0 9 512 A 5 12" Slotted Liner 9,748.2 20 4.892 62737.2 LA0 0 _ 512 512" Blank Liner 9,790.2 1 4.892 3170.738 L-80 _ _ _ _ _ - _ - _ _ 32 32 0.1 512 . A 512" Slotted Liner 10,617. 20 4.892 62526.21 L-80 34 34 01 512 A 512" Blank Liner 10,659.11 1 4.892 3183.593 LA0 35 35 0.1 512 JL 5 1/2" Slotted Liner 17,491.0 A 20 4.892 62905.07 L-80 36 36 01 512 A 512" Blank Liner 11,532.9 Bl:Iletl 1 4.892 3173.006 LA0 37 37 0.1 512 A 51/2' Liner 12,366.1 20 4.892 63000.36 L-80 37 37 0.1 512 ECC. Nose Guide 12,368.0 1 4.892 130.1105 LA0 38 313 0.1 Shoe, 5-12' BTC Box 39 39 0.1 40 40 0.1 Contractor Evaluation Method Cement Evaluation Results 70 70 D.1 110 110 0.2 Stg No. Description Top (RKB) Btm (RKB) Full Return? 119 119 02 No 119 119 0.2 Amount Yield Mix H2O Ratio 120 120 0.2 Fluid Class (sacks) (R%seck) (gakaack) V(bbl) Fluid Des 154 154 0.2 ,24: 2,083 45.3 Other In Hole ,26: 2,099 46.0 ,2& 2,100 46D OD (in) I Description Top (RKB) Btm (RKB) ID (in) 1 Make Madel 34! 2,155 48.3 ,35 2,157 483 ,351 2,161 48.5 ANficial Lifl Run.B Install Date Wellhead Type Make WN (psi) Size (in) Revision Dale 38:2184 494 7/16.0 ,68: 3,227 61.8 Wellhead Components J3& 3,313 3,317 62.0 62.2 Up, Lwr Lw, ,871 ,911 3,337 63.0 Comm. Dia Conn. Dia ,98:3,365 848 Make Model S... Upr Conn. Typ (In) Lwr Conn.Typ(1n)Type L(WP-) ,0&3,38365.4 ,141 3,433 67.1 General Notes J& 3,436 672 ,16: 3,438 67.3 Data Comment 164 3,441 67.4 241 3,472 681 MOVING 10/1/2006 ,.2 25: 3,474 68 Job Category Job Phase Date start End Date ,26 3,474 682 MV MOVING 1011r200S I 11/12008 68.2 MOVING 1011/2008 ,25'.3,475 261 3,476 68.2 AFE Number Total AFE +Sup Amount Total Fld Cost Total Final lnvc'1ce Cost ,293,488 68.2 67.9 3724 Job Remarks ,30:3,492 ,30!3,494 676 ,311 3,497 67.2 Possible Cost Savings Pose Time Save (hrs) Estimated Problem Cast Est Lost Time (hrs) ,32! 3,500 670 ,33: 3,503 65.8 Phases M1 3.5015 65.6 ,34: 3,507 68.5 Planned 34. 3.508 66.5 Likely DMC' Days ML Planned End ,48 3,562 69.8 Ph OP, Phase Cost (days) Depth (RKB) ,73: 3,638 73.9 ,75. 3,6,13 744 ,751 3,6a4 74.4 AFE Cost Breakdown Cost cd. I Cost tp. I Code 1 Cost Description Amount ,76:3,846 74.8 ,761 3,646 74.8 Job Contacts ,8313,%2 772 ,0 ,87:3,670 3,663 ]].3 7B.9 Contact Name Company Title Office Mobile Bennie Leas ENI Rig Clerk 907-670-8580 907-575-9427 79.9 ,87:3,671 3.678 807 Bobby Walls ENI Drilling 907-670.8580 325665,4402 .91( Supervisor .951 3.685 82.0 Jack Keener ENI Drilling 9076706580 907-715-6434 ,981 3,885 B2.0 Supervisor ,01:3,692 83.1 Scott ENI Duping 907-670.8580 907,4416759 ,(M. 3,894 83.5 Beauchamp sor Cerk ,04:3,6% 83.8 Tom Norvig ENI Rig RRig Cllerk 907670-8580 907-2296100 O6' 3697 862 3,720 87.5 BIN No. Size (in) Madel IADC Codes IADC Bit Dull ,89 ,84! 3,721 8B.0 ,]89 8].0 Depth In (RKB) Depth Out (RKB) Drillso (ft) Drill Time (... Bit His Out... IADC Bit Dull ,625 81.5 3,852 90.5 String Components 3,852 90.9 3,845 86.53,847 DRILLING 11/7/20083,881 B6.4 Job CategoryJob Phase Date start Entl Dale 88.9 3,882 UM.5 88.0 DR DRILLING 11/72008 12282008 DRILLING 11/7/2008 3,910 87.7 V1 AFE Number Tota' "O'+Silo Amount Tog1 cpyt" �a Total Final Invoice Cost3,935 3,912 875 90.1 3724 Y,/• 90.1 )L•,ri_ ,y�`/t(<�i�3,935 Job Remarks 3,935 90.1 Possible Cost Savings Poss Time Save(hrs) Estimated Problem Cost Est Lost 7ime is) data last updated on 1/7/2009 2:22 PM 9mt 30 W printed on Thursday, January 15, 2009 2/$ -X \ www.peloton.com page "!� a Well Name I OP03-P05 Report N Skirt End fhnl Phu. Op Code Sud -Cede Time N T Start (ft) End (FI) Comments PWS. Pin down stomper on drilling module, level and shim rig module, drop down Lampson curtains, ley out seals and berm around ng modules, welder continued fabricate cellar box drip pan, Epoch continued rig up mud watch and K -box system, Schlumberger running lines on rig module to rig up MWD, clean up old rig location, truck up end band plywood, pick up SOP's with bridge cane to finish cutting out comp and base plate to move to well center. Connect service lines between modules and transfer Fluid from utility to drilling module,0 (Note) Nabors located at Continuum, the rest a equipment for nippling up: Annular 1 000 12:00 12 00 PREP A IN P 154.0 150 0 preventem Divener spool and etc to deliver to OPP, PTSM, Finish securing and trimming hematite around rig modules, tighten dresser sleeve to inner connect equalizer line, welder modifying BOP set back stomp, continue fabricate and welding out roof support beems for service buildings, electrician fixing lighting around rig, plump in gem heater in drilling chain dump room, skid ng floor to center over well, make up choke hose and brake coolant lines. No accidents or spit Is.J 000045M Continue hooking up lines: Flow line, gas buster line, and choke line. Continue bundling and bending plywood, locate subs for testing top drive ®OP's and mud hose. `1 1 Welders continue welding on roof support beams, continue to clean up and organim 1 12:00 000 12 00 PREP A 100 P 154 0 154.0 equipment on OPP. PTSM, Finish welding out roof brace freming for trailer park on top of utility module, hook up linesin room adjacent m mud pits. now line and gas buster line, Inventory BOP rams. Welders continue to work on welding out roof column brans in mud pit room, rig up and circulate through amndpipe and top drive to mud pit 42. Hadalaakinmid-section standpipe'. tighten up tame-ok. Continue with genaal housekeeping to clan up rig and location. Canrig and Epoch continue testing mud watch and K -bon system. Schlumberger continue rigging up their equipment, tanning lines, etc. for MWD: (Installed cabling for six each sensors4nsuuments installed four each sensors on rig Floor. Inventoned shack and picked up supplies in Deadhorse, Spooled cabling on rig floor module in preparation ofunit - 000 1200 12.00 PREP A 1.00 P 154.0 154.0 placement. PTSM, Welder confinue to weld out roof brace columns in mud pit room, Attempt to pressure test standpipe and kelly hose to IBOP valve on topdtive: Had two leaks, one threaded nipple on keily hose hammer union on topddve leaked, and threaded plug on standpipe leaked_ Blow down kelly hose and standpipe to repair leaks. Test kelly hose, cement line and hose to 5,000 psi for 10 minutes. Caurig complete installation, test and `\ calibrate. Change out dessiant beads in air dryer. Nlnnle uo stsnina head and divener spool to 20" conductor, teat starting head ro 500 psi, as per Vann, General housekeeping I throughout 6g0 0000.0500 Welders welding support beams in mud pit room. Moving and re-srmnging equipment on Airforce pad to move welding shop and mechanic shop to OPP. Move divener line and prepare to move to OPP. Loafing subs, BOPS, TIWs, end equipment for 2 12:00 000 12.00 PREP A 1.00 P 154.0 154 0 drillfloor. Claiming and moving equipment on OPP. PTSM, Pick up bit, bit breaker, sub rack subs, and necessary handling equipment to ng Door. Change mat rotary inset bushings in per ENVNabore commissioning. Dress out all handling equipment for S'drillpipe and 8" drill collars. Change out air dryer dessicam, continue to weld out roof column braces in mud pits for utility roof module, clean up docks on air -force pad and truck in non-essential items to NOC in Deadhune. Tum on atezm to cellar/meaanins level, welder fabricate small area at derrick ladder windwdl exit. Continue l 000 1200 1200 PREP A 100 P 1540 154.0 with general housekeeping. Welder continue t0 hbriute drip an cellar box. PTSM, Hold eatery meeting for "Critical lift", CH2NHll cone am Schlumberger MWD and dincefie d drillers traleq also xt Epoch and MI S. trader, on top of Nabors utility module rocffor rig up. Epoch/Camig continue to work on mud watch and K -box system, Schlumberger MWD also working on their equipment, Plan on moving Nabors Mechanic shop from Air -Force pad to OPP today also. Nan, finish widening the road and dirt work at mine site "E". CH2MHill built containment 110°4 at mine site "E" for light plant and an up same, also se up water shack at E -pit ready. Inventory on pre -spud equipment, weld `\ I down buildings on top of utility module, dress shaker with screens, continue welding support beams in mud pit s me, continue fabticating drip pan for eager four, mechanic repair .it ryst. to drawworke chum dutch.❑ n_ 0000-0500 Continue moving equipment and clean up OPP and Air -Force pad, install water hoses at shakers, moving excess equipment from pipe shed and bringing in equipment J 1200 0:00 1200 PREP A 1.00 P 154.0 154.0 needed for spud. PTSM, Welders continue fabricating drip -pan cellar box, Welder fabricating on altar windwalls. Epoch continue testing mud watch system and K -box. Continue to prepare handling equipment for spud. Set BOP pedestal and weld in plan. Install and set short half of cellardrip pan in place. Cunrig calibrate block height, top drive rpm, and torque to Epoch rysten on K4sox. Welder weld on grounding lugs to mud pump as Per M/ NabasMfodusp,dCommisaioning. Peinttongh.ads,thonsideddppan,andwppon beams. Continue welding/fabricefing skid beam. Phase 1 weather conditions slowed down 4 000 12:00 1200 PREP A 100 P 1540 1540 construction ofcellar. Report# sun End fhnl Phase Op Code Sub -Code YNT Start(ft) End (Ft) Comments v,� \%3 �\1`--L;o PTSM. Finish saltine first half of cellar trio can. Welding oo BOP pedestal and start to seal efFellass. Pr rung locattmn Nabon AWo tmilms, prepare mud dmks for mud products being delivered today (4 -truck loads). Schlumberger rigging up lines and equipment for MWD. Electricians wiling in trailers m top ofuNity module for preparations of OCI to start wire in communications today. All four trailers wired for power and had Nabors backhading non-essential items to Deadhone. ENIftep.witnesscommissioningof Epoch Auto-0riller (WOB,ROP, Differential) on K -box, rpm, torque, and block height. Completed building running under remaining portable equipment for drilling and mnstructiou. From ISM to present, phase 2 weather conditions exist field wide, convoy travel only as per North Slope security. The vac cock ordered by Eto for cleaning mud pits was unable to show due to Phase 2 weather conditions. Will convoy thismomingto location C 000045M Prepare to load V drillpipe in pipe shed. Pump water out of #5 pit to repair 1200 000 12,00 PREP A I.00 P 1540 154.0 washed out line. Prep BOP bolts. Fork pushing snow to now push area. Inventory subs re PTSM, point cellar has drip pan, continue building support beams, transfer water from dewarer pits to active pits, cleaning pits with vaotruck, remove welding debris from utility module roof, fabrication on roof brace columns, and clean pits #1, #2, and 03. Welder installingflashingoncellarbox. Load pipe shed with 5" drill pipe and 20joinrs ofHWDP for drilling eurface. Prepare Nabors shop for moving from Airforce pad to OPP. Hookup bed truck to shop fm moving. Remove trash line in utility module to repair leaks. Pm all r- overs, safety valva dart valve; and subs in short side of pipe shed. Stage cellar box drip pan behind cellar and install long side of drip pan in cellar, Epoch mud loggers on location 000 1200 12.00 PREP A 1.00 P 154 0 154.0 rigging up equipment. PTSM, finish installing drip pan in cellar and continue welding in flashing on cellar box. GCI wiring in communicafions for all four trailers. Rig electricians continue wiring in all underarm top ofutility module. Nabors forklift driver unloading W Swaco mud products and staging onto mud docks. Check RKB to bottom inside mnductm, ice plug at 115'. Schlumberger directional tools (16" surface and 12 1/4" intermediate) and drillingjars offloaded at DPP, Move and berm in Nabors shop mat to rig. Start benning in area for placement ofmting catch tanks. Cleaning mud pitsfor spud mud.❑ 0000-0500 Continue cleaning mud pits, continue beaming for cutting tanks, dean trash out of pipe shed, and have schooling on pipe skate operation. Nipple up diviner spool tce and 12:00 0:00 12.00 PREP A IM P 154.0 ISCD 20" annular diverter spool. PTSM, Continue to weld in flashing m cellar walls and insulate same. Strap measurements for surface alae# nipple on diverter tee spool and annular prevenmr. Weld in stiff ars undemcath support columns. Load Schlumberger directional tools into drill module side pipe shed for surface and warm up same. Spm Alaska Clean Sees Shack and Vetco Grey Shad. Load pipe rams into caller storage area. Build newjumper hose with new hydraulic fittings for rectae power tong unit. Continue cleaning last ofactive pits with CH2MHill vacuum truck. General housekeeping secure new anchor for Gerinimo escape line to denid headache crown stand. Replace washed out cash line piping in utility module side 000 1200 12.00 PREP A 1.00 P 1540 154.0 ofpipe shed. PTSM, ASRC scaffolding crew (5 workers, 1 supervisor) enacting scaffolding in rig cellar 34 feet tall, scaffolding toweron each side of surface smck-up. Set houlera m place m locationpreparation. Continue weld in flashing and insulate cellar windwalls. Thawout riser nipple and scope up. Lay plywood for walkway to service hands buildings on top of utility module. Cleaning rew mud pits with CH2111fill vacuum tend. Housekeeping perform o thorough clean up of and around rig. Construct Berm for MI Swam liquid mud productstorage. Continue fabrication ofdesilter dump line to mud pit,❑ Oran 00 Install well signs, continue cleaning raw mud pits with C112141 ill vacuum truck, continue de -junk and clean rig. ForkdiR driver pushing snow, cleaning and re -arranging 1200 000 12.00 PREP A 100 P 154.0 1540 equipment on OPP. Continue nipple up flowiine to user nipple. PTSM Continue cleaning raw mud pits with CMlvUhll vec-vuck, general housekeeping of entire rig, cut and remove ringer mum line and weld in place. Weld in two each 4" topples can conductm pipe at 60° angle and install 4' ball valves on same (Vewo Gray Rep, 'Rowdy' witness installation). Cut mud pits cuttings chute trunk -hose to length. Shorten up conveyor drag chain to correct length for adjustment, Organize Nabors 245E pad, rig modules and location in preparation for spudding well. Last load of W Swam mud products arrived on location, of u d same. Stege all liquid mud products in I M 000 1200 1200 PREP A 1.00 P 1540 154.0 containment on OPP, PTSM. Pickup and ruck back 66jcints of 5" drillpipe in demck. EM Petroleum group man arrived on location at 12:20 pm and impacted entire rig and interior. Finishing insulating cellar wind walls and welding0ashing around caller box. Finish coding and move desilter return line. Install walkways to service modules on top of utility module. Install drilling line kick rollen on dmwworks drum goods. Cut hole in sellar windwalls for diverts line ri u . Rig up win cables to traveling block bales and HYMI lifng eyes to take weight of by ril for orientation of diverter spool to makeup diverter line. CH2hBEll delivered Schlumberger cement bulk links to OPP, offload and spa same 0000-0500 Align diverttr spook clean area to brine in diviner line. Continue welding Fleshing around cellarbox. Move cuttings holding tank to welding shop and rut off 12:00 0:00 12.00 PREP A 1.00 P 154.0 154.Owalkway. Start running lines from LBT base oil holding tank to shaken. Repartq Sun End Ihrp Phase Op Code Sub -Code N -T start (h) End (Ft) Comments PTSM. Sol and align diverter te>spool stack, but cut hole in cellar box wall for diventer line installation.Clean un knife valve and fluceds- involl diverear knife wive. tie in and nipple up diverter line. Run in lock down screws m 20" speed had. Cut and thread 2" pipe with damps and plumb in LTV fine. Move second contingency ending tank to Nabors welding shop to remove walkway from drillers aide to off drillers side. Weldinfloorplate around heater conk exit in cellar wind wall, replace bent piping and replace finings below casingjumper hose for rig floor to remme casing unit line. General housekeeping and maintaance. Welder continue to work on welding out flashing top and bottom ofeellar boxwindwalls. GCIwnunuetodgupwmmuniauonsin Kaaicmnp. Epohontinucm ng up routine and rig up gas line chromatograph lines. Rig electricians work on wiring up miscellaneous items on rig, rigging up wiring on Nabors shop railer on ground. Nabors forklift driver unloaded 2000' of 2 VIP' HT41,1-190 tubulars and unload HydN 2 3/8' fixed 8 000 1200 12.00 PREP C 100 P 154.0 154o pipe rams. 8 1200 000 1200 PREP C 1M P 154.0 PTSM. Continue nipple up surface stack, connect flow line, bleeder line, and hole fill line. Secureauawithmmbuckles. Anchordown diverter line. Plumb nandconoect Kooma control lines to diverter knife valv% function none, . k. 'froublah000 and adjust mown seven to desired height Mixing spud mud. Continue welding flashing in cellar. Finish installing drill line kick rollers on drawworks. Continue plumbing in LW line in shaker room. Prep for pre -spud as per pre -spud check list ❑ 000045M Fork lift driver innall catch pan under end of diverter line and moving 13 3/8" casing into pipe shed. Mixing spud mud. Rigging drillfloor for picking up BHA. Function tettdivererbagsndknifevalve. Welder continue weldingflazhing around cellar and cellar 154.0 box. PTSM. Nipple up diverter system, anchor diverter line and set onings bucket under end of diverter line. Finish berming cuttings mak and instill key stock in elevator pias. Weld d6ilinglinekickba&mllersondmwworksandweldotallarbox. Continuemixing600 bible spud mud, remove thread prototms from 13 3/8" casing in pipe shed, and bring up x- 154.0 over and stabilizer to ng Floor for BHA. 154.0 Continue welding Flashing on cellar box and ng up teller pump. 1540 Simulate diverter evacuation drill and man down drill with EM and support crews. 154.0 Change out leaking o -ring on top drive. PTSM. Pick up stand of drillpipe, function Hydril and diverter knife valve for John Crisp (Alaska Some Man). Bag closed in 35 swords and knife valve opened in 20 nowns. Draw down ted at Korey unit 2 minutes 20 seconds. Function test fireal rms, gas denounces, 154 0 and PVT alarms. Attempt to function teat PM on Epoch/rig watch. Troubleshoot and repair system as per 154.0 Gan, 154.0 Fill surface suck with water, knife valve leaking, drain suck. 154.0 Simulate diverter evacuation drill and man down drill with EN1 and support crews. Troubleshot leukin¢ diverter knife valve.❑ 00000500 Troubleshot and repair diverter knife valve. Fill stack with water, no looks, 154 0 check flow sonar, o.k. Prepare to rig up Gyro Dau wireline and pickup BHA. Fill naer with water, diviner knife valve leaking. Clean suction screens on number 1 and 2 115.0 mud plumps. Nipple down diverter knife valve from diverter spool, clean, repair, and nipple back up to I 15 .0 diverter sppol. 115.0 Fill risen with water, check for lake, all o.k. 115 0 Blow down drill water transfer pump line and clean suction scream on N2 mud pump. 115.0 Hang Schlumberger wireline shave, make up Gym Dau tools and test. 115 0 Make up BHA pl. Circulate spud mud through mud system to check for leaks and proper alignment, Circulme 115.0 at 40 apm and 165 Spm. 163 0 Drill from 125' to 163' with 30 rpm, 24 wob, 130 psi, and 350 spm. 163.0 Pull out of hole with BHA 41 and lay out. 163 0 Pick up BHA 92 and ran in hole. Drill from163'te 346' with 30 rpm, 44 wob, 495 psi, and 504 gpm. Survey at 179'and 241'.❑ 346.0 00000500 Continue doll and survey from 346to 501'. 125 0 Ream end wash down from 115'to 125' with 30 rpm, 24 wob, 350 spm and 130 psi. DNI farm 317' to 594' with 590 gpm, 890 psi, 25 rpm, 25-30k wee, 3,51, torque. 3.4 bra; 594.0 actual drlg time, 1.9 him actual slide time, and 1.5 bra actual route time. Trip of of hole, ley down three joints of HFIi stand back four stands of HWDP with 594.0 jars. Lay down BHA, and stand back non-magnetic drill collar. 594 0 Pick up BHA 4 3. D N steel a used for sundin Cols on a throw h h le in m r b in (Note, these holes are in roamer hushings used for kefly drive bushings). Notify Anchorage and cell 594.0 out Baker fishing lois. 594.0 Pull of of hole, lay down BHA, and prepare to pick up fishing tools. 594.0 Load drillfloor with Baker fishing tools. Clea cellar area, looking for peg. Make up 14" magnet, bit sub, and x -over, me in hole with 5" ddllpipe, teg up at 485' with 5940 IOk down. 9 000 600 6.00 PREP A 1.00 P 154.0 9 600 930 3.50 PREP A 100 P 1540 9 930 11'00 1.50 PREP A 100 P 154,0 9 1100 1200 1.00 PREP A 1.00 T 154.0 9 4.00 PREP A 100 P 1540 12:00 1600 9 1600 1830 250 PREP A I'M T 154.0 9 1830 21.30 3.00 PREP A 100 T 154F 9 21:30 2300 1.50 PREP A 1.00 P 1540 9 23:00 000 1.00 PREP A 1.00 T 154.0 10 0 D 1:00 100 PREP C 100 P 115.0 10 1:00 400 3.00 PREP H IN T 1150 10 400 430 0.50 PREP C 1.00 P 1150 10 430 500 0.50 PREP C 1.00 P 115.0 10 500 900 4.00 PREP A 1,00 P 1150 10 9:00 11:30 2.50 PREP A 1.00 P 115.0 i 1 I 10 11:30 1230 1.00 PREP A 100 P 115,0 ��p 10 1290 14:00 1.50 DRILL E 3.00 P 125.0 10 1400 1530 1.50 DRILL E 400 P 163.0 10 1530 19:00 3.50 DML E 400 P 163.0 10 1900 2300 400 DR 1AL E 3.00 P 1630 10 23:00 0:00 100 PREP E 1.00 P 1150 11 000 830 9.50 DRILL E 300 P 3170 11 8'30 1200 3.50 DML E 4.00 P 594.0 11 1200 15:00 3.00 DRILL E 400 P 594.0 y / 11 15'00 16:00 100 DRILL E 20M T 594.0 11 1600 1830 2.50 DRO.L E 4.00 T 5940 11 18:30 21:00 250 DWLL E 2000 T 594.0 11 21.00 22:00 1.00 DRB,L E 4.00 T 594.0 PTSM. Continue nipple up surface stack, connect flow line, bleeder line, and hole fill line. Secureauawithmmbuckles. Anchordown diverter line. Plumb nandconoect Kooma control lines to diverter knife valv% function none, . k. 'froublah000 and adjust mown seven to desired height Mixing spud mud. Continue welding flashing in cellar. Finish installing drill line kick rollers on drawworks. Continue plumbing in LW line in shaker room. Prep for pre -spud as per pre -spud check list ❑ 000045M Fork lift driver innall catch pan under end of diverter line and moving 13 3/8" casing into pipe shed. Mixing spud mud. Rigging drillfloor for picking up BHA. Function tettdivererbagsndknifevalve. Welder continue weldingflazhing around cellar and cellar 154.0 box. PTSM. Nipple up diverter system, anchor diverter line and set onings bucket under end of diverter line. Finish berming cuttings mak and instill key stock in elevator pias. Weld d6ilinglinekickba&mllersondmwworksandweldotallarbox. Continuemixing600 bible spud mud, remove thread prototms from 13 3/8" casing in pipe shed, and bring up x- 154.0 over and stabilizer to ng Floor for BHA. 154.0 Continue welding Flashing on cellar box and ng up teller pump. 1540 Simulate diverter evacuation drill and man down drill with EM and support crews. 154.0 Change out leaking o -ring on top drive. PTSM. Pick up stand of drillpipe, function Hydril and diverter knife valve for John Crisp (Alaska Some Man). Bag closed in 35 swords and knife valve opened in 20 nowns. Draw down ted at Korey unit 2 minutes 20 seconds. Function test fireal rms, gas denounces, 154 0 and PVT alarms. Attempt to function teat PM on Epoch/rig watch. Troubleshoot and repair system as per 154.0 Gan, 154.0 Fill surface suck with water, knife valve leaking, drain suck. 154.0 Simulate diverter evacuation drill and man down drill with EN1 and support crews. Troubleshot leukin¢ diverter knife valve.❑ 00000500 Troubleshot and repair diverter knife valve. Fill stack with water, no looks, 154 0 check flow sonar, o.k. Prepare to rig up Gyro Dau wireline and pickup BHA. Fill naer with water, diviner knife valve leaking. Clean suction screens on number 1 and 2 115.0 mud plumps. Nipple down diverter knife valve from diverter spool, clean, repair, and nipple back up to I 15 .0 diverter sppol. 115.0 Fill risen with water, check for lake, all o.k. 115 0 Blow down drill water transfer pump line and clean suction scream on N2 mud pump. 115.0 Hang Schlumberger wireline shave, make up Gym Dau tools and test. 115 0 Make up BHA pl. Circulate spud mud through mud system to check for leaks and proper alignment, Circulme 115.0 at 40 apm and 165 Spm. 163 0 Drill from 125' to 163' with 30 rpm, 24 wob, 130 psi, and 350 spm. 163.0 Pull out of hole with BHA 41 and lay out. 163 0 Pick up BHA 92 and ran in hole. Drill from163'te 346' with 30 rpm, 44 wob, 495 psi, and 504 gpm. Survey at 179'and 241'.❑ 346.0 00000500 Continue doll and survey from 346to 501'. 125 0 Ream end wash down from 115'to 125' with 30 rpm, 24 wob, 350 spm and 130 psi. DNI farm 317' to 594' with 590 gpm, 890 psi, 25 rpm, 25-30k wee, 3,51, torque. 3.4 bra; 594.0 actual drlg time, 1.9 him actual slide time, and 1.5 bra actual route time. Trip of of hole, ley down three joints of HFIi stand back four stands of HWDP with 594.0 jars. Lay down BHA, and stand back non-magnetic drill collar. 594 0 Pick up BHA 4 3. D N steel a used for sundin Cols on a throw h h le in m r b in (Note, these holes are in roamer hushings used for kefly drive bushings). Notify Anchorage and cell 594.0 out Baker fishing lois. 594.0 Pull of of hole, lay down BHA, and prepare to pick up fishing tools. 594.0 Load drillfloor with Baker fishing tools. Clea cellar area, looking for peg. Make up 14" magnet, bit sub, and x -over, me in hole with 5" ddllpipe, teg up at 485' with 5940 IOk down. Stan F4M no -r, Phase Op Code Su_ _title auT Stairs (ft) Rnd(Ft) Cotnmevet 11 22'00 23'.00 100 DRILL E 1900 T 594.0 . op mue up, wasp met rmme past mage won is rpnk no spm, n gpm, 594 0 hole, wash down to 594', bottom fon, shut down circulation. Pullout of hole with fishing assembly. Nofish.= (Nae, build berms and move mechanic shop and Toolpusher trailer from Air Force pad to OPP. Put a top on cuttings tank and install steam to steam lines).❑ WOO -0200 Prepare and pickup Globe junk basket, x -overs and HWDP. Nabors Tongs unable to go around 16" Globeshcebasketcormection. ❑ 594.0 0200-OSM Waiting on tongs from Baker oil tool. Service rig. 594.0 Lay down BHA, stood back stand of HWDP, clear drillt3oor of dl fishing BHA. Pick up 1 joint of HWDP, make up x -overs, and pick up Globejunk basket Nabors tongs 594 0 unable to go around 16" basket to lighten basket shoo. While waiting on tongs enmute from Deadhorse, service top drive, crown, and drawwurks. 594.0 Clean rod wash boxes on mud Pumps. Rig up Baker Oil tool tongs, lighten connections an Globe basket and make upjoint of 594.0 HWDP. Trip in hole with 5" drillpipe, tag up at 475', make up top drive, wash and ream to 594' with 594.0 20 in, 60 spm, and 41 psi. 596.0 Cut core with Globe baskn to 596' with 24k wob. 596.0 Trip out of hole from 596'. Lay down BHA and 2joints ofHWDP, break down Globe basket, remove core, no fish 596.0 raovery. 596,0 Clear drillRoor of f shing cools and clean. 596.0 Grease dmwworks brake linkage. Make up Baker reverse circulatingjunk basket and trip in hole to 482', teg up wits 1% 596 0 down, top drive up and wash down to 596 with 17 rpm, 45 psi, and 279 Rpm. 601 0 Milling to 601' with 1-2k with, 27 psi, and 93 gpm. 601.0 Trip out of hole, lay down fishing BHA, no Junk recovery. Clean drillFloor. 601.0 Pickup 16" bit, ambiliuq x -over, and stand of HWDP. Run in hole, tag up at 482'. 601.0 Makeup top drive, wash and ream w 601' with 600 gpm, 142 spm, 470 psi and 10 rpm. Drill fmm 60l't9615' with798 gpm, 800 psi, 188 spm, 40-100 rpm, and 2-15k wob. Drilling o.k. no indication of drilling on junk. Backreamupenddowaseveraldmeswhile 615.0 drilling to 615' with no indications ofjunk below bit. Trip out of hole, lay down BHA, wash 16" bit and check for any indications of conning on junk. Bit o.k. clean drillFloor. ❑ 615,0 0ON4500 Run in hole with drilling BHA, drill to 647'. 615.0 Pick up BHI, upload MWD and check orientation. 615.0 Trip in hale, shallow test MWD with 700 put and 1,000 peri. Drill from 615' in 93P with 40 rpm, 700 gpm, 1,430 psi, 166 spm, and 30-35k wob. Gyro 9310 survey at 738'. 931.0 Run Gym survey at 928', rig down Gyro wireline. Drill and alide from 93 V to 1,550' with 700 Bpm, 1,500 psi, 166 spm, 40 rpm, 30-351, wob. 1,550.0 PN weight 95k, DN 93k, 3,000k torque on bottom, off button 1 900k. Survey every nand. Trip out of hole, to orientate motor and pick up stababove motm to build angle, from 1.550 0 1,550 to 834', monitor hole, proper displacement, and no swabbing. TH, out othe], rack back HWDPMC. Download MWD, ley down MWD and stab. 1550.0 Orientate mown from 1.5" to 1.8" Pick up BHA, new MWD and nabiliaer❑ 1,5500 0000-0500 Pick up BHA, upload MWD, ron in hole. 1,5500 Picking up BHA upload MWD. 1 550.0 Service ng, adjust brake bands on drawworks. Run in hole with BHA pick up stand of 5' drillpipe and shallow test MWD with 1000 Um 1,550.0 and 1,260 psi. Blow down top drive. 1,550.0 Continue con in hole to 1,520', make up top drive. 1,890 0 Drill from 1,550' to I,890'. 1,890.0 Circulate bottoms up to clean hole with 700 gum, and 1,375 psi. Drill from 1,890'to 2,191' with 30-35k wob, 1,900 pat, 800 Rpm, 5,5001, torque on bottom, 2,191,0 4,500k off him. I ISk pickup, 1001, down and I IOk rotate weight. 2,191.0 Camig troubleshoot chemicial problems on top drive. 2,358.0 Drill from 2, 191'to TD at 2,358'. TVD 2.163'. 2,358 0 Wiper trip from 2,351834', RIH, no hole problems or restrictions. Circulate and condition hole with 787 gpm, and 1,795 psi. Pump nutting sweep and cim 2,358.0 out. Pull 4 stands out of hole, blow down top drive. ❑ 2,358.0 0000-0500 POOH, lay out BHA, and make dummy min with landingjoint. 2,358,0 Pull out of hole than 1,986'. 2,35&0 Stand back HWDP and lay down BHA. 2,358 0 Rig up 13 3/8" casing equipment. 2,358.0 Make dummy con with 13 3/8" casing hanger. Measured at3T RKB. 11 2300 0:00 100 DRILL E 4.00 T 594.0 12 0.00 0:30 0.50 DRILL E 400 T 5940 12 030 200 1.50 DRILL E 400 T 594O 12 200 530 3.50 DRILL E 23.00 T 594.0 12 5:30 700 1.50 DRILL E 400 T 594.0 12 700 830 1.50 DRILL E 400 T 594.0 12 830 930 I.00 DRILL E 10,00 T 594.0 12 9:30 11.00 1.50 DRILL E 4.00 T 5%.0 11 12 11:00 12:00 1.00 DRILL E 4.00 T 596.0 �� 12 1200 1300 1 00 DRILL E 20M T 596.0 12 13:00 1330 0.50 DRILL E 20.00 T 5960 12 1330 1430 I. W DRILL E 4,00 T 596.0 12 1430 1530 1.00 DRILL E 1400 T 596.0 12 15:30 1800 250 DRILL E 4.00 T 601.0 12 1800 2000 200 DRILL E 4.00 T 60LO 12 2000 21'30 1.50 DRILL E 1900 T 6010 12 21:30 2200 0.50 DRILL E 300 T 601.0 12 2200 000 2.00 DRILL E 400 T 615.0 13 0:00 400 400 DRILL E 400 P 615.0 13 400 4:30 0.50 DRILL E 4.00 P 6150 13 430 1000 5.50 DRILL E 3.00 P 615.0 j { 13 10:00 10:30 0.50 DRILL E 1900 P 9310 13 10:30 17:30 7.00 DROLL E 3.00 P 931.0 13 1730 1900 1.50 DRILL E 400 P 1,5500 13 1900 22:30 3.50 DRILL E 4.00 P 1,5500 13 2230 000 150 DRILL E 4.00 P 1,5500 14 000 130 1.50 DRILL E 400 P 1,550.0 14 1:30 230 1.00 DRILL E 20.00 P 1,5500 14 230 430 200 DRILL E 400 P 1,550.0 14 430 500 0.50 DRILL E 400 P 15500 y 14 500 900 400 DRILL E 300 P 1,550.0 14 g:00 10:00 1.00 DRILL E TM P 1,8900 14 1000 1400 4.00 DRILL E 3 00 P 1,890.0 14 14:00 15:00 100 DRILL E 2000. T 2,191.0 14 1500 1800 3.00 DRILL E 300 P 2,191.0 14 1800 20.30 250 DRILL E 4.00 P 2,358.0 14 2030 2300 2.50 DRILL E 100 P 2,3580 14 2100 000 100 DRILL E 400 P 2,358.0 is 000 230 2.50 DRILL E 4.00 P 2,358.0 15 2:30 630 4.00 DRILL E 4.00 P 2,3580 15 030 11:00 450 DRILL E 20.00 P 2,358.0 15 1100 1200 1.00 DRILL E 20.00 P 2,3580 . op mue up, wasp met rmme past mage won is rpnk no spm, n gpm, 594 0 hole, wash down to 594', bottom fon, shut down circulation. Pullout of hole with fishing assembly. Nofish.= (Nae, build berms and move mechanic shop and Toolpusher trailer from Air Force pad to OPP. Put a top on cuttings tank and install steam to steam lines).❑ WOO -0200 Prepare and pickup Globe junk basket, x -overs and HWDP. Nabors Tongs unable to go around 16" Globeshcebasketcormection. ❑ 594.0 0200-OSM Waiting on tongs from Baker oil tool. Service rig. 594.0 Lay down BHA, stood back stand of HWDP, clear drillt3oor of dl fishing BHA. Pick up 1 joint of HWDP, make up x -overs, and pick up Globejunk basket Nabors tongs 594 0 unable to go around 16" basket to lighten basket shoo. While waiting on tongs enmute from Deadhorse, service top drive, crown, and drawwurks. 594.0 Clean rod wash boxes on mud Pumps. Rig up Baker Oil tool tongs, lighten connections an Globe basket and make upjoint of 594.0 HWDP. Trip in hole with 5" drillpipe, tag up at 475', make up top drive, wash and ream to 594' with 594.0 20 in, 60 spm, and 41 psi. 596.0 Cut core with Globe baskn to 596' with 24k wob. 596.0 Trip out of hole from 596'. Lay down BHA and 2joints ofHWDP, break down Globe basket, remove core, no fish 596.0 raovery. 596,0 Clear drillRoor of f shing cools and clean. 596.0 Grease dmwworks brake linkage. Make up Baker reverse circulatingjunk basket and trip in hole to 482', teg up wits 1% 596 0 down, top drive up and wash down to 596 with 17 rpm, 45 psi, and 279 Rpm. 601 0 Milling to 601' with 1-2k with, 27 psi, and 93 gpm. 601.0 Trip out of hole, lay down fishing BHA, no Junk recovery. Clean drillFloor. 601.0 Pickup 16" bit, ambiliuq x -over, and stand of HWDP. Run in hole, tag up at 482'. 601.0 Makeup top drive, wash and ream w 601' with 600 gpm, 142 spm, 470 psi and 10 rpm. Drill fmm 60l't9615' with798 gpm, 800 psi, 188 spm, 40-100 rpm, and 2-15k wob. Drilling o.k. no indication of drilling on junk. Backreamupenddowaseveraldmeswhile 615.0 drilling to 615' with no indications ofjunk below bit. Trip out of hole, lay down BHA, wash 16" bit and check for any indications of conning on junk. Bit o.k. clean drillFloor. ❑ 615,0 0ON4500 Run in hole with drilling BHA, drill to 647'. 615.0 Pick up BHI, upload MWD and check orientation. 615.0 Trip in hale, shallow test MWD with 700 put and 1,000 peri. Drill from 615' in 93P with 40 rpm, 700 gpm, 1,430 psi, 166 spm, and 30-35k wob. Gyro 9310 survey at 738'. 931.0 Run Gym survey at 928', rig down Gyro wireline. Drill and alide from 93 V to 1,550' with 700 Bpm, 1,500 psi, 166 spm, 40 rpm, 30-351, wob. 1,550.0 PN weight 95k, DN 93k, 3,000k torque on bottom, off button 1 900k. Survey every nand. Trip out of hole, to orientate motor and pick up stababove motm to build angle, from 1.550 0 1,550 to 834', monitor hole, proper displacement, and no swabbing. TH, out othe], rack back HWDPMC. Download MWD, ley down MWD and stab. 1550.0 Orientate mown from 1.5" to 1.8" Pick up BHA, new MWD and nabiliaer❑ 1,5500 0000-0500 Pick up BHA, upload MWD, ron in hole. 1,5500 Picking up BHA upload MWD. 1 550.0 Service ng, adjust brake bands on drawworks. Run in hole with BHA pick up stand of 5' drillpipe and shallow test MWD with 1000 Um 1,550.0 and 1,260 psi. Blow down top drive. 1,550.0 Continue con in hole to 1,520', make up top drive. 1,890 0 Drill from 1,550' to I,890'. 1,890.0 Circulate bottoms up to clean hole with 700 gum, and 1,375 psi. Drill from 1,890'to 2,191' with 30-35k wob, 1,900 pat, 800 Rpm, 5,5001, torque on bottom, 2,191,0 4,500k off him. I ISk pickup, 1001, down and I IOk rotate weight. 2,191.0 Camig troubleshoot chemicial problems on top drive. 2,358.0 Drill from 2, 191'to TD at 2,358'. TVD 2.163'. 2,358 0 Wiper trip from 2,351834', RIH, no hole problems or restrictions. Circulate and condition hole with 787 gpm, and 1,795 psi. Pump nutting sweep and cim 2,358.0 out. Pull 4 stands out of hole, blow down top drive. ❑ 2,358.0 0000-0500 POOH, lay out BHA, and make dummy min with landingjoint. 2,358,0 Pull out of hole than 1,986'. 2,35&0 Stand back HWDP and lay down BHA. 2,358 0 Rig up 13 3/8" casing equipment. 2,358.0 Make dummy con with 13 3/8" casing hanger. Measured at3T RKB. Reportd r Stant End Zr, PRau OF Code Sub -Code Start Qt) End(Pt) Comments )TNT 15 1200 1300 1.00 DML E Z0,00 P 2,358.0 2,358 0 Move centralizers to dg flow and continue rig up to run casing. 15 1300 13:30 0.50 DRILL E 2000 P 2,3580 2,3580 Pre -task safety mating. 15 1330 18:00 4.50 DRILL E 13.00 T 2,358.0 2,358.0 Blew hydraulic hone on stabbing board. Replace hose. 15 1800 220 4.0 DRILL E 19.00 P 2,3580 2,3580 Run 133/8- asingm 1,036', filling everyjoint RecorCyickupandslackoffevery5joims. 15 22;0 22:30 0.50 DRILL E 7.00 P 2,358.0 2,358.0 Circulate at 1,036with 200 gpm and 200 psi. Pickup 100k and slack ofT85k. Full retums. Run 13 3/8" casing to 1,78T.❑ 0 0000-0130 Circulate❑ 01304230 Blew "0" ring on pressure regulator on power tongs, could not repaiq changr Cut tongs 02300400 Run 13 3/8" casing [02,281'.❑ 15 22:30 000 1,50 DRILL E 19,00 P 2,358.0 2,358.0 04000500 Pipie skate broke down, repair same. 16 000 1:30 1.50 DRILL G 7.00 P 2,358.0 2,358.0 Cire / cond fluids. 220 psi / 195 gpm, up 150, do 120 16 1:30 230 1.00 DRILL G 25 W T 2.358 ,0 2,358 0 Blown "0" ring GBR erg tongs. Replace tongs. 16 230 40 150 DRILL G 400 P 2,3590 2,358.0 Resume RIH 13-3/8 cs& 1865 - 2281 ft 16 40 5100 1.00 DRILL G Z00 P 2,358.0 2,358 0 Circ / cond fluids 150 psi 1203 gpm, up 170, do 130 16 500 800 100 DRB,L G 400 P 2,358.0 2,358.0 PU two 10 ft pups, two 511 pups, wash dn, tag load shoulder. Shce 2350 ft. 16 B:00 930 1.50 DRILL G 2500 T 2,3580 2,358.0 Flow line repairs, h, pulled bell nipple from stuck. 16 9:30 140 450 DML H 7.00 P 2,3580 2,358.0 Cim / cond fluids, PISM, RN Caw hit, cont circ / cond fluids in prep for Can job. \� PJSM, Commence cart 13-3/8 erg: Pump 10 bids pre flush, test lines 4000 psi, pump 100 bbl mud push, drop him plu& mix / pump 454 bbls 107 pill lead slurry, observed dye in Jmud push, switched to tail slurry, pumped 73 bbls of 12 ppg Lite CRETE cement. leaving top ofuil @ 1936, displace with rig pumps ® 5 bpm, bumped plug, held 900 psi. for 5 16 1400 1800 4 00 DRILL H 9,00 P 2,358fl 2,358.0 minsfloats held. CIP at 17M hours. Nipple up /down diyerter. Clean phs. Remove Cement head. Lay down landing joint Clean Floor and cellar. Blow, down mud lines.❑ 16 180 0'00 600 DRILL C 500 P 2,3580 2,358.000000500: Continue to clean pits, mud tanks and rig floor. PISM, Nipple do BOPE, remove flowline, fillup line, riser remove flowline from utility side wall, place on landingwash annular, remove diverter lines / knife valve from cellar. PJSM, R/D scaffolding. Tie on to annular, break bolts leaving two in piece. Space limitations prevent forklift from reaching annular. RIU slings to blocks. Till annular out of Cellarwith + •`1� rig blacks and forklift. Remove riser spool. Remove wellhead. Clean / inspect same.❑ 7❑ II ❑ 0:0 000 24.00 DRILL C 2000 P 2,3580 2,358.0 0000-0500 Prep /install Vince Mulfibowl wellhead . Test 5000 psi PISM, install Veten 13-5/8 5K nutritional wellhead. Test to 5000 psi 10 min. Test is 000 5:0 5.00 DRB.L C 20.00 P 2,358.0 2,3580 successful, no re -teats. 18 5:00 1630 1150 DRELL C 20.00 P 2,3580 2,358.0 PJSM, nipple up 13.5/8 5K DOPE, all related equipment. `1 Iy 18 1630 1800 1.50 DRE.L C 20.00 P 2,358.0 2,358.0 FISK erect scaffolding in upper BOP area. p� PJSM, resume nipple up BOPS, hammer up bolts while prepare choke and kill lines for insmlladon.❑ IB 1800 0:0 6.00 DRILL C 20.00 P 2,358.0 2,358 0 0000 - 0500 Torque up BOP bobs, prepareinstall ckoke and kill lines. 19 0:00 8:30 850 DRJ.L C 20.00 P 2,3580 2,3580 Continue nipple up BOPS, arrange cellar arca. 19 830 1330 5.130 DRILL C 20.00 P 2,358.0 2,358.0 PISM, arrange scaffolding to BOP. Resume nipple up BOPE peripherals, mmbuckles. Open ram doors, inspect for condition 19 1330 1800 4.50 DRB.L C 20,00 P 2,358.0 2,358.0 and propMy sized ram blocks.Inna11 flow nipple, Flow line, Fill up lines, and bleed line. P15M, commence test BOPE, all related equipment: Insure annulus valve open below but l plug seat. Make up test plug to tat joint, ser test plug. Fill BOP stack choke manifold, kill I__!� 19 18:00 22:0 4.0 DRILL C 12.00 P 2,358.0 2,3580 lines with water. Prepare test ROPE. PISM, attempt full body ten DOPE and choke manifold. Chart recorder malfunction, Tmubleshoot recorder. Choke flange leaking. Tighten sem e. ❑ 00 to 0600: Test top set rams and Hydril. Good tests. Discovered hydraulic leak in 19 2200 000 2.0 DRILL C 1300 T 2,3590 2,358.0 Hydril single gate body. PISM, resume attempt ten HOPE, valve bonnet assembly laking on choke valves 91 & d7. Tighten same. Connect control hoses to HCR valve kill line side. Test rams, manifold, floor valves. Discover hydraulic leak at lower pipe ram body. Can not repair in field. Decision to replace. Other planned repairs include: Change out "union" on kill line with Flanged connection, choke position indicator, choke conte[ air pump will not case running, choke 20 000 430 4.50 DRILL C 12.00 T 2,3580 2,3580 Control pressure gauge not reading pressure. PISM, Nicole down BOPE. all related eeuinment. Set Cut leaking ram body. Prepare load 1 20 I 430 1730 13.0DRI1.1, C 5.00 T 2,358.0 2,3580outforrepairs. X0 PJSM, Take delivery new BOP ram set. Install same, dress with proper ram sized function tat, commence nipple up remainder ROPE, all related equipment) 20 17'30 000 6.50 DRILL C 50 T 2,358.0 2,358 0 000-0500 Erect scaffolding. Nipple up BOPE 21 0:00 3:30 3.50 DRILL C 5.00 P 2,358.0 2,3580 Complete nipple up BOPE, connect 91 plumbin&ill related equipment. Report# Start End Phase Op Code Sub -Code P0T Sert(ft) End (Ft) Comments first PJSM, ng up and test BOPE, all components, poor valves, top drive valves, lines end valves floor to pumps. Test annular to 250 psi low / 35M psi high. Teat remainder components 250 psi low / 5000 pai high. 5 minutes per test Perform ume vo ume pressure test accumulator rystem. Ten successful. All repairs from previous test complete. Rig down ten equipment, blow down lines. ❑ tn 21 \1 1\ An 3:30 1530 120RR, 0 DL C 12 00 . P 2,358.0 2,358.0 Test witness by Mr Bob Noble AOGCC, PJSM, Handle dirt] pipe in mast. Replace damaged pipe. Rcanfinge drill pipe, pick up 51 21 1530 2330 8.00 EXULL E 20.00 P 2,358.0 2,358.0 joints from pipe and. POH, stand back 51 joints in mast for drill out. PJSM, Rig up for test 13-3/8 casing a 21 2330 000 0.50 DRML E 12.00 P 2,358.0 2,358.0 0000 - 0500 Test 13-3/8 es, to 2500 psi, Prepare end assemble BHA 03 22 090 230 2.50 DRILL E 1200 P 2,358.0 2,358.0 PJSM, tat 13-38 csg 2500 psi / 30 min. Tess[ successful. PJSM, Piece nuke sours to rig floor, make up BHA #3, attempt RBI same. Tag 22 230 8:30 6.00 DML E 4.00 P 2,358 0 2,358,0 obstruction approximately 40 ft. 22 8:30 1000 150 DRLLL E 1300 T 2,358.0 2,358.0 Snag bit at flow nipple. Repair flow nipple/flow line. 22 1000 1290 2.00 DRILL E 400 T 2,358 0 2,358.0 Resume anempt pass obstruction at 40 ft. Can not peas. 1`I 22 1200 1300 LOO DRILL E 25.00 P 2,358.0 2,35&D PJSM,smica rig/top drive. Ind Order string mill, take delivery ofeame, install mill, RIH to obstruction. Mill / clean out tight 13-3/8 using ouo joint connection. Take no noticeable weight. Corm 7-M 22 1300 17:30 4.50 DRILL E 13 00 T 2,358.0 2,358 0 away. POH, lay dawn mill. Clear floor. 22 17:30 20:00 2.50 DRILL E 25 00 U ? 358.0 2,358.0 PISM, change Out saver sub at top drive. 22 2000 2100 I.W DML E 1200. T 2,358.0 2,358,0 PISK re -test 13-3/8 casing 2500 psi / 30 min. Two successful PISM, resume make up BHA 43Z 22 2100 000 300 DML E 4.00 P 2,358.0 2.358.00000-0500 Handle BHA #3, RIH, surface test directional vry. 23 0:00 230 2.50 DRILL E 20.00 P 2,358d 2,358.0 Continue Make up BHA #3, RIX same. 23 230 4:00 1.50 DRILL E 7.00 P 2,3580 2,3580 Condition viscous wellbore fluids, surface test MWD/LWD. 23 400 530 1,50 DRILL E 4.00 P 2,358.0 2,358.0 Insall ghost reamer following BHA. 23 5:30 630 100 DRILL E 400 P 2,358.0 ?358.0 Follow BHA with 5" drill pipe to 1056 ft. 23 630 730 1.0 DRML E TOO P 2,358.0 2,3580 Circulate/ condition drill fluids. 23 730 830 100 DRILL E 400 P 2,358.0 2,358.0 RAH 5" drill pipe to 1620 ft. 23 830 9:00 0.50 DML E 7.00 P 2,358 D 2,358.0 Circulate / condition drill fluids. \� 23 900 1100 200 DRLLL E 4.00 P 2,358.0 2,358fl RIH 5" drill pipe W 2203 ft I Wash to 2053 ft. Tag conenimated cement above float collm.(2265 fl). Drill float collar, 80 J ft densemment in shoe track, drill guides oe az 2349 p. and 8 n eve cement rat hole. 650 23 1100 1690 5.00 DRUL E 7.00 P 2,3580 2,3580 gum/1250 psi/70 rpm/4-7K WOB. Drill ahead 12-1/4 hole 2359-2393 Flute, formation, Cuttings returns at 20 ft 5% new 23 16:00 1630 0.50 DRILL E 300 P 2,358.0 2,393.0 formation f95 % cement. Drill additional 15 ft with 100%formation returns 23 1630 1930 3.00 DRILL E TOO P 2,3930 2,3930 Circulate/condition fluids/clean new formation for LOT. 23 1930 2030 1 W DRILL E 1200 P 2,393.0 2,393.0 PJSM, perform LOT: resulting in 111 EMW (8 9 ppg fluid 5 spm, 334 psi surface press) 23 2030 2230 2.00 DML E 9.00 P 2,3930 2,393,0 PJSM, offload trucks with oil base mud, clean surface equipment, clean pits. ence displace wellbore with o'1 base mud. 3 bpm / 65 psi. 60 rpm for fluid 23 2230 000 1.50 DRILL E 9.011 P 2,393fl 2,393.0 consistancy. 24 000 1:30 1.50 DR E 9.00 P 2,393,0 2,393.0 Displace water base mud in wellbore with Versa Pro oil base fluids. Continue clean pits, flush ill lines, clean shaker area, change shako screens, clean mud pump screens, install drip pan beneath romry table, take on bulk ail base fluids to pits from 24 1:30 1500 13.50 DRILL E 8.00 P 2,3930 2,393 0 trucks. 24 15'00 1630 150 DRR,L E 200 P 2,393.0 2,393.0 Circulate wellbore /surface volume, equalize all fluids. 600 gpm / 1320psi. PJSM, ce9rfonn LOT with ail base fluids. 2 ppg 5 bpm, 316 psi surface pressure resuWng 24 1630 18:00 1.50 DRILL E t200 P 2,3930 2,393.0 in 12#F . Rig down, blow dawn line. �`\ 24 18:00 1900 100 DIULL E 7.00 P 2,393.0 2,393.0 Circulate, establish baseline. Take slow pump razes, MWD baseline =925 ECD FISK drill ahead 12-1/4 hale direc4one12393 - 2872 ft. ❑ 800 gpm, SPP 2180, RPM IN. WOO 10- 15K, Up 125, Dn 100, Rot 113, Torque on bonom 5K, Torque offbMom 4K, ECD 9.6, ADT = 294 hrajms 17.98 hrs. No gain / losses, connections free, normal up / down drag, earnings Tatum normal quantity / quality. Gas "0" units.❑ 00:00- 05:00 Trig f/2872' MD to 428'MD❑ 24 19'00 000 500 DRILL E 300 P 2,393.0 2,872.0 Survey @M6 MD/2W5' TVD -INC -6263, AZI=69.87 Route drilling ahead from 2872 ft Ivm to 3542 ft. MD, RPM=130, WOB=Sk-15k, GPM -681, BPM -16.2, PSI -1813, Ddg.ToMue-5kfik, PU Wr130k,SO Wt=95k, 25 O:OD 630 6.50 DRILL E 3.00 P 2,872.0 3,542.0 ROGWt=110k. At 3542 ft. MD Losing fluid to well. determine loss rate (x1180 BPH, shut down pump mediately and flow check- fluid level in seek drooped out of sight in seconds. POOH 25 6'30 7:30 I.00 DRILL E 7.00 T 3,5410 3,542 0 from 3542 ft. to 3348 ft. 1� At 3348 ft. MD work pipe and circulate at 5 BPM with 220 PSI, Establish loss rate (ja 30 f 25 730 930 200 DRILL E 200 T 3,542.0 BPH. mix 25 BELS LCM pill of #40 micron salvo rb at 20 PPB end pump pill, spot LCM 3,542.0 Out bit @3348 ft. down pill and shut pump. POOH from 3348 ft. W 3255 ft. work pipe & circulate @5 BPM with 225 PSI while building volume in active system back up by adding 8.3 PPG OBM, and mixing 440 micron safecmb LCM to entre mud system W 5 PPB, OK -Lasses stopped/stable at 11:30 an. 25 9:30 13:00 3.50 DRILL E 7,00 T 3,542.0 3,542.0 nage up pump rest from 5 BPM to 12 Rpm, OK -no Imens table. Time Re" X Start End /lave) Phase Op Code Srau ,ado P -N -T Stan (ft) Rod (Ft) Cannonade;1 030 Flow check on conisation- static, Begin washing in hole from 3255 R. MD to Bottom a 19.00 DRILL E 3542 ft. MD, staging up pump rate on each stand from 7- 1213PM with -out may, losses -OK, P at 3542 A. stage up pump rate to 19 BPM (Drlg.Rate) wits 2515 PSI, RPM=125, Torque 29 00 Btm=5600 Mbs, PU Wt=130k, SO Wt—=95k, Rot Wt=110k, PVT ®516 BBLS, OK No 19:30 Losses/Stabla, Take new slow pump rata with 9.2 PPG mud Wt. in & out (Note.Total 25 1300 1530 ? 50 DRILL E 7.00 T 3,542 0 3,542 0 Losses at 270 BBLS) P Drill ahead 12-1/4 hole directional 3542 - 4410 ft. ❑ 29 \� GPM 754, SPP 2400, ITP 140, DN 100, ROT 115, WOB 10-12, "M120, TQ On 7, 000 TQ OFF 6, ECD 9.8, GAS "0"units, ADT -5.19 hos, No gain /loss, connections One, 25 1530 2330 8 0 DRILL E 3.00 P 3,5420 4,404.0 cuttings normal. P SAFETY STAND DOWN, BOTH CREWS, ALL SUPPORT PERSONNEL.❑ I� 29 Topics: Monitoring flow / gain / loss, gas alerms. Most back up electronic monitoring with 1:00 visual, reporting all incidents (minor & major).❑ 100 DRILL E 7.00 P 06 00 AM Depth®4883 MDC 29 Survey Depth®4714' MI), 3241' TWO 200 INC 6162❑ 2,50 DRILL E AZI 23 85❑ T 6,045.0 25 2330 0:00 0.50 DRE.L E 20.00 P 4,404.0 4,4040 ECD@9.6 with 700 gpm 430 SAFETY STAND DOWN, BOTH CREWS, ALL SUPPORT PERSONNEL 0.50 DRILL E Topics: Monitoring flow /gain / loss, gas slarms. Must back up electronic monitoring with 26 000 030 0.50DRIL1. E 20.00 P 4,404.0 4,404.0 visual, reporting all incidents (minor & major) . 28 26 030 1930 19.00 DRILL E 700 P 4,404.0 29 26 19:30 000 4 50 DRILL E 7.00 P 6,045 0 29 \� 27 000 1:00 1 00 DRILL E 700 P 6,045.0 I� 29 27 1:00 200 100 DRILL E 7.00 P 6,0450 29 27 200 430 2,50 DRILL E 6.00 T 6,045.0 27 430 500 0.50 DRILL E 600 T 6,045.0 .( 27 500 530 0.50 DRRL E 6.00 T 6,045 0 % 27 530 700 1.50 DRILL E 600 T 6,045.0 27 700 15:00 8.00 DRILL E 600 T 6,045 0 27 15W 1730 2.50 DRILL E 7.00 P 6,045.0 27 1730 1930 2.00 DRILL E 400 P 6,045.0 27 1930 23:00 3 50 DRILL E 4.00 P 6,045 0 27 23:00 0:00 1.00 DRILL E 12 P 6,045.0 28 000 8:30 8.50 DRILL E 12 P 6,0450 28 830 11:00 250 DRJLL E 12 P 6,0450 28 1100 14:00 3.00 DML E 25 P 6,0450 28 14:M 16:00 200 DRILL E 4 P 6,045.0 28 16:00 1800 2.00 DRILL E 4 P 6,045.0 28 1800 1900 100 DRILL E 7 P 6,0450 `- 28 1900 20:00 100 DRILL E 25 T 6,045.0 28 20:M 0:00 4,00 DRILL E 6 P 6,045.0 29 000 230 2.50 DRILL E 6 P 6,0450 29 \� 2:30 9:30 7.00 DRILL E 7 P 6,045.0 I� 29 930 1500 5.50 DRILL E 4 P 6,045 0 29 15:00 18:00 300 DRILL E 4 P 6,045.0 Drill ahead 12-1/4 hole directional "04. 6045 R (Inmrval TD ac ner (:enlnmatln Up 185, Do 105, But 125, WOB 10-12, GPM 800, SPP 2750, Torq on ban 10, Tmq 6,0450 offbton 8. ECD 97, ADT =12 hos, No gain/ loss. Corona, normquantity/quality. v/ Circulate / condition fluids for wiper inp to 13-3/8 shoe. Pump two sweeps. (Low As Hallowed by 30 bbl 11.3 ppg weighted sweep). No additional cuttings raum to shaker. Continue circulate shaker clean. 800 pin / 2750 psi. 130 rpm.❑ n 0000-0500 POH wiper trip. Tight hole 5760-4620. Stock nine at 5380-5285. Work 6,045.0 free. Circulate, resume POH wiper trip towards 13-34 shoe. Continue circulate hole clean, Rotate / reciprocate pip, 6045 4 GPM 80Q PSI 2750. Take 6,045 0 slow pump to, flow check well, smtic. 6,045.0 Lay down One single drill pipe, POH m 5744flow check, pump weight pill. Flow check. PJSM, POH to 5712 tight work vine unaM1le to Deus Make top drive, attempt circulate, packed off Work pipe, regain rotation, pull to 5893, swabbing with over -pull 280K. Stand back stand to mast. Pick upjoint drill pipe in work with. Can not circulatework fro. stand 6,045.0 back stand. Establish circulation, backo urs $298 - 5202, 700 gpm / 2150 Psi, 65 rpm, UP 130K, do 6,045 0 95K, not I I8K. 6,045.0 POH to 4627 ft, swabbing, pull 250- 280K. 6,045,0 Circulate / work pipe, clean wellbore BHA to surface. 715 gpm / 2165 psi. 130 open. Backman to 13-3/8 action shoe at 2350 ft. 850 pin / 2950 psi. Still unable pull on elevators. 25% excess oversize / undrilled cuttings to shakers. Total 19 bbls fluid lm to f umnation while packed off. No lou /gain while fia circulation. Mix Cal Carb on fly during 6,045.0 circulation. Circulate / condition fluids at casing shoe. 850 gpm / 2390 psi. Shaka clean. Pump weight 6,,N15,0 pill, flow check. Fluid column static. 6,0,15o POH to BHA. flow, check. 6,045.0 PJSM, handle BHA #9, lay down BHA, download data, break / grade bit. P1SM, ng up for test ROPE, pull wear bushing, make up test plug.❑ 6,045.0 0000 - 0500 Rig up for HOPE test. Begin test 0430 hrs. PJSM, continue test HOPE / all components, choke manifold, kill / choke lines, top drive MOP, all lines mud pumps to Boor, ell floor valves. Perform time / volume / press test 6,045,0 aammulator. All tests successful, no re -tests. 6,045.0 Rig down HOP test equipment, pull test plug set wear bushing, clear Floor. 6,045.0 PJSM, service ng. 6,045 0 PJSM, flow check, MU clean out BHA #10, RIF same. Flow check. 6,045 0 Follow BHA with 5" drillpipe to 133/8 casing shoe at 2350 ft. 6,045.0 Flow check, circulate / condition fluids 850 pin / 1850 psi. No gain / loss. 6,045.0 PJSM, Repair leaking iron roughneck. Flow check, resume RIH 5" ddllpipa take weight at 3087 ft wash / ream 3087 - 3183 B. 600 gpm / 1650 psi. Resume RIK take weight M 5200 ft. Wash / teem 52M - 5576 ft at and of tour. Minimal cuttings term. No gain / loss.❑ 0000-0500 Continue wash/ream 5576-6045 ft(TOO Necessay re am this interval. 6,045.0 Tight hole. 6,045.0 Continue an / ream 5576 - in TD 6045 ft. 600 gpm / 17W psi. rpm 70. Circulate / condition fluids, increase to 9J ppg, gpm 850, SPP 3000 psi, RPM 60, pump viscous swag no additional cuttings ratom. Pum nut plug m hydraulic tali m, results 5% 6,045.0 washout Spot 60 bbl LCM pill 6045 - 5645 R. to seal p ug mterva . No gain / loss. PJSM, flow check, POH on elevators to BHA, no swab /gain / loss. Normal drag correct 6,045,0 hole fill. 6,045.0 Flow check, handle BHA, lay down clean out assembly. q Stan End n. r Phase Op Code Srs dada n_7' r Start (ft) End (Ft) Comments 29 18:00 0:00 600 DRILL E 12 P 6,045 0 30 000 1:30 150 DRILL E 12 P 6,0450 30 100 5:30 4.00 DRILL E 4 P 6,0450 30 5:30 7:00 1.50 DRILL D 4 P 6,045.0 30 7:00 9:00 2.00 DRILL E 25 T 6,045.0 30 9:00 1000 1.00 DRILL E 4 P 6,045.0 30 1000 1130 1.50 DRILL E 7 P 6,045.0 30 11:30 1430 300 DRILL E 4 P 6,045.0 \� 30 30 14:30 17:00 ITW 17:30 2.50 0.50 DRILL DRILL E H 7 17 P P 6,0450 6,0450 32 1730 18:00 0.50 DRILL F 7 P 6,045.0 30 1730 19:30 2.00 DRILL H 17 P 6,045.0 30 1930 20:00 050 DRILL H 4 P 6,0450 30 2000 2200 2.00 DRILL H 7 P 6,045.0 30 2200 0:00 200 DRILL H 17 P 6,0450 31 0:00 7:30 7.50 DRILL E 4 P 6,0450 31 730 9:00 1.50 DRILL E 25 P 6,045.0 31 9:00 10:30 150 DRILL E 4 P 6,045.0 \��a...., 31 10:30 12:00 1.50 DRILL E 20 P 6,0450 1 3.1 12:00 1230 0.50 DRILL E 25 T 6,045.0 32 2130 22:00 0.50 DRILL F 19 P 6,045.0 32 22:M 0:00 2.00 DRILL F 4 P 6,0450 33 000 3:30 3.50 DRILL F 19 P 5,245.0 33 330 400 050 DRILL F 7 P 5,2450 33 400 4:30 0.50 DRILL F 19 P 5,245.0 PJSM, ng up / change to 2-3/B rams, retest same 250 / 3500 pv. Test aurreaful. No re team. Rig down test equipment, drain BOP stack. 0000-0500 Rig down test equipment rig up floor/ pickup 2-3/8 stinger, RIH same. Follow with ❑ 6,045.0 5" drillpipe. 6,0,15o Rig down BOP test equipment, clear rig Floor. 6,045 0 PJSM, Bow, check, pick up populace, 1000 ft 2-3/8 tubing stinger. 6,045.0 Flow cback, follow 2-3/8 with 5" drill pipe. 6,045 0 Repair iron roughneck. 6,045.0 Flow check, PJSM RIJi to casing shoe 2350 ft with rig tongs, MO pipe with chain tongs. 6,045.0 Circulate at shoe while complem repairs Iron Rosghnak. gpm 339 / SPP 3125 psi. Flow check, resume RIH 5" drillpipe to TD at 6045 ft. Break circulation at 10 stand 6,045.0 intervals in open hole to confirm mulesha not plugging up - ok. 6,045,0 Circulate / condition fluids for cement plug. 318 gpm 13020 psi / rpm 30. 6,045.0 PJSM, ng up Schlumberger cementing equipment. Commence set cement plug: Test lines 5000 psi. Pump 100 bins 139 mud mah, pump 120 bbls (674 sks, 10% over gauged hole) 17 ppg cmt pump 10 bbls mucipush, pump 1.5 6611 H2O, switch to rig pump, displace with 77A bids 93 ppg OHM. ICP (cement) - 4 7 bpm I 650 psi, FCP (displacement) = 5.1 bpm / 2085 psi. 100%remms during job. Calculated 6,045.0 TOC C5263' MD. Cement in plea Q 19 20 hen. No cement to surface. fi 045.0 POH slowly 10 stands 5" drillpipe to SIM fi Pipe wet all stands. Drop wiper ball, circulate drillpipe clean. Tract cement to surface. SPM 73, GPM 318, SPP 2950 par, continue directors until no trace cemear as per mud engineer Wiper ball recovered 6,045.0 at shaker. Pump weight pill. Flow check, POH 5" drillpipe to 2880 ft and of tour.❑ ❑ 6,045.0 0000 - 0500 POI, lay dawn 2-3/8 stinger. Continue POH 5" dNlprpe to 1005 ft. (Flow check -Static) change handling equipment from 5" to ❑ 2 3/8' and cont POOH F/1005 ft, and lay down 2-38 HT-SLH90 Dnll Pipe / Cement 6,045.0 Stinger T/411 ft. (Brakes dragging on Drwks). PJSM-Rig service- Adjust brakes on Emirs, service Drwks, Topdrive, Blocks, Rotary 6,0450 table, Crown shims. Flow cloak- Static, Continue POOH laying down 2-3/8" JIT-SLH90 DNI Pipe Wall ft. and 6,045.0 break -off mule shoe. Flow check -Static, PJSM- Lay down 2 3/8" handling equipment, install 5" DP elevators, re - 6,045 0 hang ng tongs. Clean up rig Hour free ofOBM from trip out of hole. 6,045.0 Make up Retrieving tool & pull wear -bushing. Troubleshoot draw works brake (kicking and dmggrng), remove broke bands from drew works. Transport to machine shop for repairs. Circulate over top of hole with nip tank, onitorrng well. ❑ 00:00 - 0300- Install brake bands and adjust brakes corn on equalizer bu/Dmks. ❑ 03:00 - 05:00= Se test plug, Vapw-Cray Rep. Run in all Lock Down Screws on plug 6,0450 change rens back to "B 3.5" x 6- 6,045.0 Assemble drawworks brake bands, adjust, grease, and funciron same. Install guards. 6,045 0 Run test plug and luck down screws. 6,045 0 Change lower pipe rams back to 3 1/2'x6" variable. 6,045.0 Function lower pipe mans -OX, BII BOP stack and rest joint. Attempturtutlowerpipamonswithrmpaccess. Trouble shoottest pump, found crash 6,045 0 under valve in test pump. Clean out and re -assemble pump. Test VBR lower pipe rams to 250 psi low and 3,500 psi high. All tet for 5 mimtes. Cmod 6,045.0 test. Rig down test equipment, back out lockdown screws, remove test plug and install weer 6,045.0 bushing. 6,045.0 Pick up and make up directional BHA 4 12 6,0450 Shallow test MWD with 1,560 psi and 650 pan. 6,045.0 Trip in hole In 2,350' at casing shoe. Proper displacement. 6,045.0 Circulate and condition mud with 1,560 psi and 650 gpm. Wash down from 4,860'to 5,230' with 2060 psi and 630 gpm.❑ 0000-0330 Wash end rem down m 5.245', tag firm cement plug A20,0001bs, dress off olugto 1dickoffdeothat5.400'.0 0330-0400 Circ & Cpnd mud❑ 6,0450 0400.0700 Kickoff 6,045.0 Trip in hole from 2,359 to 4,860 Wash down from 2,945' to 3,042'. Ws"cam in hole from 5,230 to 5,245' Tag hard cement (Top of kick off point, ser down 20k weight on bit, fun. rpm=60, pn=2200, gpmr 50, wob=10-15k, torque offbottonr-6k, on bosom=7k fblbs. Take slow pump mte at 5,245' MD, gl MP at 30 psm-175 pn, 45 5,245.0 spm -260 psi,. Circulate bottoms up at 5,245', circulate out remaining mudpuah from carnatjob (3540 5,245,0 14,11). Drill cement from 5,245'to 5,300' kick off point, web=20-30k, rpm�, torque off bottom 6k, on bottcon 7k, psi offlumom 2100, on button 2200 psi, total bot rpm -190, mud motor 5,245.0 130 rpm. 31 1230 000 11.50 DRILL E 25 X 6,045.0 32 000 3:00 300 DRILL E 25 T 6,045.0 32 300 4:30 1.50 DR ILL C 20 P 6,0450 32 430 9:30 5.00 DRILL C 20 P 6,045.0 32 930 10:00 050 DRILL C 12 P 6,045.0 32 1000 1100 100 DRILL C 12 T 6,0450 1 P 32 11:00 11:30 050 DRILL C 12 P 6,045.0 1 32 11:30 13:00 1.50 DRILL C 20 P 6,045.0 1 32 13:00 1730 4.50 DRILL F 4 P 6,045 0 32 1730 18:00 0.50 DRILL F 7 P 6,045.0 32 1800 18:30 0.50 DRILL F 4 P 6,045.0 32 1800 21:30 3.00 DRILL F 7 P 6,045.0 32 2130 22:00 0.50 DRILL F 19 P 6,045.0 32 22:M 0:00 2.00 DRILL F 4 P 6,0450 33 000 3:30 3.50 DRILL F 19 P 5,245.0 33 330 400 050 DRILL F 7 P 5,2450 33 400 4:30 0.50 DRILL F 19 P 5,245.0 PJSM, ng up / change to 2-3/B rams, retest same 250 / 3500 pv. Test aurreaful. No re team. Rig down test equipment, drain BOP stack. 0000-0500 Rig down test equipment rig up floor/ pickup 2-3/8 stinger, RIH same. Follow with ❑ 6,045.0 5" drillpipe. 6,0,15o Rig down BOP test equipment, clear rig Floor. 6,045 0 PJSM, Bow, check, pick up populace, 1000 ft 2-3/8 tubing stinger. 6,045.0 Flow cback, follow 2-3/8 with 5" drill pipe. 6,045 0 Repair iron roughneck. 6,045.0 Flow check, PJSM RIJi to casing shoe 2350 ft with rig tongs, MO pipe with chain tongs. 6,045.0 Circulate at shoe while complem repairs Iron Rosghnak. gpm 339 / SPP 3125 psi. Flow check, resume RIH 5" drillpipe to TD at 6045 ft. Break circulation at 10 stand 6,045.0 intervals in open hole to confirm mulesha not plugging up - ok. 6,045,0 Circulate / condition fluids for cement plug. 318 gpm 13020 psi / rpm 30. 6,045.0 PJSM, ng up Schlumberger cementing equipment. Commence set cement plug: Test lines 5000 psi. Pump 100 bins 139 mud mah, pump 120 bbls (674 sks, 10% over gauged hole) 17 ppg cmt pump 10 bbls mucipush, pump 1.5 6611 H2O, switch to rig pump, displace with 77A bids 93 ppg OHM. ICP (cement) - 4 7 bpm I 650 psi, FCP (displacement) = 5.1 bpm / 2085 psi. 100%remms during job. Calculated 6,045.0 TOC C5263' MD. Cement in plea Q 19 20 hen. No cement to surface. fi 045.0 POH slowly 10 stands 5" drillpipe to SIM fi Pipe wet all stands. Drop wiper ball, circulate drillpipe clean. Tract cement to surface. SPM 73, GPM 318, SPP 2950 par, continue directors until no trace cemear as per mud engineer Wiper ball recovered 6,045.0 at shaker. Pump weight pill. Flow check, POH 5" drillpipe to 2880 ft and of tour.❑ ❑ 6,045.0 0000 - 0500 POI, lay dawn 2-3/8 stinger. Continue POH 5" dNlprpe to 1005 ft. (Flow check -Static) change handling equipment from 5" to ❑ 2 3/8' and cont POOH F/1005 ft, and lay down 2-38 HT-SLH90 Dnll Pipe / Cement 6,045.0 Stinger T/411 ft. (Brakes dragging on Drwks). PJSM-Rig service- Adjust brakes on Emirs, service Drwks, Topdrive, Blocks, Rotary 6,0450 table, Crown shims. Flow cloak- Static, Continue POOH laying down 2-3/8" JIT-SLH90 DNI Pipe Wall ft. and 6,045.0 break -off mule shoe. Flow check -Static, PJSM- Lay down 2 3/8" handling equipment, install 5" DP elevators, re - 6,045 0 hang ng tongs. Clean up rig Hour free ofOBM from trip out of hole. 6,045.0 Make up Retrieving tool & pull wear -bushing. Troubleshoot draw works brake (kicking and dmggrng), remove broke bands from drew works. Transport to machine shop for repairs. Circulate over top of hole with nip tank, onitorrng well. ❑ 00:00 - 0300- Install brake bands and adjust brakes corn on equalizer bu/Dmks. ❑ 03:00 - 05:00= Se test plug, Vapw-Cray Rep. Run in all Lock Down Screws on plug 6,0450 change rens back to "B 3.5" x 6- 6,045.0 Assemble drawworks brake bands, adjust, grease, and funciron same. Install guards. 6,045 0 Run test plug and luck down screws. 6,045 0 Change lower pipe rams back to 3 1/2'x6" variable. 6,045.0 Function lower pipe mans -OX, BII BOP stack and rest joint. Attempturtutlowerpipamonswithrmpaccess. Trouble shoottest pump, found crash 6,045 0 under valve in test pump. Clean out and re -assemble pump. Test VBR lower pipe rams to 250 psi low and 3,500 psi high. All tet for 5 mimtes. Cmod 6,045.0 test. Rig down test equipment, back out lockdown screws, remove test plug and install weer 6,045.0 bushing. 6,045.0 Pick up and make up directional BHA 4 12 6,0450 Shallow test MWD with 1,560 psi and 650 pan. 6,045.0 Trip in hole In 2,350' at casing shoe. Proper displacement. 6,045.0 Circulate and condition mud with 1,560 psi and 650 gpm. Wash down from 4,860'to 5,230' with 2060 psi and 630 gpm.❑ 0000-0330 Wash end rem down m 5.245', tag firm cement plug A20,0001bs, dress off olugto 1dickoffdeothat5.400'.0 0330-0400 Circ & Cpnd mud❑ 6,0450 0400.0700 Kickoff 6,045.0 Trip in hole from 2,359 to 4,860 Wash down from 2,945' to 3,042'. Ws"cam in hole from 5,230 to 5,245' Tag hard cement (Top of kick off point, ser down 20k weight on bit, fun. rpm=60, pn=2200, gpmr 50, wob=10-15k, torque offbottonr-6k, on bosom=7k fblbs. Take slow pump mte at 5,245' MD, gl MP at 30 psm-175 pn, 45 5,245.0 spm -260 psi,. Circulate bottoms up at 5,245', circulate out remaining mudpuah from carnatjob (3540 5,245,0 14,11). Drill cement from 5,245'to 5,300' kick off point, web=20-30k, rpm�, torque off bottom 6k, on bottcon 7k, psi offlumom 2100, on button 2200 psi, total bot rpm -190, mud motor 5,245.0 130 rpm. Report, Sbrt End Icor PNse Op Code Sub -Code Time Start (0) End (Ft) Comments 19 P 6,012.0 34 Sidetrack: Directional drill ahead kick off from 5,300' MD m 6,012' hID, gpm=745, psi off 0:30 0.50 DRILL F 4 btoa 2560, psi on btm=2770, diffmimml= 210 psi, top drive rpm=40, mud Our rpm=149, 6,012.0 34 030 3:30 total bit rpm= 199, web -20-35k, torque offbm=6300 fulbs, on bnn-7200 Mbs, pick up DRILL F 7 T 6,012.0 wt --156k, slack off=100k, rotate= 125k. TD intermediate casing point at 6012' MD, 369T 33 430 15:30 1100 DRILL F 3 P 5,2450 6,012.0 TVD, mud weight at 9 7 ppg. T 6,0120 34 430 Rack back stand DP, pump high viscosity sweep and circulate hole wits max rpm and 850 33 1530 20:00 4,50 DRILL F 7 P 6,012b 6,012 0 gpm, 3100 psi. 33 2000 000 4,00 DRILL F 19 P 6,012.0 34 000 0:30 0.50 DRILL F 4 T 6,012.0 34 030 3:30 3.00 DRILL F 7 T 6,012.0 34 330 030 100 DRILL F 7 T 6,0120 34 430 5:30 1.00 DRILL F 4 T 6,012.0 `64 36 600 12:00 6.00 DRILL F 12 P 6,0120 5:30 14:30 900 DRILL F 4 P 6,0120 34 1430 MIX) 1.50 DRILL F 7 P 6,012.0 34 1600 1:30 1.50 DRILL F 4 P 6,0120 34 1730 20:00 2.50 DRILL F 4 P 6,0120 34 20:00 2030 0.50 DRILL F 20 P 6,012.0 34 2030 000 3.50 DRILL F 4 P 6,0120 35 000 100 1.00 DRILL F 20 P 6,0120 35 1:00 4:30 350 DRILL F 4 P 6,012.0 35 430 630 2.00 DRILL F 7 P 6,012.0 V4\\ 35 630 100 6.50 DRILL F 7 P 6,012.0 Hack -ream out of hole from 6,000' to 5,340' with 750 gpm, top drive rout -40, torque 6,500- 14,000ft4bs. Loosing mud, Backream from 5,340'to 4,926 pumping at 2 bpm, hole pecking off, torque from 12,000 / 18,000 fulbs. lost 61 bbla of mud. ❑ MONN30 Trip in hole to 5,360' circulate and condition hole. Stage mud pumps up to 700 gpm with minimal losses. Pump 30 bbl of 25 ppb nut plug sweep and cirwlate out With first bottoms up shakes were loaded cuttings from hole. ❑ 6,012.0 0430-0500 Pumping out of hale with 400 gpm and 900 psi. from 5,3614 to 5,040'. 6,012.0 Trip in hole from 4,854' to 5,332'. Stage pumps up m 550 Spun, 1,700 psi, top drive rpm 70, recip and rotate from 5,222' In 5,332' in mngeut hole. Shakers loaded with bmtome up. Stage pumps up to 700 Spun, 2,450 psi, 70 rpm. PN=150k, S/0=100k, run in hole stand # 48, circulate, confine, recip 6,0120 and rotate from 5,27T to 5,360'. Pump 20 bbls of 25 ppb high vis nut plug sweep at 700 pre, 2,450 psi. with gond toting 6,012.0 returns on bottoms up. Pump out of hole from 5,332' m 4,845' with 400 Spur, 925 psi, PN -150k, ovepull 2540k 6,012 0 over. Unable to pump out past 4,845'. Backream out of hole from 4,845'to 4,725' with 400 gpm, 950 psi, 40 rpm, 7 -Ilk torque, PN w4= -150k, rot=120k, So wt --I Nk, at 4,725' packed o6; shut down Pumps, bleed off pressure, slump and torque, establish rotation and circulation, backrevn out from 4,73H to 4,558' slowly angling pumps up to 800 Spur, 2,650 psi, 100 rpm, 6-81, torque. Continue to 6,012.0 backream out to 2,356. Circulate at 2,350', 13 3/8' casing shoe with 800 gpm, 2,000 psi, 6k torque, 100 rpm. 6,012.0 Rotate and rot. pipe. No current losses at this time, very little cuttings returns at shakers. 6,012.0 Trip out of hole from 2,356 to BHA with proper displacement. 6,012 0 Rack back BHA, lay down mud motor and directionel tools. 6,012.0 Clear and clean drillBom. Pickup cleanout BHA and run in hole to 2,350', proper displacement fill drillpipe.❑ 0000-0100 Servicang®casingshoe❑ 0100-0930 RHI to 5900'14D❑ 6,012.0 0430 - 0500 Fill pipe &reaming to bottom 6,0120 Service sig, top drive, crown, donee ml s, and iron roughneck. Trip in hole from 2,286 to 5,924', no obstructions and const pipe displacement PN 6,012.0 WT=140k and S/0 WT=100k. Top drive up, break circulation and stage pumps W to 800 glen, 2,850 psi, 150 rpm, and 6k torque. Resor and wash down to 5,978', unable to work oast 5.978'. Shut down rotation and slack dorm 40k below slack off weight, pickup and no dmg. 20 bbls total losses while 6,012.0 circulating and washing down. , Continue circulating, conditioning mud and hole. Pump 35 bbl high vis sweep, large amounts of tunings on bonuses up, mix and pump 2nd high vis sweep, small amount of cuttings beck, continue condition mud from 10. I+ppg to 9,7 ppg through the entire system while miming all solids removal equipment including centrifuges. PIUWT=150k S/O 6,0120 WT=100k, Tmque -71,, and Rot WT=120k Flow check, pull Out Ofhole on elevators from 5,978'to BNA. Mettler well at shoe, sonic No dreg or hole obstructions on nip out. SPRs at 5,950', #1 pump, 25 spm=118 pd, 35 spm=152 psi. 6,012.0 SLM on trip out, 5974.53'. 6,0120 Stand back HWDP andjars, lay out drillcollars, stabilisers, subs, and bit. Rig up and test BOPS, change out top set of rams m 9 5/8".❑ 6,0120 0000-0500 Testing BOPS. 6,0120 Continue test BOP. 6,012.0 Change top pipe oma to 9 5/8"casing rams. Continue test BOP on 5" drillpipe, choke manifold, and all safety valves to 250/3,500 psi. Each test for 5 minutes each. No re -rust. Test witness waived by Chuck Cheve-AOOCC. 6,012.0 Test witnessed by Mark Ashley -NAD and Scott Beauchamp-Eni. 6,012.0 Pick up and make up 9 5/8" test joint. 6,012 0 Ten annular and upper pipe rams to 25013,500 psi on 9 5/8" casing for 5 minutes each test. 6,012.0 Break and lay down 9 54" testjoint. 6,012,0 P1MS. Rig up to run 9 5/8" casing. 6,012.0 Make dummy, run with 9 5/8' casing hang, as per Vewo, 6,012.0 PJSM with all Peummael involved running teeing. Run in hole with 95/8°,4716/B, L-80 BTC -M casing. Bskelok shoe track and ingall 6,012.0 centralizers as per program to 2,094' with proper fill and displacement. 35 13:00 19:30 6.50 DRILL F 4 P 6,0120 35 1930 2230 3.00 DRILL F 4 P 6,0120 35 2230 000 1.50 DRILL F 13 P 6,0120 36 000 030 0.50 DRILL F 12 P 6,012.0 36 030 6:00 5.50 DRILL F 12 P 6,012.0 36 600 12:00 6.00 DRILL F 12 P 6,0120 36 1200 13:00 1.00 DRILL F 12 P 6,0120 i \u 36 1300 13:30 0.50 DRILL F 12 P 6,012.0 I \� 36 13:30 14:30 100 DRILL F 20 P 6012.0 36 1430 1630 2.00 DRILL F 20 P 6,0120 36 1630 17:W 0.50 DRILL F 20 P 6,012.0 36 1700 1730 0.50 DRILL F 20 P 6,0120 36 1730 000 650 DRILL F 19 P 6,012.0 Hack -ream out of hole from 6,000' to 5,340' with 750 gpm, top drive rout -40, torque 6,500- 14,000ft4bs. Loosing mud, Backream from 5,340'to 4,926 pumping at 2 bpm, hole pecking off, torque from 12,000 / 18,000 fulbs. lost 61 bbla of mud. ❑ MONN30 Trip in hole to 5,360' circulate and condition hole. Stage mud pumps up to 700 gpm with minimal losses. Pump 30 bbl of 25 ppb nut plug sweep and cirwlate out With first bottoms up shakes were loaded cuttings from hole. ❑ 6,012.0 0430-0500 Pumping out of hale with 400 gpm and 900 psi. from 5,3614 to 5,040'. 6,012.0 Trip in hole from 4,854' to 5,332'. Stage pumps up m 550 Spun, 1,700 psi, top drive rpm 70, recip and rotate from 5,222' In 5,332' in mngeut hole. Shakers loaded with bmtome up. Stage pumps up to 700 Spun, 2,450 psi, 70 rpm. PN=150k, S/0=100k, run in hole stand # 48, circulate, confine, recip 6,0120 and rotate from 5,27T to 5,360'. Pump 20 bbls of 25 ppb high vis nut plug sweep at 700 pre, 2,450 psi. with gond toting 6,012.0 returns on bottoms up. Pump out of hole from 5,332' m 4,845' with 400 Spur, 925 psi, PN -150k, ovepull 2540k 6,012 0 over. Unable to pump out past 4,845'. Backream out of hole from 4,845'to 4,725' with 400 gpm, 950 psi, 40 rpm, 7 -Ilk torque, PN w4= -150k, rot=120k, So wt --I Nk, at 4,725' packed o6; shut down Pumps, bleed off pressure, slump and torque, establish rotation and circulation, backrevn out from 4,73H to 4,558' slowly angling pumps up to 800 Spur, 2,650 psi, 100 rpm, 6-81, torque. Continue to 6,012.0 backream out to 2,356. Circulate at 2,350', 13 3/8' casing shoe with 800 gpm, 2,000 psi, 6k torque, 100 rpm. 6,012.0 Rotate and rot. pipe. No current losses at this time, very little cuttings returns at shakers. 6,012.0 Trip out of hole from 2,356 to BHA with proper displacement. 6,012 0 Rack back BHA, lay down mud motor and directionel tools. 6,012.0 Clear and clean drillBom. Pickup cleanout BHA and run in hole to 2,350', proper displacement fill drillpipe.❑ 0000-0100 Servicang®casingshoe❑ 0100-0930 RHI to 5900'14D❑ 6,012.0 0430 - 0500 Fill pipe &reaming to bottom 6,0120 Service sig, top drive, crown, donee ml s, and iron roughneck. Trip in hole from 2,286 to 5,924', no obstructions and const pipe displacement PN 6,012.0 WT=140k and S/0 WT=100k. Top drive up, break circulation and stage pumps W to 800 glen, 2,850 psi, 150 rpm, and 6k torque. Resor and wash down to 5,978', unable to work oast 5.978'. Shut down rotation and slack dorm 40k below slack off weight, pickup and no dmg. 20 bbls total losses while 6,012.0 circulating and washing down. , Continue circulating, conditioning mud and hole. Pump 35 bbl high vis sweep, large amounts of tunings on bonuses up, mix and pump 2nd high vis sweep, small amount of cuttings beck, continue condition mud from 10. I+ppg to 9,7 ppg through the entire system while miming all solids removal equipment including centrifuges. PIUWT=150k S/O 6,0120 WT=100k, Tmque -71,, and Rot WT=120k Flow check, pull Out Ofhole on elevators from 5,978'to BNA. Mettler well at shoe, sonic No dreg or hole obstructions on nip out. SPRs at 5,950', #1 pump, 25 spm=118 pd, 35 spm=152 psi. 6,012.0 SLM on trip out, 5974.53'. 6,0120 Stand back HWDP andjars, lay out drillcollars, stabilisers, subs, and bit. Rig up and test BOPS, change out top set of rams m 9 5/8".❑ 6,0120 0000-0500 Testing BOPS. 6,0120 Continue test BOP. 6,012.0 Change top pipe oma to 9 5/8"casing rams. Continue test BOP on 5" drillpipe, choke manifold, and all safety valves to 250/3,500 psi. Each test for 5 minutes each. No re -rust. Test witness waived by Chuck Cheve-AOOCC. 6,012.0 Test witnessed by Mark Ashley -NAD and Scott Beauchamp-Eni. 6,012.0 Pick up and make up 9 5/8" test joint. 6,012 0 Ten annular and upper pipe rams to 25013,500 psi on 9 5/8" casing for 5 minutes each test. 6,012.0 Break and lay down 9 54" testjoint. 6,012,0 P1MS. Rig up to run 9 5/8" casing. 6,012.0 Make dummy, run with 9 5/8' casing hang, as per Vewo, 6,012.0 PJSM with all Peummael involved running teeing. Run in hole with 95/8°,4716/B, L-80 BTC -M casing. Bskelok shoe track and ingall 6,012.0 centralizers as per program to 2,094' with proper fill and displacement. Repos N Start End Phu, Op Code Sub -Code Time Start(ft) End (Ft) Comments P -N -T 37 0'.00 0:30 0.50 DRILL G 19 P 6,012.0 37 030 1:30 1.00 DRILL G 7 P 6,012.0 37 130 400 2.50 DRILL G 19 P 6,0120 37 400 430 0.50 DRILL G 7 P 6,0120 37 430 6:00 1.50 DRILL G 19 P 6,012.0 37 600 7:30 1.50 DRILL G 7 P 6,012.0 37 730 13:00 5.50 DRILL G 19 P 6,0120 37 1300 14:00 100 DRILL G 19 P 6,012.0 37 1400 1430 0.50 DRILL G 19 P 6,0120 \�I 371430 `tl 1500 0.50 DRILL G 19 P 6,012.0 \ 37 15:00 16:30 15D DRILL G 20 P 6,012.0 37 1630 17'.30 IN DRILL G 7 P 6,0120 37 1730 18:00 050 DRILL H 20 P 6,012.0 37 18.00 1930 1.50 DRILL H 19 P 6,0120 37 1930 21:00 1.50 DRILL H 20 P 6,012.0 37 21:00 2200 1.00 DRILL H 20 P 6,012.0 37 22:00 0:00 2.00 DRILL G 20 P 6,0120 38 000 2:00 200 DRILL C 12 P 6,0120 38 200 5:00 300 DRILL C 12 P 6,0120 38 500 600 1.00 DRILL C 12 P 6,0120 38 6:00 8:00 200 DRILL C 20 P 6,0120 38 800 1000 20D DRILL E 20 P 6,D12.0 38 1000 1130 1.50 DRILL E 4 P 6,012.0 38 1130 21:30 1000 DRILL E 4 P 6,012.0 38 21:30 2200 0.50 DRILL E 7 P 6,0120 38 2200 23:00 1 00 DRILL E 12 P 6,012.0 38 23:00 000 1.00 DRILL E 20 P 6,0120 39 000 300 3.00 DRILL E 20 P 6,0120 39 300 7:00 4.00 DRILL E 19 P 6,012.0 39 7:00 9:00 2.00 DRILL E 3 P 6,012.0 39 9:00 12:00 3.00 DRILL E 7 P 6,0320 Il� 39 12:00 1430 2.50 DRILL E 7 P 6,0320 39 1430 19:30 5.00 DRILL E 20 P 6,032.0 39 1930 2200 2.50 DRILL E 7 P 6,032.0 39 2200 21:00 100 DRILL E 19 P 6,032.0 39 23:00 0:00 1.00 DRILL E 22 T 6,032.0 4a 0:00 5:00 500 DRILL E 22 T 6,032.0 40 500 600 100 DRILL E 19 P 6,0320 40 `v 6:00 10:30 4.50 DRILL E 4 P 6,032.0 40 10:30 1330 3.00 DRILL E 4 P 6,0320 40 1330 14:30 1.00 DRILL E 20 P 6,032.0 0 14:30 1600 1.50 DRILL C 20 P 6,032.0 6,012 0 Run in hole with 9 5/8" casing from 2,094' to 2,351'. Break circulation at shoe and pump casing capacity, staging pump up from 2 to 5 plain, 50 6,012.0 Vm,270 psi, and 207 gpm with no losses. 6,0120 Run 9 5/8" casing from 2,351'to 3,478'. Not getting proper displacement. Stage pump up from 2 m 4 bpm, 270 psi. Circulate until returns stabilize with minimal 6,0120 loss. 6,012.0 Run 9 5/8" casing from 3,478' to 4,342'. Break circulation and pump casing capacity, singing pump up from 2 to 4 bpm with 265 psi 6,012.0 and 174 gpm with no losses. 6,0120 Ron 9 5/8" casing from 4,342' to 5,879'. Run 9 5/8" casing, washing down from 5,879' to 5,923' with 2-5 bpm, 390 psi, with no 6,012.0 losses. 6,012.0 Pick up and make up landingjoint with 9 5/8" casing hanger. Circulate and wash down and land hanger in hanger profile, at 5 bpm, 390 psi, and no losseswork and reciprocate casing. No excess drag and shakers clean. Run a tinof 142 6,012.0 joints of 9 5/8" casing and me pups totaling 5,923.79', shoe at 5,960'. 6,0120 Rig down casing spider and fill tool. Makeup Schlumberger cement head and rig up lines. Ciroulm.m5bom,39i).m.recimocmeasing. PN215kand S/0155k. Norestrictions 6,0120 and no losses. 6,0120 Pre -job safety meeting with all personnel Involved with cementjob. Pump 5 bbls water, test lines m 3,000 psi. Pump 100 bbls chemical wash 8, 100 bbls of mudpush II spacer, drop bottom plug, mix and pump 84 Mt of 12.5 ppg cement Drop tap plug, pump 5 bbts of water, switch to mud pump and displace at 8.5 bpm, 750 psi. slow m 2 bpm and bump plug at 4226 stks and 500 psi over circ p,u,,. Hold for 5 minutes, 6,0120 bleed bad, Baas holding. 6,0120 Lay down cement head casing elevators, and lmdingjoint. 6,012.0 Clear rig Boor of casing tools and clean. 6,012,0 Pick up and make up Vance 9 5/8" packoff assembly 6,012.0 Run and set pack off, test seals to 5,000 psi for 10 minute. O.K. Set test plug. 6,012.0 Change out Dtt piperases from 95/8 - casing rams to 4 IZZ"x variable mons FBI BOP with water and tet upper mans to 250 psi low and 3,500 psi high for 5 minutes Per 6,0120 test OX Pull¢st plug, drain BOP, end inssll wear bushing. Rigup Liule Red Servicesandpump 205 bbls diesel at 925 psi and 13/4 BPM for freeze protection of 9 5/8" annulus. C 6,0120 floor of test tool s. Move BHA to rig Boor, load pipe shed with 5" drillpipe and measure pipe. ❑ 6,0120 Gave 24 hr notice to Chuck Steve (AOGCC) for early BOP teas 6,0120 Make up clean out BHA and mn in hole. 6,0120 Trip in hole picking up 5" drillpipe from pipe shed, tag 9 518" float collar at 5,869'. 6,012.0 Circulate drillpipe volume. Test 9 5/8" casing with 9.7 Dog mud, tamping at 3 mks minute appx 29 bpm up to 2,500 6,0120 psi. Pumped 4.5 bbls. Held for 30 minutes, bled back 4.5 bbls to trip tank, good tut. Slip and cut 100' of drilling line, continue cleaning pits.❑ 0000 - 0300 Slip and cut drilling line❑ 6,012.0 0300 - 0700 Drill plug at float shoe 6,0120 Slip and cut 100' of drilling line, service dg and adjust brakes. Drill plugs, Boat collar, and shoe track from 4,869 to 4,960', clean out ralhole down to 6,012.0 6,012'. Drill new hole from 6,012' in 6,032', drilled hard for the fist 5', acted like NB stab was wall 6,0320 hanging. Circulate bottoms up having a P1SM with everyone involved, spot trucks and hoses, JSA 6,032.0 with new crew. Displace 93 ppg. OBM with Low solids 03 pp, OBM at 5 bpm clean suction pit of old 6,032.00 mud. Rack back one stand, tig up for EL T. Clean mud dt and Offload 9 3 ppg VPLR oil base 6,032.0 mud. 6,032.0 Circulate and condition mud at 5,900' at 5 bpm to 9 2 ppg in and mt. Perform FIT. pumping at 3 strokes per minute, 029 bpm to 537 psi with 92 ppg mud 6,032 0 weight EMW 12 0 ppg. Pumped 2.6 bbls and returned same. Wait on weather. Phu. 3 conditions.❑ 6,0320 0000-0500 Wait oa weather. At 0500 It , slug pipe and pull out of hole to test BOP,. 6,0320 Walt on weather. Phase 3 conditions (White mt). Clean rig. Take slow pump rates at 5,916 with 9.2 ppg OBM. 30 spm=180 psi, 45 spm -320 psi. 6,032.0 Check Flow, pump slug, blow down top drive. 6,032.0 Trip out of hole to 654'. Tripoutofholglayingdown HWDPandjara. RacktwostandsofHWDPinderrickand 6,032.0 lay down BHA. 6,0320 Clan drillfloor and drain BOPa. 6,032.0 Pull wear bushing, mut set plu& fill BOPS and choke marigold with water. N Start End Oar Phase Op Code Sri, -ode ��mm start (R) End (F[) Comments Test BOPS, choke manifold, and safery valves to 25D psi low and 3,500 psi high. All ten for 5 minutes. Draw, down ten with BOP accumulator unit, 1 min. 52 secomds for buildup. 6,032.0 Chaise pressure test waivered by Chuck Scheve. 6,0320 Pull ten plug and install wear bushing. 6,0320 Break and lay down test ..his and clean ebullgon, Pick an BHA 415 as per program.❑ 0000-05W Continue pick up BHA, shallow fast MWD, and picking up 5"drillpipe on trip 6,032.0 in. Pick up BHA #15, Run in hole, shallow test with 560 gpm and 1,065 psi. Blow down top 6,032 D drive. 6,032 0 Trip in hole picking up singles of 5" drillpipe from 375' to If 6,032.0 Shallow ten MWD with 550 gain and 1,115 psi. Trip in hole picking up singles of 5' drillpipe from 854' to 3,342'. Picked up a told of 93 6,032,0 joints. 6,0320 Trip in hole from 3,342'to 5,927, filling pipe every 15 stands. L.... hole at 100' per, he from 5,969 to 6,031 -with 550 ppm, 130 spm, 1,700 psi, and 6,032,0 40 rpm. Drill from 6,032' to 6,702' with 120-140 rpm, 550 gam, 1,795 psi, 130 spm, us torque on bosom, 51, torque off bottom, 4-10k with, and ECD at 10.4-103 ppg max. SPRs at 6,692' with #2pump, 25 .=] 70 psi, 35 spm-�30 psi. 43 pump, 25 spm -165 psi, 35 spm=235 psi. ❑ 0 6,702.0 0000.0500 drilling ahead to 7076' Drill from 6,702' to 7,076 with 550 gam, 1930 psi, 130 spm, 8-9k virgas 6-71, off bottom 7,0760 torque, "it wob, 130 rpm, 1424 pick up wt 92k down weight. 10.97 ECD, 3725' TVD. Drill from 7,076' to 7,756 with 550 gpm, 130 spm, 2040 psi, 6-8k wob, 140 an 9-10k torque, 8-94 torque offbmtom 155k pick up weight, Wk slack offwright, 11.10 ppg ECD, 3,772' TVD.❑ SPR W/ #1 pump, 30 spm=250 psi, 45 spm=350 psi. 93 pump, 30 spm -250 psi, 45 7,756,0 spm -380 psi. Drill from7,756' to 8,030' with 550 gpm, 130 spm, 2150 psi, bSk with, 110 rpm, 8-IOk torque, 6-81, torque off bosom, 172k pick up weight, 754 slack off weight. 11.1 ppg ECD, 8,032.0 3,802' TVD. 15 his adjusted drill fime. Circuits. and condition hole to reduce ECD, drag, and torque with 550 gpm 130 spm, 2080 psi, 130 rpm. Reduce ECD from I I.I ppg to 10,5 ppg. Shaken loaded with cuttings on 8,032.0 bosoms up. Drill from 8,032'to 8,470' with 550 gpm, 120 rpm, 1,980 psi, 4-1 Ok wob, 8-9k torque on bottom, 7-81, torque off bosom, 160k pick up weight, 98k slack offweight, 106 ppg ECD, 5.85 his. adjusted drilling time, 3,871TVD. SPA at 8,450' #1 pump, 25 spm-210psi, 35 spm=285 psi, 92pump, 25 spm -212 psi, 35 spm= 285 psi.❑ 0000-0330 Drill ahead from 8,470' to 8673' _. 8,470.0 0330-0500 Lost power to fig due to generator overheat Drill from 8,470'to 8,673' with 550 gpm, 130 spm, 2,000 psi, 140 rpm, 9-10k torque on bottom. 91, torque off bottom, 5-81, wob, 162k pick up weight, 871, slack offweight, I IOk 8,6730 r=te weight. 10.7 ppg ECD, and 3,849' TVD. 8,673.0 Engine overheated, dropped all power off line. Drill from 8,673' to 8,892' with 550 gpm, 130 spm, 2000 psi, 4.1 Ok with, 140 rpm, 10-11k torque on bottom 9-1 Ok torque offbottom, 162k pick up weight, 854 shckoffweght, 1104 ratan, weight, 10.8 ppg ECD, 3,849' TVD, 8 has adjusted drill time.0 8,892 0 SPM with #2 pump, 30 spm -275 psi, 45 spm4OO psi. Drill from kS92'to 9,372' widr 550 gpm, 130 spm, 2,100 poi, 140 rpm, &10k wob, 11-12k torque m bosom, 104 torque off bosom, 1701,pickup weight, 80k slackoff weight, I lok rotate weight, I I.I Ppg ECD, 3,850' TVD. SPR, #3 pump, 30 spm310 psi. 45 spm -430 psi. 42 pump, 30 spm -300 psi, 45 spm430 psi.❑ 9,372.01500 -1530 -Top Drive Failure. Diagnosis] and repaired electrical signal Cimllate to reduce ECD and drag with 550 gpm 2,100 psi 130 spm mid 140 rpm. Drop to 9,372.0 10 9 PPB Drill fr9m9,3]2 to 9,562' with 550 gpm, 130 spm, 2,160 psi, 2-12k with, 140 rpm, 170k pick up weight, 75k slack offweight, 1071, rotate weighs 11-124 torque on bottom, IOk torque offbosom, 11.15 ppg ECD.❑ 9,562p ONO -0500 Drill ahead from 9,56T to 9,946' _ Drill from 9,562' to 10,043' with 550 g or ,130 spm, 2,200 psi, 4-I Ok wob, 140 in, 170k pick up wt.❑ 70k slack off wt 107k rotate wt. I I -12k torque on bosom, IOk torque off bosom, 3,840' 10,043.0 TVD, and 11.37 ppg ECD. 9,657.0 Circulate bottoms up, pull out of hole from 10,0,13' in 9,657. 9,717.0 Build 60' of bough from %65T 10 9.717' with 550 gpm, 130 spm, 2,130 psi, 140 rpm. Drill from 9,717' to 9,874' with 550 gpm, 130 spm, 2,230 psi, 140 rpm, 2-Sk with, IOk torque offboo. 11-12k torque on bon, 1684 pick up wt. 704 slack offwt, 107k rmate wt, 9,874.0 11,2 ppg ECD; and 5.17 he, adjusted drill time. Drill from 9,87,1' to 10,615' with 550 gpm, 130 spm, 2,3W psi, 140 in, 2-81, with, i 75 pick up wt. 75k slack off wt. 107k rotate wt. I 11, torque offbsn, 12-13k torque on bon. 10,615.0 11 4 ppg ECD, and ADT/631 hrs. Service top drive and rig. Take slow pump rates with #2 pump, 30 spm -310 psi, 45 spm - 10,615.0 450 psi. #3 pump, 30 spm -310 psi, 45 spm450 psi. 40 16:M 2030 4.50 DML C 12 P 6,032.0 40 2030 21:00 050 DRILL C 19 P 6,0320 40 21:00 22:00 1.00 DRILL C 20 P 6,032.0 40 2200 000 200 DRILL E 4 P 6,0320 41 000 4:00 4.00 DRWL E 4 P 6,032.0 41 4:00 5:00 LW DRILL E 4 P 6,032.0 41 5:00 530 0.50 DRML E 4 P 6,0320 41 5 30 10:30 5.00 DRILL E 4 P 6,032.0 41 10:30 1330 300 DRILL E 4 P 6,032.0 1 a 13:30 1530 2.00 DRML E 7 p 6,032.0 7 41 1530 000 8.50 DRML E 3 P 6,0320 3 42 000 5:30 5 50 DRR.L E 3 P 6,7020 42 5:30 12:M 6.50 DRILL E 3 P 7,0760 DRILL E 3 P 9,717.0 44 1200 220 10.0 DRILL 42 1200 15:00 300 DRML E 3 P 7,756.0 DROLL f � V 7 P 10,615.0 42 1500 1700 2.00 DRILL E 7 P 8,0320 Test BOPS, choke manifold, and safery valves to 25D psi low and 3,500 psi high. All ten for 5 minutes. Draw, down ten with BOP accumulator unit, 1 min. 52 secomds for buildup. 6,032.0 Chaise pressure test waivered by Chuck Scheve. 6,0320 Pull ten plug and install wear bushing. 6,0320 Break and lay down test ..his and clean ebullgon, Pick an BHA 415 as per program.❑ 0000-05W Continue pick up BHA, shallow fast MWD, and picking up 5"drillpipe on trip 6,032.0 in. Pick up BHA #15, Run in hole, shallow test with 560 gpm and 1,065 psi. Blow down top 6,032 D drive. 6,032 0 Trip in hole picking up singles of 5" drillpipe from 375' to If 6,032.0 Shallow ten MWD with 550 gain and 1,115 psi. Trip in hole picking up singles of 5' drillpipe from 854' to 3,342'. Picked up a told of 93 6,032,0 joints. 6,0320 Trip in hole from 3,342'to 5,927, filling pipe every 15 stands. L.... hole at 100' per, he from 5,969 to 6,031 -with 550 ppm, 130 spm, 1,700 psi, and 6,032,0 40 rpm. Drill from 6,032' to 6,702' with 120-140 rpm, 550 gam, 1,795 psi, 130 spm, us torque on bosom, 51, torque off bottom, 4-10k with, and ECD at 10.4-103 ppg max. SPRs at 6,692' with #2pump, 25 .=] 70 psi, 35 spm-�30 psi. 43 pump, 25 spm -165 psi, 35 spm=235 psi. ❑ 0 6,702.0 0000.0500 drilling ahead to 7076' Drill from 6,702' to 7,076 with 550 gam, 1930 psi, 130 spm, 8-9k virgas 6-71, off bottom 7,0760 torque, "it wob, 130 rpm, 1424 pick up wt 92k down weight. 10.97 ECD, 3725' TVD. Drill from 7,076' to 7,756 with 550 gpm, 130 spm, 2040 psi, 6-8k wob, 140 an 9-10k torque, 8-94 torque offbmtom 155k pick up weight, Wk slack offwright, 11.10 ppg ECD, 3,772' TVD.❑ SPR W/ #1 pump, 30 spm=250 psi, 45 spm=350 psi. 93 pump, 30 spm -250 psi, 45 7,756,0 spm -380 psi. Drill from7,756' to 8,030' with 550 gpm, 130 spm, 2150 psi, bSk with, 110 rpm, 8-IOk torque, 6-81, torque off bosom, 172k pick up weight, 754 slack off weight. 11.1 ppg ECD, 8,032.0 3,802' TVD. 15 his adjusted drill fime. Circuits. and condition hole to reduce ECD, drag, and torque with 550 gpm 130 spm, 2080 psi, 130 rpm. Reduce ECD from I I.I ppg to 10,5 ppg. Shaken loaded with cuttings on 8,032.0 bosoms up. Drill from 8,032'to 8,470' with 550 gpm, 120 rpm, 1,980 psi, 4-1 Ok wob, 8-9k torque on bottom, 7-81, torque off bosom, 160k pick up weight, 98k slack offweight, 106 ppg ECD, 5.85 his. adjusted drilling time, 3,871TVD. SPA at 8,450' #1 pump, 25 spm-210psi, 35 spm=285 psi, 92pump, 25 spm -212 psi, 35 spm= 285 psi.❑ 0000-0330 Drill ahead from 8,470' to 8673' _. 8,470.0 0330-0500 Lost power to fig due to generator overheat Drill from 8,470'to 8,673' with 550 gpm, 130 spm, 2,000 psi, 140 rpm, 9-10k torque on bottom. 91, torque off bottom, 5-81, wob, 162k pick up weight, 871, slack offweight, I IOk 8,6730 r=te weight. 10.7 ppg ECD, and 3,849' TVD. 8,673.0 Engine overheated, dropped all power off line. Drill from 8,673' to 8,892' with 550 gpm, 130 spm, 2000 psi, 4.1 Ok with, 140 rpm, 10-11k torque on bottom 9-1 Ok torque offbottom, 162k pick up weight, 854 shckoffweght, 1104 ratan, weight, 10.8 ppg ECD, 3,849' TVD, 8 has adjusted drill time.0 8,892 0 SPM with #2 pump, 30 spm -275 psi, 45 spm4OO psi. Drill from kS92'to 9,372' widr 550 gpm, 130 spm, 2,100 poi, 140 rpm, &10k wob, 11-12k torque m bosom, 104 torque off bosom, 1701,pickup weight, 80k slackoff weight, I lok rotate weight, I I.I Ppg ECD, 3,850' TVD. SPR, #3 pump, 30 spm310 psi. 45 spm -430 psi. 42 pump, 30 spm -300 psi, 45 spm430 psi.❑ 9,372.01500 -1530 -Top Drive Failure. Diagnosis] and repaired electrical signal Cimllate to reduce ECD and drag with 550 gpm 2,100 psi 130 spm mid 140 rpm. Drop to 9,372.0 10 9 PPB Drill fr9m9,3]2 to 9,562' with 550 gpm, 130 spm, 2,160 psi, 2-12k with, 140 rpm, 170k pick up weight, 75k slack offweight, 1071, rotate weighs 11-124 torque on bottom, IOk torque offbosom, 11.15 ppg ECD.❑ 9,562p ONO -0500 Drill ahead from 9,56T to 9,946' _ Drill from 9,562' to 10,043' with 550 g or ,130 spm, 2,200 psi, 4-I Ok wob, 140 in, 170k pick up wt.❑ 70k slack off wt 107k rotate wt. I I -12k torque on bosom, IOk torque off bosom, 3,840' 10,043.0 TVD, and 11.37 ppg ECD. 9,657.0 Circulate bottoms up, pull out of hole from 10,0,13' in 9,657. 9,717.0 Build 60' of bough from %65T 10 9.717' with 550 gpm, 130 spm, 2,130 psi, 140 rpm. Drill from 9,717' to 9,874' with 550 gpm, 130 spm, 2,230 psi, 140 rpm, 2-Sk with, IOk torque offboo. 11-12k torque on bon, 1684 pick up wt. 704 slack offwt, 107k rmate wt, 9,874.0 11,2 ppg ECD; and 5.17 he, adjusted drill time. Drill from 9,87,1' to 10,615' with 550 gpm, 130 spm, 2,3W psi, 140 in, 2-81, with, i 75 pick up wt. 75k slack off wt. 107k rotate wt. I 11, torque offbsn, 12-13k torque on bon. 10,615.0 11 4 ppg ECD, and ADT/631 hrs. Service top drive and rig. Take slow pump rates with #2 pump, 30 spm -310 psi, 45 spm - 10,615.0 450 psi. #3 pump, 30 spm -310 psi, 45 spm450 psi. 42 17:00 000 7.00 DRML E 3 P 8,032.0 43 0:00 330 3.50 DRILL E 3 P 8,470.0 43 3:30 530 2.00 DML E 20 T 8,6730 43 5:30 12:00 6.50 DML E 3 P 8,673.0 43 1200 21:00 9.00 DRILL E 3 P 8,8920 43 2100 21:30 0.50 DRILL E 7 P 9,3720 43 2130 000 2,50 DRILL E 3 P 9,372.0 6:W 6.00 DRILL E 3 P 9,5620 44 000 44 600 730 1.50 DML E 7 P 10,043.0 44 730 900 1.50 DFUL E 3 P 9,567.0 h'V 44 9:W 1200 300 DRILL E 3 P 9,717.0 44 1200 220 10.0 DRILL E 3 P 9,8740 44 2200 2230 0.50 DROLL E 7 P 10,615.0 Test BOPS, choke manifold, and safery valves to 25D psi low and 3,500 psi high. All ten for 5 minutes. Draw, down ten with BOP accumulator unit, 1 min. 52 secomds for buildup. 6,032.0 Chaise pressure test waivered by Chuck Scheve. 6,0320 Pull ten plug and install wear bushing. 6,0320 Break and lay down test ..his and clean ebullgon, Pick an BHA 415 as per program.❑ 0000-05W Continue pick up BHA, shallow fast MWD, and picking up 5"drillpipe on trip 6,032.0 in. Pick up BHA #15, Run in hole, shallow test with 560 gpm and 1,065 psi. Blow down top 6,032 D drive. 6,032 0 Trip in hole picking up singles of 5" drillpipe from 375' to If 6,032.0 Shallow ten MWD with 550 gain and 1,115 psi. Trip in hole picking up singles of 5' drillpipe from 854' to 3,342'. Picked up a told of 93 6,032,0 joints. 6,0320 Trip in hole from 3,342'to 5,927, filling pipe every 15 stands. L.... hole at 100' per, he from 5,969 to 6,031 -with 550 ppm, 130 spm, 1,700 psi, and 6,032,0 40 rpm. Drill from 6,032' to 6,702' with 120-140 rpm, 550 gam, 1,795 psi, 130 spm, us torque on bosom, 51, torque off bottom, 4-10k with, and ECD at 10.4-103 ppg max. SPRs at 6,692' with #2pump, 25 .=] 70 psi, 35 spm-�30 psi. 43 pump, 25 spm -165 psi, 35 spm=235 psi. ❑ 0 6,702.0 0000.0500 drilling ahead to 7076' Drill from 6,702' to 7,076 with 550 gam, 1930 psi, 130 spm, 8-9k virgas 6-71, off bottom 7,0760 torque, "it wob, 130 rpm, 1424 pick up wt 92k down weight. 10.97 ECD, 3725' TVD. Drill from 7,076' to 7,756 with 550 gpm, 130 spm, 2040 psi, 6-8k wob, 140 an 9-10k torque, 8-94 torque offbmtom 155k pick up weight, Wk slack offwright, 11.10 ppg ECD, 3,772' TVD.❑ SPR W/ #1 pump, 30 spm=250 psi, 45 spm=350 psi. 93 pump, 30 spm -250 psi, 45 7,756,0 spm -380 psi. Drill from7,756' to 8,030' with 550 gpm, 130 spm, 2150 psi, bSk with, 110 rpm, 8-IOk torque, 6-81, torque off bosom, 172k pick up weight, 754 slack off weight. 11.1 ppg ECD, 8,032.0 3,802' TVD. 15 his adjusted drill fime. Circuits. and condition hole to reduce ECD, drag, and torque with 550 gpm 130 spm, 2080 psi, 130 rpm. Reduce ECD from I I.I ppg to 10,5 ppg. Shaken loaded with cuttings on 8,032.0 bosoms up. Drill from 8,032'to 8,470' with 550 gpm, 120 rpm, 1,980 psi, 4-1 Ok wob, 8-9k torque on bottom, 7-81, torque off bosom, 160k pick up weight, 98k slack offweight, 106 ppg ECD, 5.85 his. adjusted drilling time, 3,871TVD. SPA at 8,450' #1 pump, 25 spm-210psi, 35 spm=285 psi, 92pump, 25 spm -212 psi, 35 spm= 285 psi.❑ 0000-0330 Drill ahead from 8,470' to 8673' _. 8,470.0 0330-0500 Lost power to fig due to generator overheat Drill from 8,470'to 8,673' with 550 gpm, 130 spm, 2,000 psi, 140 rpm, 9-10k torque on bottom. 91, torque off bottom, 5-81, wob, 162k pick up weight, 871, slack offweight, I IOk 8,6730 r=te weight. 10.7 ppg ECD, and 3,849' TVD. 8,673.0 Engine overheated, dropped all power off line. Drill from 8,673' to 8,892' with 550 gpm, 130 spm, 2000 psi, 4.1 Ok with, 140 rpm, 10-11k torque on bottom 9-1 Ok torque offbottom, 162k pick up weight, 854 shckoffweght, 1104 ratan, weight, 10.8 ppg ECD, 3,849' TVD, 8 has adjusted drill time.0 8,892 0 SPM with #2 pump, 30 spm -275 psi, 45 spm4OO psi. Drill from kS92'to 9,372' widr 550 gpm, 130 spm, 2,100 poi, 140 rpm, &10k wob, 11-12k torque m bosom, 104 torque off bosom, 1701,pickup weight, 80k slackoff weight, I lok rotate weight, I I.I Ppg ECD, 3,850' TVD. SPR, #3 pump, 30 spm310 psi. 45 spm -430 psi. 42 pump, 30 spm -300 psi, 45 spm430 psi.❑ 9,372.01500 -1530 -Top Drive Failure. Diagnosis] and repaired electrical signal Cimllate to reduce ECD and drag with 550 gpm 2,100 psi 130 spm mid 140 rpm. Drop to 9,372.0 10 9 PPB Drill fr9m9,3]2 to 9,562' with 550 gpm, 130 spm, 2,160 psi, 2-12k with, 140 rpm, 170k pick up weight, 75k slack offweight, 1071, rotate weighs 11-124 torque on bottom, IOk torque offbosom, 11.15 ppg ECD.❑ 9,562p ONO -0500 Drill ahead from 9,56T to 9,946' _ Drill from 9,562' to 10,043' with 550 g or ,130 spm, 2,200 psi, 4-I Ok wob, 140 in, 170k pick up wt.❑ 70k slack off wt 107k rotate wt. I I -12k torque on bosom, IOk torque off bosom, 3,840' 10,043.0 TVD, and 11.37 ppg ECD. 9,657.0 Circulate bottoms up, pull out of hole from 10,0,13' in 9,657. 9,717.0 Build 60' of bough from %65T 10 9.717' with 550 gpm, 130 spm, 2,130 psi, 140 rpm. Drill from 9,717' to 9,874' with 550 gpm, 130 spm, 2,230 psi, 140 rpm, 2-Sk with, IOk torque offboo. 11-12k torque on bon, 1684 pick up wt. 704 slack offwt, 107k rmate wt, 9,874.0 11,2 ppg ECD; and 5.17 he, adjusted drill time. Drill from 9,87,1' to 10,615' with 550 gpm, 130 spm, 2,3W psi, 140 in, 2-81, with, i 75 pick up wt. 75k slack off wt. 107k rotate wt. I 11, torque offbsn, 12-13k torque on bon. 10,615.0 11 4 ppg ECD, and ADT/631 hrs. Service top drive and rig. Take slow pump rates with #2 pump, 30 spm -310 psi, 45 spm - 10,615.0 450 psi. #3 pump, 30 spm -310 psi, 45 spm450 psi. Steel End Dor Phase Op Code S.r--od, n Nmr Sten (B) End (PI) Comments I 44 2230 0:00 150 DRILL E 3 P 10,6150 45 000 I&M 1000 DRILL, 45 1000 12M 2.00 DRILL E 7 P 11,475.0 45 1200 000 1200 DRILL E 3 P 114750 46 000 5.00 500 DRILL E 3 P 12,240.0 46 500 800 3.00 DRILL E 7 P 12,384.0 1 46 800 0:00 16W DRILL E 6 P 12,3840 47 000 400 400 DRILL E 6 P 12,384.0 47 400 5:30 150 DRILL E 7 P 12,384.0 47 5:30 1000 4.50 DRILL E 4 P 12,384.0 \� 47 1000 1330 3.50 DRILL E 4 P 12,1141 47 1330 2100 150 DRILL E 12 P 12,3840 47 2100 2200 1.00 DRILL E 12 P 12,384.0 47 2200 000 200 DRILL E 20 P 12,384.0 48 0:00 030 0.50 DRILL E 25 P 12,384.0 48 0:30 300 2.50 DML E 4 P 12,3840 48 300 1430 11.50 DRILL E 4 P 12,3840 48 1430 2200 7.50 DRILL E 7 P 12,384.0 48 22:00 0:00 2.00 DRILL E 4 P 12,3840 49 000 730 7.50 DRILL E 4 P 12,384.0 49 730 1030 3.00 DRILL E 4 P 12,3840 49 1030 1200 150 DRILL G 20 P 12,384.0 49 1200 2130 9.50 DRILL G 4 P 12,384.0 D 49 21:30 0:00 2.50 DRILL G 4 P 12,384.0 50 000 600 6.00 DRILL G 4 P 12,3840 50 600 8:00 200 DRILL G 7 P 12,384.0 50 11 800 930 1.50 DRILL G 19 P 12,3840 50 930 1030 100 DRILL G 7 P 12,384.0 50 1030 1500 4.50 DRILL G 25 P 12,384.0 50 1500 000 9.00 DRILL G 4 P 12,3840 51 000 100 100 DRILL E 4 P 12,384.0 51 1:00 2:00 1.00 DRILL E 25 P 12,384.0 51 200 1500 1300 DRIl E 4 P 12,384.0 Drill from 10,615' to 10,911' with all parameters same as above. 70 hm ADT.❑ 10,711.0 0000-0500 Drill from 10,71 F to 11,065'. Rotary drill f/ 11090' o' 11475', 550 GPM, 130 SPM ® 2430 psi. OFF, 2445 psi. ON, IIP WT = 180, ON WT = 65K, RT WT=107 K, TO ON 13-14K, TO OFF = 13K, 140 RPM, 11,475.0 ECD =11] 11265' MD 3906' TVD. Circulate and cordite. ® 550 GPM, 2430 psi. ECUs drop* to 11 .5, establish a slow 11,475.0 pump rate, M1® 30 SPM— 325 psi. 45 SPM= 490 psi. Service sig and top drive. Rotery drill 0 11475' t/ 11771'.550 GPM, 130 SPM ® 2430 psi. OFF, 2445 psi. ON, UP WT —180, DN WT= 65K, RT WT =107 K, TQ ON 13-14K, TQ OFF= 131, 140 RPM ECD =11.7, 11265' Md, 3915' TVD. ❑ 12,240 0 0000 - 0500 Drilling ahead to 12,384' MD. Circ & Cond. Drill ahead 84/2 hole F/1220'- ✓12384' / TVD 3932' (To w per Em Geologist)❑ Up 190, On 60, Rot 105, RPM 140, WOB 2 - 12, GPM 550, SPM 130, SPP 24800 12,384.0 Gas 35 units, ADT= 3.45 hrs, ECD 11.41 Circulate/ condition fluid, GPM 550, SPP 2450 psi. RPM 45, continue circulate shaker 12,3840 clean, tunings ream normal quantity / quality. No gain / loss. Flow check, PISM, Backream out hole 12384' - 7266' MD end of tour. Pais nomhole sidetrack. no difficulty, hale packing off with torque 8000 - 7960 R. Work fru, regain 100°%circulation. GPM 540, RPM 140.D 12,384.0 0000-05M Backrewn out hole, circulate at 9-5/8 she. Continue backream out hole 7266 - 5950 R. Wellbore packing off 7183 - 7163. Work free 12,384,0 GPM 550, SPP 1850. 12,384.0 Circulate clean at 9-58 caning shoe. No On / loss. Cuaings ream normal. 12,384.0 Resume POH to BHA. 12,384d Flow check, PISM, by down BHA 916. Download Iwd date. PJSM, test BOPE. all related equipment 250 / 35M psi. Perform time / volume / pressure test accumulator syswn. Test ...at.[, no re -test. ❑ 12,3840 Wiaesa wand Mr Lou Grimaldi AOGCC. 12,384.0 Rig down test equipment install wear ting. Note static losses approx 1.5 bph. Flow check, continued static losses at 1 bph. install temporary drip trp beneath rotary table.❑ 12,384.0 0000 - 0500 Install drip tarp, make up BHA M17 12,384.0 PISM, Service rig PISM, Complete assemble BHA MI6 (Hole Wm assembly). Flow check, UH same. 12,384 0 Continued static losses 1.5 bob. Flow check, follow BHA with 5" drill pipe to 12384 H (17D), fill pipe 20 stand intervals, 40 12,384.0 bbl loss during RHI. No brid8in8 / tight hole. Flow check, PJSM (Fluid displacement), commence displace wellbore Fluids to 9.2 ppg 12,384.0 "Versa Pro". L5 -2 bph dynamic losses. Shaker clew. 4 bpm / 500 psi. Up 180, 70 down. Flow check, PJSM, POH for liner ern. 10344 R at and of tour.❑ Mud losses of 1-2 bblamr, lou of approximately 50 bbls last 24 hour❑ 12,384.0 0000 - 05M FOR 5- drill pipe. 12,384.0 Continue POH 5" drillpipe to BHA. Nmmal drag. Losses 1 - 2 5 bph. Flow check, PISM, Lay down BHA MI6 Clear Floor / pipe shed unnecessary abulwa / 12,384 0 h ser ling tools. 12,384.0 PISM, Rig up all 5-1/2 liner mu equipment. PISM, Row check (1 bph losses), commence RIi 5-1/21iur ucemblq (Guide shoe, 12,384.0 Sloped, blanked, swell packer, Baker Packer). Rig down casing crew, clear floor. Rig up floor / 5" drillpipe handling equipment, Flow check PJSM, follow liner assembly with 5" drillpipe to 9037 B at and of tow 12,384.0 0000 - 0500 Run 5-1/2 liner PISM, flow check, Continue tun 5-1/2 liner, take weigh, no downward movemmt, begin 12,384.0 slow rotation from 10570 - tag at 12384 B Pick up to 12378 0, 12,384,0 PISM flow check, displace pipe volume, confirm clew, drop hall, pump to seat at packer. Seat ball, build pressure to 20M psi, set 30K on packs, build pressure W 3000 psi / 30 seconds, build to 4000 psi / 5 minutes, bled pressure. Test 5 K 9-5/8 annulus 250"'/ / 5 minutes. Packer aea test successful. Bleed annulus. Flow check. Shear from liner hangar, confirm released.❑ 12,384.0 Final depths—f.iAo.biv nifian Tin line. Hanver/Packer 57345ft 12,384.0 Circulate wellbore top of packer, pump weight pill. 12,384o PJSM, slip / cut drilling line. Service rig. PISM, flow check POD laying down 5" drillpipe. ii 12,384.0 0000 - 0500 Lay down 5" drillpipe. 12,384.0 Flow check, PJSM, lay down liner ern tool. Clew floor. 12,384.0 Service rig. 12,384.0 Flow check, tun in hole 5" drillpipe from mast pull out hole laying down same. IReport# Start End @rat phase Op Code SubCode Lane Snort (ft) End (R) Comment; 12,384.0 repairs. 12,384 0 Flow check Resume lay down 5" drillpipe. 12,384.0 Repair leak N2 at pipe handler. Flow check Reaume lay down 5" drillpipe. 15 joints remaining at end of tour.❑ 12,384,0 0000-0500 Lay down 5"drillpipe, not rams, prepare fm compledon. 12,384.0 Complete lay down 5" drillpipe. DO TO COWLETION PARSE 0300 FIRS 1228/08 51 1500 2000 500 DRILL E 25 T 12,3840 51 2000 21:00 1.00 DRILL E 4 P 12,384.0 \v 51 21:00 22:00 100 DRILL E 25 T 12,3840 51 2200 0:00 2.00 DRILL E 4 p 12,3840 52 0'.00 300 3.00 DRILL E 4 p 12,384.0 12,384.0 repairs. 12,384 0 Flow check Resume lay down 5" drillpipe. 12,384.0 Repair leak N2 at pipe handler. Flow check Reaume lay down 5" drillpipe. 15 joints remaining at end of tour.❑ 12,384,0 0000-0500 Lay down 5"drillpipe, not rams, prepare fm compledon. 12,384.0 Complete lay down 5" drillpipe. DO TO COWLETION PARSE 0300 FIRS 1228/08 I Well Name OP03-P05 port p Shit End "'art Ph..Op Code 8uh-Code Ti. T Start (f) 52 300 600 3.00 DRILL K 1200 P 12,3840 52 6:00 730 1.50DRB.L K 2000 P 12,384.0 52 730 12'30 SMI)RILL K 20.00 P 12,384.0 52 1230 000 113ODRILL K 20.00 P 12,384.0 53 0:00 3:00 3.00 DRILL K 2000 P 12,384.0 \^� 3:00 1200 9.00 DRILL K 20.00 P 12,384.0 �3 �) 53 1200 000 12.00DRILL K 4.00 P 12,384.0 54 0:00 230 2.50 DRILL K 400 P 12,384.0 54 230 1730 1500 DRILL K 25.00 T 12,3840 i 54 17:30 0:00 6 50 DRILL K 4.00 P 12,384.0 55 000 2'00 2.00 DRILL K 2000. P 12,3840 55 200 530 350 DRILL K 1200 P 12,384.0 55 5:30 000 18,50 DRILL K S 00 P 12,384.0 0 O 000 24.00 DRILL K 20.00 P 12,3840 56 57 000 930 9.50 DRILL K 2000 P 12,384.0 57 930 17:00 7.50 DRILL C SOO P 12,384.0 ,I 57 17'00 20:00 300 DRILL C 12.00 P 12,384.0 57 2000 22'30 2.50 DRILL C 5.00 P 12,384.0 57 2230 2330 100 DRILL C 1200 P 12,384.0 57 2330 000 0.50 DRILL C 1200 P 12,384.0 58 0:00 4:00 400 DRILL K 20.M P 12,384.0 `I 58 490 1000 600 DRILL K 9.00 P 12,3840 58 10:00 13:00 3 00 DRILL K 9.00 P 12,384.0 End (Ft) Comments PJSM, test upper variable rams on 4-1/2 cubim 250 / 35U0 psi 10 minutes. Test successful, 12,384 0 no re-tesu. Prepare 4-1/2 tubing during test. 12,384.0 Rig dawn BOPE test equpment, clear Boor, centinue prepare 4 -In robing. PJSM, place Schlumberger ESP equipment to rig Boo, spot spool, string and hung cable / 12,384.0 sheaves. Place casing crew equipment to rig Boo, dg up same. PJSM, Assemble ESP TM crossover with screen intake. Rig up slickline unit. Set pump / packoff / test plug. Ten same 1000 psi / 15 minutes. Test successful. Remove ten plug, sn cubing stop, rig down slickline unit. Place motor to sig floor, dress / inspect / service same. Rig up remaining ESP cable to work area. Make up pressure discharge sub top ofjoint Ioban, NI, orient makeup outward seal to TIC crossover sub. Test moor and gauge while splice pigtail to ESP line. 000 - 0500 Continue test motor / gauge, assemble remaining components. Rig up casing 12,384.0 crew. 12,3840 PJSM, confieue splice ESP cable t0 mato, testsame. Test successful. Install mandrel / chemical injection line, clamp / plumb in connections. Comma motor leads, re -test same. Test successful. Make up joint k2, Make ready injection line, protectaliews, 12,384 0 motor/ equipment clamps, all remaining components. Follow minor / pump vaembly with 4-1/2 completion robing. memw ESP cable and gauge at 1000 R intervals. Note losses at 1.5 - 2 bph while mn tubing. 0000-0230 Run 4-f/2 ESP corn tenoo to 4,642'.❑ W30 - 0700 Lay down 1 joint cu mg. Pickup 1 joint of drill pipe. Makeup cup drive. 12,384.0 Undo knot in drill line on dmwwmks. 12,384.0 Continue tun 4-1/2 ESP completion. McMer cable 1000 R intervals. Fouled line at drawworka dorm. PJSM. Lay down top joint, cut ESP lines (Precaution at for well control) Suspend top drive / remove fouled drilling One. Cut 400 It damaged drilling line. Re- splice electrical able / injection line due to precaution cut for well control. Test 12,384.0 spliced lines. Resume inn 4-1k tubing pick up 2 joints 5 -la double wall vacuum NR Make up tubing hunger, terminate fires, make connections to hanger, unroll penetrator, surface ten / mugger all connections. Tens successPol, no re -tests. Prepare land voting hanger. Used a total of 124 Cannon Single Channel cross coupling clamps, 4 la" x 4 1/2" and 2 - 4 1/2' x 5 IR' and f- 5 1/2" x 5 1/2'.0 12,384.00000-0500 I•and Wheat, banger. ten seals, de"n caller suadWhea banner. wa�seels, dean edla sue PJSM, complete ten ESP / injection line connections. Land rating hanger with 73K pounds. 12,384,0 Confirm hanger sated /aligned. Run in lack down screws. PJSM, Test hanger seats 250 / 5000 psi. 15 minute. Close nems, test top hanger, 12,384 0 penevatm, injection line connections I OW psi 115 minutes. All tests successful, n0 terms, PISM, clan / thaw scaffolding ROPE, cellar walls, all components. Prepare nipple down BOPE. ❑ 12,384.00000-0500 Comi uedean/Naweellararea. Coutinue clean / Naw ROPE, cellararca. Including Scaffolding cellarwulls and Floor, wellheads, drip per, choke / kill lines. Begin cut flashing at cellar wells. Remove choke kill lines while clean and thaw ❑ ❑ 12,384.00000-0500 Continuechoul Naw BOPE,cellarwast Continue clean / Naw cellar area for nipple dawn. PJSM, scaffolding crew disassemble Penial saBolding asmaunding BOP. Welder at old rotary chain guard hump from rig Door 12,384 0 Continue clean mud plus. PJSM, remove flowfine/ bell nipple, kill and choke lines. Install flange to choke line for freeze protect. Nipple down ROPE, at back on "stump'. Remove remaining saffolding 12,384.0 nipple down riser, mud moss. Set out for storage. Terminate control lines 9 tubing hanger, Centrilift Boal test at ESP cable terminals. Ten 12,384.0 successful, no re -tests. 12,3 84 0 PISM, install production Vee. Tenmen / seals, all Mated components 5000 psi / 15 minutes. All tests successful. Big 12,384.0 down test equipment. Remove two way check. Secure well. ❑ 00 00 - 05:00— R/IJ Lines to freeze protect well to diesel, well heed froze up. Thaw well had with hater Bunk (3 hours) OK. LRS Freeze protect well by pumping diad down 9- 5/8" is 4.5' woutas❑ 12,384,0 Taking returns up tubing, ICP @450 psi / I BPM at 1,1 recuma/pumped. Clear cellar, rig up for freeze paned well. Blow Brough lines, conflrm clear. Tics, lines 12,384.0 1000 psi, attempt pump outer annulus. Wellhead froze at valve. Rig up heaters, thaw same. PISM Commence freeze protect wall. Pump diesel down 9-58 K 4-12 annulus. ream through tubing to choke. Establish pump rate with "Little Red" 1 bpm ICP, 320 psi. At 320 bbls, choke back 1 bpm. FCP=400 psi / 378 bbls diesel with clean nares 6 9 ppg. Cats pumping, Rig down 'Line Red" Minx at 1030 hrs. Tubing 85 psi, Annulus 225 psi. 12,384.0 Maintain correct BHP with choke during procedure. Close wee valva. Blow down lines. Rig up lubricator, Install VR plug in OA. SET RPV 12,384fl THIS DATE 130 HIS, Reportp Start End (hrsl Phase OF Code Sub-Code PXT Share (TO End Ont) Comments PJSM, haul off OBM waste, continue clean pits, load vacwcks with residual from pitrig down remaining scaffolding in collar. Clean / pick up ng area. Prepare rig move. Function test moving system hydmuilies. Prepare "Lambson" table and crib blacks. Remove tunings tank 0 TOTAL FLUIDS LOST TO WELL DURING DRR.L- COMPLETE 1124bbIs0 SHIPPED 1,030 BARRELS OF VERSAPRO MUD 9.3 PPG TO M-1 SWACO MILD PLANT.❑ RELEASE NABORS RIG 245 THIS DATE 0000 HRS.❑ THIS IS THE FMAL REPORT FOR THE OPO3-P05 WELL.0 58 13:00 0:00 11.00 DRB.L K 100 P 12,3840 12,384.00000-0500 Rigdown/prepmanmwato OP26-DSP02 Transmittal Form February 23, 2009 AOGCC 333 W. 7th Ave., Ste. 100 Anchorage, AK 99501 eni Ein! Petroleum Re: Final Mudlogs and Mudlogging Report distribution for OP03-P05 Enclosed with this letter are the final Open Hole Logs for the recently drilled OP03-P05 well. The following data is included. Quanity Detailed Discription 1 Full set of logs 1 Mudlogging Report 1 Data Disk Thank -you, Andrew Buchanan Operations Geologist Nikaitchuq Development Eni Petroleum Revieved by: C, i Signature ,qcr "'r4666 Title -----Original Message ----- From: jason.brink@enipetroleum.com [mailto:jason.brink@enipetroleum.com) Sent: Thursday, November 27, 2008 1:09 AM To: Maunder, Thomas E (DOA) Subject: RE: OP03-P05 (208-137) (P7-11) Directional Thanks, Tom. Good talking with you. We will plug back the pilot hole with cement. Jason Brink Drilling Engineer ENI Alaska Office: 907-865-3321 "Maunder, Thomas E (DOA)" <tom.maunder@alas To ka.gov> <jason.brink@enipetroleum.com> cc 11/26/2008 03:18 PM Subject RE: OP03-PO5 (208-137) (P7-11) Directional Jason, This just closes the loop on our discussion earlier today. It is best to plan to cement up the pilot hole as originally authorized in the permit. Tom Maunder, PE AOGCC -----Original Message ----- From: jason.brink@enipetroleum.com [mailto:jason.brink@enipetroleum.com7 Sent: Wednesday, November 26, 2008 11:31 AM To: Maunder, Thomas E (DOA) Subject: Fw: OP03-PO5 (P7-11) Directional Tom This is the surveys, vertical section, and plan view of our plan to open hole sidetrack in the pilot hole above the OA sand reservoir top. Let's discuss. My cell: 947-3790 Jason Brink Drilling Engineer ENI Alaska Regg, James B (DOA) p7t From: Regg, James B (DOA) Sent: Wednesday, November 26, 2008 3:16 PM 1 an It(zb�2Z17o To: jack.keener@enipetroleum.com Cc: DOA AOGCC Prudhoe Bay; Maunder, Thomas E (DOA) Subject: RE: Kill line modification on Nabors rig 245e As discussed, we will allow you to continue with the hammer union in the kill line (kill line connection to the mud manifold); it must be replaced with either a flanged or hubbed connection before starting your next well. You also mentioned the LPR is currently being replaced (appeared to be leaking oil from ram body). Other items noted during this morning's inspection as needing attention: - position indicator; - pressure gauge; - continuously running pump on choke panel. We would appreciate a follow-up email when repairs have been completed. Thank you. Jim Regg AOGCC 333 W.7th Avenue, Suite 100 Anchorage, AK 99501 907-793-1236 -----Original Message ----- From: jack.keener@enipetroleum.com(mailto:jack.keener@enipetroleum.com] Sent: Wednesday, November 26, 2008 5:59 AM To: Regg, James B (DOA) Subject: Kill line modification on Nabors rig 245e Jim As you might know we had an initial BOP test this morning and the lower ram body failed on the hydraulic side. Chuck found a hammer union in the kill line, what I need to know if I can get time on a rig move to change it as the welding is estimated at 10-12 hrs. We change out one on the choke during the Moduspec commissioning, just missed the other one. Thankyou in advance Jack Keener, ENI Petroleum • • suiT [JiT Fri- z SARAH PALIN, GOVERNOR ALASKA OIL AND GAS 333 W 7th AVENUE, SUITE 100 CONSERVATION COMIMIISSION ANCHORAGE, ALASKA 99501 -3539 PHONE (907) 279 -1433 FAX (907) 276 -7542 Joseph Longo Drilling Engineer ENI US Operating Co. Inc. 3800 Centerpoint Dr. Ste 300 Anchorage, AK 99503 Re: Nikaitchuq, Nikaitchuq Undefined Oil Pool, OP03 -P05 ENI US Operating Co. Inc. Permit No: 208 -137 Surface Location: 3220' FSL, 1533' FEL, S5, T13N, R9E, UM Bottomhole Location: 2746' FSL, 4356' FEL, S28, T14N, R9E, UM Dear Mr. Longo: Enclosed is the approved application for permit to drill the above referenced development well. In accordance with 20 AAC 25.005(f), all records, data and logs acquired for the pilot hole must be clearly differentiated in both name OP- 03 -P05 PH and API number (50- 029 - 23396- 70 -00) from records, data and logs acquired for well (name on permit). The permit is approved subject to full compliance with 20 AAC 25.055. Approval to perforate, test or produce any reservoir within 500' of a property line where ownership or landownership changes is contingent upon issuance of a conservation order approving a spacing exception. ENI assumes the liability of any protest to the spacing exception that may occur. This permit to drill does not exempt you from obtaining additional permits or an approval required by law from other governmental agencies and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. When providing notice for a • ENI Permit No. 208 -137' 0P03 -P05' representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659 -3607 (pager). Sincerely, Daniel T. Seamount, Jr. Chair DATED this i day of September, 2008 cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. RECE � 4.r:M ,U G 2 6 2008 ;. ' 1 }! & Gas Cons. Commission Anchorage ! •,. STATE OF ALASKA t` `'�� G'r ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 1a. Type of Work: 1 b. Current Well Class: Exploratory ❑ Development Oil Q , 1c. Specify if well is proposed br. Drill 0 • Redrill ❑ Stratigraphic Test ❑ Service ❑ Development Gas ❑ Coalbed Methane ❑ Gas Hydrates ❑ Re -entry ❑ Multiple Zone ❑ Single Zone ❑ Shale Gas ❑ 2. Operator Name: 5. Bond Blanket 2 Single Well ❑ 11 Well Name and Nunber: Eni US Operating Co Inc Bond No. RLB0008627 OP03 -P05 3. Address: 6. Proposed Depth 12' Field /Pool(s): Eni US Operating Co. Inc. 3800 Centerpant Dr Suite 300, Anchorage, AK 99503 MD: 13,374' ' TVD: 3,971' • 4a Location of Well (Governmental Section): 7 Property De gnation2 114 35r (. 35' Nikaitchuq Surface: 3,220' FSL and 1533' FEL of S5, T13N, R9E, UM , 9/t'4 ADL 4 A�30s6Z3. j i pl vs Top of Productive Horizon: 601 FSL, 4395 FEL, S33, T14N, R9E, UM 8 Land Use Permit. 13. Approximate Spud Date ADL390616 �' 27 • 9/15/2008 Total Depth: 2,746' FSL and 4356' FEL of S28, T14N, R9E, UM 9 Acres in Property. 14. Distance to Nearest 1,280' Property: 4,356' 4b. Location of Well (State Base Plane Coordinates): NAD27 10. KB Elevation 15. Distance to Nearest Well Surface x- 51674643 • y- 6036573 69 " Zone- 4 (Height above GL) 52' feet Within Pool: 7,809' 16. Deviated wells' Kickoff depth: 350' feet 17 Maximum Anticipated Pressures in psig (see 20 AAC 25.035) Maximum Hole Angle: 9012 degrees Downhde: 1658 ' Surface: 1256 • 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 Weld 120' 36' 36' 160' • 160' . N/A 16 13 3/8 68 L -80 BTC 2,402' 35' 35' 2,437' • 2,152' - Lead = 2853ff '= 659 Sacks Tail= 386ft' '= 416 Sacks 12.25 9 5/8 47 L-80 BTC -M 5,905' 33' 33' 5,938' - 3,702' . Lead = 784fe'= 396 Sacks Lead = 561fF'= 483 Sacks 8 5 5 1/2 17 L -80 IBT -M 6,592' 5,738' 3,670' 12,330' ' 3,892 ' N/A 19 PRESENT WELL CONDITION SUMMARY (To be completed for Redrill and Re -Entry Operations) Total Depth MD (ft) Total Depth TVD (ft). Plugs (measured): Effect. Depth MD (ft) Effect. Depth TVD (ft): Junk (measured) Casing Length Size Cement Volume MD TVD Conductor /Structural Surface Intermediate Production Liner Perforation Depth MD(ft): Perforatbn Depth TVD (ft): 20. Attachments: Filing Fee ❑ BOP Sketch 2 Drilling Program Time v. Depth Plot 0 Shallow Hazard Analysis0 Property Plat ❑ Diverter Sketch ❑✓ Seabed Report❑ Drilling Fluid Program 20 MC 25.050 requrements0 21 Verbal Approval: Commission Representative: Date 22. I hereby certify that the foregoing is true and correct � Contact } Printed Name...,. I C.).c> L� Ai 6() Title 1 )'R1 L (..-ti k.) Lj 'i�ti( ih) ∎ = t=' Signature" 6 V Phone iG �Slos- '.sr2.. Date 2/ / G.s".2coca ..../ j Commission Use Only Permit to Drill API Number: Permit Approv See cover letter for other �" Number /37 50 -0 Z9 -2 339 6 r 0 6 Date: • ib 'Dt requirements. / Conditions of approval : If box is checked, well may not be used to explore for, test, or produce coalbed methane, gas hydrates, or gas contained in shale Other trO ®V � , w, . :0 4,...A (3 � �� Samples sera: Yes I No ❑ Mud bg req'd: Ye[� No❑ v \ H measures: Yes ❑ No Dire ctional svy req'd Ye[Vr No❑ 35 ps't 4ivcrQ a. A-z t , gOP- lcsk ,. r \ 4 1 eee��� JJJ (�J DATE: / ! / 4/ / APPROVED BY THE COMMISSION [/ J / l / , COMMISSIONER 0\IG\I • 1 Eni Petroleum 3800 Centerpoint Drive Suite 300 Anchorage, AK 99503 (907) 865 -3300 (907) 865 -3380 (Fax) August 25, 2008 Mr. John Norman, Chair Alaska Oil and Gas Conservation Commission 333 West 7 Ave., Suite 100 Anchorage, Alaska 99501 Subject: Application for Permit to Drill: OP03 -P05 Dear Mr. Norman, Eni US Operating Co. Inc. hereby applies for a Permit to Drill an onshore Production well for the Nikaitchuq Development at Oliktok Point. Eni US Operating Co. Inc. plans to utilize Nabors Rig 245 -E to drill, evaluate, and complete a directionally drilled Production well targeting the Schrader Bluff Sand. OP03 -P05 will be drilled from Oliktok Point Pad situated South East of ConocoPhilips Alaska Inc.'s existing Seawater Treatment Plant. Additional oil and gas wells will also be drilled and evaluated from this location. Waste drilling fluids and drilled cuttings will be transported to G &I #3 located on DS -04, Prudhoe Bay, for disposal. Please find the attached information as required by 20 AAC 25.005 (a) and (c) for your review. Pertinent information attached to this application includes the following: 1) Form 10 -401 Application for Permit to Drill 2) Proposed Fluids Program 3) Proposed Casing Program 4) Proposed Cementing Program 5) Proposed Drilling Program 6) Surface Platt 7) Days vs. Depth Curve 8) Proposed Wellbore Survey 9) Wellbore Schematic 10) Shallow Hazard Evaluation 11) Diagrams and descriptions of the BOP equipment to be used • The following are Eni US Operating Co. Inc.'s designated contacts for reporting responsibilities to the Commission: 1) Completion Report Joseph Longo, Drilling Engineer (20 AAC 25.070) (907) 865 -3323 2) Geologic Data and Logs Charles Russell, Subsurface Manager (20 AAC 25.071) (713) 393 -6251 If you have any questions or require additional information, please contact me at (907) 865 -3320 or Joseph Longo at (907) 865 -3323. Sincerely, Eni US Operating Co. Inc. A j) Maurizio Grandi Drilling and Completions Operations Manager enclosures cc: Joseph Longo — Eni US Operating Co. Inc Tom Gennings — Eni US Operating Co. Inc. 1 • Ens Petroleum RIM Application for Permit to Drill OP03- P05PB1 pilot, plug back uphole, then sidetrack drill the OP03 -P05, complete, then test. Well : Oliktok Point Slot 3 to Producing Lateral 5 OP03- P05PB1 pilot, plug back hole. ✓ OP03 -P05 Sidetrack, complete, then test. The Pilot Hole : OP03- P05PB1 will be drilled to tie in the Horizontal producer, The OP03 -P05 The scope of work is to Drill, Complete, and Test the primary objective, the OA Sand. Surface Location is 3,220' FSL and 1,533' FEL of S5, T13N, R9E, UM ASP NAD27 Zone 4 (X = 516,746.43 Y = 6,036,573.69) / ENI plans to drill (then plug) a pilot hole to locate the top of the OA Sand Pilot Hole ( OP03- P05PB1 ) TD Location is 693' FSL and 4,360' FEL of S33, T14N, R9E, UM ASP NAD27 Zone 4 (X = 519,150.00 Y = 6,039,240.11) at a depth of 6,014' MD / 3,801' TVD. Producer (0P03 -P05 ) TD Location is 2,746' FSL and 4,356' FEL of S28, T14N, R9E, UM ASP NAD27 Zone 4 (X = 519,150.00 Y = 6,046,663.90 ) at a depth of 13,374' MD / 3,971' TVD. • ENI plans to use Nabors 245E and start this work on or shortly after September - 15 - 2008. Nabors 245E, The Rig is currently mobilizing to site. Operations are anticipated to take 35 days. 1 1 Mud Program: 16" hole 13 -3/8" Surface Casing from surface to 2,437' MD / 2,152" TVD with 50.0° of inclination at interval TD. Water Base Mud - Thick Spud Mud through Permafrost - Low annular velocities - Rely on Viscosity to clean hole & stabilize permafrost. Slightly thinner below permafrost, with slightly higher annular velocities. The Base of Permafrost is estimated at 1,921' MD / 1,802' TVD. j Interval (MD) Density (ppg) PV (cP) YP (Lb / 100 Ft ") pH Funnel Vis Fluid Loss Surf - 1,921 8.8 - 9.2 30 - 55 50 - 70 9.0 - 9.5 300 - 400 NC - 8 1,921 - 2,437 9.2 - 9.2 30 - 55 40 - 60 250 - 300 < 8 12 -1/4" Pilot Hole to 6,014' MD / 3,801" TVD with 67.0° of inclination to locate the Offset Well: OP -11 OA Sand. Then Plug and sidetrack to drill 12 -1/4" hole 9- 5/8" Intermediate Casing to 5,938' MD / 3,702' TVD with 85.0° of inclination at interval TD. Synthetic (Mineral Oil) Base Mud for lubricity and well bore stability. Maintain minimum MW. Solids Control equipment is crucial. Interval (MD) Density (ppg) PV (cP) YP (Lb / 100 Ft ") Chlorides (mg /L) HPHT FL ES (v) 2,437 6,014 9.2 < 28 15 - 24 20k - 48k 4.0 - 6.0 >400 KOP - 5,938 8 -1/2" Hole - Tail to 13,374' MD / 3,971" TVD with 75.2- 90.1° of inclination over the interval. This interval is the horizontal lateral and extends the well from 2,703 to 10,127 ft vertical section, adding 7,424' of horizontal lateral, hopefully all within the primary objective, the Offset Well: OP -11 OA Sand. o' Synthetic (Mineral Oil) Base Mud - No Barite additions - Calcium Carbonate as weighting agent - CaCO3 sized to plug sand pore throats, limit dynamic filtration losses to sand. Try to maintain 80 ppb CaCo3. Interval (MD) Density (ppg) PV (cP) YP (Lb / 100 Ft') Chlorides (mg /L) HPHT FL ES (v) 5,938 - 13,374 9.2 < 28 15 - 24 20k - 48k 4.0 - 6.0 >400 Bit Program : Interval (MD) Footage Hole Bit Type TFA GPM 0 - 2,437 2,437 16" hole 13 -3/8" Surface Casing Mill Tooth 0.75 - 0.90 450 - 700 2,437 - 6,014 3,577 12 -1/4" Pilot Hole PDC 0.50 - 0.75 450 - 850 5,500 - 5,938 438 12 -1/4" hole 9 -5/8" Intermediate Casing 5,938 - 13,374 7,435 16" hole 13 -3/8" Surface Casing PDC 0.50 - 0.60 500 - 550 Casing Program: Casing Hole Top - Btm (MD) Footage Weight Wall Drift ID Grade Conn Burst Collapse Tensile 20 36 - 160 120 178.89 0.812 18.188 18.376 X -65 Weld 4,980 3,240 3,417 13 3/8 16.000 35 - 2,437 2,402 68 0.480 12.290 12.415 L -80 BTC 5,020 2,260 1,556 9 5/8 12.250 33 - 5,938 5,905 47 0.472 8.625 8.681 L -80 BTC -M 6,870 4,760 1,086 51/2 8.500 5,738 - 12,330 6,592 17 0.304 4.767 4.892 L -80 IBT -M NA NA - Survey Program: I 20" to TD I Survey program will be as such to remain in accordance with 20 AAC 25.050 (C) Drilling Waste Disposal Program: Cuttings Handling/ Gray water Cuttings generated from drilling operations, as well as gray water will be hauled using super suckers to G & I : located on DS -04, Prudhoe Bay, for disposal. Black Water Camp waste will be hauled to North Slope Borough Service Area 10. Construction and Debris Will be hauled to North Slope Borough Service Area 10. • • Formation Evaluation Program Open Hole: Cased Hole MWDILWD: Electric Line: Mud Log / MWD /LWD: Electric Line: Surface Hole GR / Res / PWD / Dir None Full Service None None Pilot Hole GR / Res / PWD / Dir + Den Neutron None Full Service None None Interm Hole GR / Res / PWD / Dir + Den Neutron None Full Service None None GR / Res / PWD / Dir + Den Neutron None Full Service None None Production Hole Try Geo Steering with Periscope None Full Service None None MUD Logging Program: Full Service Rig Monitoring: 1800'- TD PVT, Gas detection, H2S detection, and Flow -Show analysis and description. / Drill Cuttings Samples: 20 "- TD Two (2) Sets washed and dried on 30' intervals. Samples on 10' intervals in shows or zones of interest. • H2S Pogram: I H2S monitors will be used at all times in accordance with State Regulations. - Formation Markers: MD TVDss TVD Pore Press PP Plan MW Overbalance Formation: (ft) (ft) (ft) (psi) (ppg) (ppg) (psi) Base of Permafrost 1,921 1,750 1,802 796 8.8 " 9.2 • 66 Ugnu 3,783 2,775 2,827 1263 8.8 9.2 90 L. Ugnu 4,640 3,190 3,242 1451 8.8 9.2 100 Schrader Bluff 5,224 3,440 3,492 1565 8.8 9.2 105 N Sand 5,416 3,515 3,567 1599 8.8 9.2 107 OA Sand 5,938 3,650 3,702 1658 8.8 . 9.2 • 113 Offset Well: OP -11 OA Sand 3,768 1706 OIL GRADIENT 0.41 psi /ft . NOTE : BHP = 1,658psi = OP -11- Pressure - Gradient x TVD = 1,706psi - ( (3,768' - 3,650' ) x .41psi /ft ) = 1,706psi - (118' x .41psi /ft ) = 1,658 psi - *** WORST CASE MASP = 1,658 psi - (3,650' x .011 psi / ft) = 1,658 - 402 psi = 1,256 psi. - Note on Overbalance : MW is necessary for formation stability (not Well Control). No zone has the ability to flow to surface (The density and viscosity of the formation fluid is adequate to prevent flow from the well.) This was shown on Kerr McGee Offset Oliktok Point 1 -1 and 1 -2 drilled in 2007 ( in zone formation pressures and flow Test). ✓ Note on Shallowest KNOWN HYDROCARBON. / The Oliktok 1 -1 and 1 -2 are on the same pad. Based on these 2 nearby penetrations, the shallowest hydrocarbon will be theN Sand. Well Control A Vetco Gray 5,000 psi Multi -Bowl Well head system will be used. A 21 -1/4" - 2000psi diverter with 16" Diverter Line and Valve will be installed for drilling the 16" surface hole. The Diverter will be dry function tested. After running and cementing surface casing, the BOP stack will be used to drill the remainder of the well. The BOP stack is a 13 -5/8 "- 5000psi BOP Stack consisting of 3 rams and 1 annular in the following order. Bottom - -- one (1) BLIND ram, two (2) PIPE rams, and the 13 -5/8" -5000 psi annular preventer - -- TOP. All initial installation tests for rams and valves will be to the rated working pressure of 5,000psi. All subsequent tests (unless new equipment is installed) will be to 3500psi. All tests (including initial) on the annualar will be to 3,500 psi. BOPE Equipment will be tested every seven (7) days. The Oliktok Point, OP -11 & OP -12 were drilled by KerrMcGee in 2006 - 2007 (with ENI personnel on location). ENI acquired the field, and has all the well information. NO WELL CONTROL incidents were seen on the OP -11 and OP -12 (Our SAME FIELD DIRECT OFFSETs). ✓ I 'WORST CASE MASP = 1,658 psi - (3,650' x .011 psi / ft) = 1,658 - 402 psi = 1,256 psi. I • 1 Cement Program: 16" hole 13 -3/8" Surface Casing from surface to 2,437' MD / 2,152" TVD with 50.0° of inclination at interval TD. Cement Type Interval (MD) Footage Casing Hole bL / Ft bL Excess Density Yield Ft"/ Sx Sacks Artic Set 1,937 13 3/8 16 0.0749 145.1 - Lite 0 1,937 10.7ppg 4.33 188.1 Lead 1 362.8 250% 470.4 507.9 659 Cement Type Interval (MD) Footage Casing Hole bL / Ft bL Excess Density Yield Ft'/ Sx Sacks Class G 1,937 - 2,437 500 13 3/8 16 0.0749 37.5 15.7ppg 0.93 226.4 18.8 50% 113.2 Tail Shoe Track 85 12.415 0.1497 12.7 76.7 0.0 0% 0 Base of Permafrost is at 1,921 MD 1,802 TVD ' 69.0 416 Total bL Cement 576.8 The Surface casing cement iob will be done throuah an inner string of Drill Pipe, The small down DP volume allows cement returns to be established before starting to pump tail. The excess lead may be sent back to cement company without causing unnecessary waste. 12 -1/4" hole 9 -5/8" Intermediate Casing from surface to 5,938' MD / 3,702" TVD with 85.0° of inclination at interval TD. Cement Type Interval (MD) Footage Casing Hole bL / Ft bL Excess Density Yield Ft'/ Sx Sacks Class G 2,437 - 4,938 2,502 9 5/8 12 1/4 0.0558 139.6 12.8 ppg 1.98 395.9 Lead 0 . 0 0% 0 139.6 396 Cement Type Interval (MD) Footage Casing Hole bL / Ft bL Excess Density Yield Ft'/ Sx Sacks Class G 4,938 - 5,938 1,000 13 3/8 16 0.0749 74.9 15.7ppg 1.16 362.5 18.7 25% 90.6 Tail Shoe Track 85 8.681 0.0732 6.2 30 0.0 I 0% 0 Ugnu is at 3,783 MD 2,827 TVD 99.8 483 L. Ugnu is at 4,640 MD 3,242 TVD Total bL Cement 239.4 Schrader Bluff is at 5,224 MD 3,492 TVD N Sand is at 5,416 MD 3,567 TVD OA Sand is at 5,938 MD 3,702 TVD The N Sand is at 5,416' MD or 3,567' TVD. This is the shallowest known hydrocarbon based on our 2 in -Field well (OP -11 & OP -12) offsets. TOC is being brought to the last shoe using a scavenging lead slurry. This should enhance the chances of having a quality cement job at the shoe. After cementing, the backside annulus will be displaced with diesel. • t l Eni Petroleum NIKATICHUQ PROJECT — OLIKTOK POINT NORTH SLOPE, ALAKSA OP03 -P05 OP03 -P05 DRILLING PROCEDURE MIRU 1. MIRU Nabors 245E, camps, communications, rig instrumentation, directional drilling equipment,IWD equipment, 'gas detectors, PVT, Flo -Show, Mud Logging, diverter line, etc. 2. N/U 21 -1/4" diverter. Configure and function test the diverter system with the AOGCC Field Supervisor present to witness the test. 3. Install weather barrier around sub base 16" - Surface Hole Section: 4. Take on water and /or mix spud mud. Make sure all solids control equipment is operating at capacity. Test run the pumps, Top Drive, SCR, Draw Works, and all equipment prior to accepting the rig. 5. Clean out 20" Conductor to 160', if necessary. PU 5" drill pipe and rack in the derrick. PU 5" HWDP and rack same. PU 16" Surface Hole BHA with GR /Res /Dir /PWD tools. Prepare to spud. 6. Directionally drill to Surface Casing Point. Control drill if necessary as limited by the solids control equipment. Use super suckers and vac trucks to haul off the waste generated while drilling. The planned Surface Casing Point is ±2437' MD/ 2152' TVD. 7. At Surface Casing Point circulate the hole clean. Make a wiper trip. CBU. Pump out to the HWDP and finish POOH. LD LWD tools as necessary. 8. RU to run 13 -3/8" Surface Casing. 9. If while drilling the 16" surface section, losses are experienced or excessive washout is expected install the TAM Port collar at 1000' MD. Install the Stab - In Float collar and centralizers as per program. 10. Run 13 -3/8" 68 ppf Surface casing to ±2437' MD/ 2152' TVD. Reciprocate if possible. (Land immediately if hole becomes sticky.) Land the mandrel hanger in the Vetco Gray Multi -Bowl Wellhead as programmed. Land casing as close to rig floor as possible and RU to run drill pipe. 11. Screw Stab -in stinger to bottom of drill pipe. Run drill pipe in hole. Upon reaching Stab -in Float equipment slowly lower the drill pipe until stung in. 12. Update cement program with actual open hole and casing setting depths. Begin to pump cement. After circulating cement to surface, drain, and wash out the diverter stack. 13. Remove the diverter spool. NU and test the 5000 psi 13 -5/8" BOP's. Test the BOPE to 250 psi/ 5000 psi. This test is to commission the BOPE. • EN1i Petroleum NIKATICHUQ PROJECT — OLIKTOK POINT NORTH SLOPE, ALAKSA OP03 -P05 Subsequent tests shall be tested to 250 psi/ 3500 psi. The AOGCC field inspector shall be notified to witness the BOP test. 14. PU the 12 -1/4" BHA. RIH to float collar. Test the casing to 2500 psi and chart for 30 min. 15. Swap Water Based Mud System to Mineral Oil Based Mud System 16. Drill out the shoe track and 15' of new hole. Circulate the hole clean. Conduct and chart an FIT at the 13 -3/8" shoe to 11.5 ppg EMW. If the shoe test leaks off before 11.5 ppg FIT test is reached, notify the drilling superintendent. 12 -1/4" - Pilot Hole Section: 17. Drill 12 -1/4" Hole to Planned Pilot Hole Section TD at ±6014 MD/ 3801' TVD. Insure that the top and bottom of all zones of interest are recorded as set forth in geologic program. 18. At TD, circulate hole clean. POOH to the 13 -3/8" shoe and circulate bottoms up. Finish POOH. LD MWD /LWD tools as necessary. 12 -114" - Pilot Hole PIuq Back Section: 19. RU to set cement plug. 20. RIH to TD and circulate hole clean. Set balance plug as per plan. Circulate and drop drill pipe wiper. POOH and LD Cement Stinger. MU 12 -1/4" sidetrack BHA while WOC. 21. RIH and tag top of cement plug. Polish cement plug to proposed KOP based on logs. 22. Sidetrack well 12 -1/4" — Intermediate Hole Section: 23. Drill ahead to planned 12 -1/4" Intermediate Hole section at ±5938' MD/ 3702' TVD. Circulate hole clean Make a wiper trip. CBU. Pump out to the HWDP and finish POOH. LD LWD tools as necessary. 24. RU to run 9 -5/8" Intermediate Casing. 25. Run and set 9 -5/8" 47 ppf Casing at ±5938' MD/ 3702' TVD, placing centralizers as per plan. Reciprocate 9 -5/8" Casing if possible (Land immediately if hole becomes sticky.) Circulate cement as per plan. Land 9- 5/8" Casing hanger in Vetco Gray Multi -Bowl Wellhead as per program. 26. RU to bull head diesel Freeze protect in 13 -5/8" x 9 -5/8" Annulus 27. NU and test the 5000 psi 13 -5/8" BOP's. Test the BOPE to 250 psi/ 3500 psi. The AOGCC field inspector shall witness the BOP test. 28. PU the 8 -1/2" BHA. RIH to float collar. Test the casing to 2500 psi and chart for 30 min. • • Eni petroleum Id NIKATICHUQ PROJECT — OLIKTOK POINT NORTH SLOPE, ALAKSA OP03 -P05 29. Displace hole to MOBM system as per mud program 30. Drill out the shoe track and 15' of new hole. Circulate the hole clean. Conduct and chart a FIT at the 9 -5/8" shoe to 11.5 ppg EMW. If the shoe test leaks off before 11.5 ppg FIT test is reached, notify the drilling superintendent. 8 -1/2" — Production Hole Section: 31. Drill ahead to planned 8 -1/2" Production Hole section at ±13374' MD/ 3971' TVD. Circulate the hole clean. Make a wiper trip. RIH back to bottom and Circulate hole clean. 32. Once shakers have cleaned up displace to solids free mud system 33. POOH. LD MWD /LWD tools as necessary. 34. RU to run 5 -1/2" Slotted Liner 35. Run and set 5 -1/2" 17# Slotted Liner at ±12330' MD/ 3892' TVD. Run centralizers as per plan. 36. Set Liner 5 -1/2" x 9 -5/8" Liner Hanger. 37. Displace above the hanger to inhibitive brine. 38. RU to run 4 -1/2" 12.6 ppf Tubing and Electric Submersible Pump. Land 4- 1/2" Tubing in hanger and test pack -off. 39. RD Tubing handling equipment. ND BOP's. NU Tree and Test. RD Nabors 245E. 0 • REV DATE BY CK APP DESCRIPTION REV DATE BY CK APP DESCRIPTION W O XX !� OLIKTOK T OLIKTOK � OPP INTAKE DOCK �R ' � �' THIS - P e '.. 4 PROJECT � _O TANK -- i N e a P y , DS -3R O DEW U ED ` SITE SIP i TANK S A NG AREA •, MODULES — I ' D S - 3o • T13N, R9E - :r '$ :i' C i * Q \4 15 SCALE: pi-3o 1" = 150' 11 !9 .:: rib t; ' STP PAD \ VICINITY MAP / \ \ SCALE: 1" = 1 Mile / 0 0 % \ \ \ c \ -0 -o \ \ X0 _ \ -. \ OLIKTOK POINT PAD \ \ a aso \ \ /\ \ \ / \ 1 \ \ / 1 � 1, \ / , \ • As Built Conductor \ \ o Proposed Well Locations \ / \ \ / / LOUNSBURY \ / /� & ASSOCI ► s, INC. SEE SHEET 2 FOR NOTES / % RS ENGINEERS PLEBS AREA: MODULE: UNIT: � ! Petroleum OPP PAD ion PR OPOSED WELL LOCATIONS am_ CADD FILE NO. I DRAWING NO: PART: REV: LK601D715 8/19/08 NSK 6.01 —d715 1 OF 2 I 0 i REV DATE BY CK APP DESCRIPTION REV DATE BY CK APP DESCRIPTION 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. PROTRACTED SECTION 5, T. 13 N., R. 9 E., UMIAT MERIDIAN Well Ak State Plane Sec Line PAD 0.G. No. 'Y' 'X' Latitude(N) Longitude(W) Offset NOffsF.E.L. ELEV. ELEV. OP —I1 6,036,332.70 1,656,791.89 70' 30' 39.015" 149' 51' 57.587" 2,052' 1,519' 12.1' 4.0' OP -12 6,036,328.85 1,656,784.83 70' 30' 38.977" 149' 51' 57.795" 2,056' 1,526' 12.2' 4.0' 0P03 —P05 6,036,325.09 1,656,777.67 70' 30' 38.940" 149' 51' 58.006" 2,059' 1,534' 12.2' 4.0' / Bold Indicates Proposed Well Locations. PROPOSED DISPOSAL WELLS Well Ak State Plane Sec Line PAD O.G. No. 'Y' 'X' Latitude(N) Longitude(W) Offset F.E.L. ELEV. ELEV. OP -25 6,036,006.04 1,656,514.94 70' 30' 35.808' 149' 52' 05.767' 2,378' 1,798' OP -26 6,036,013.56 1,656,529.09 70' 30' 35.881" 149' 52' 05.349' 2,370' 1,784' LOUNSBURY & ASSOCIATES, INC. O RURYEYGRS ENGINEERS PLANNERS AREA: MODULE: UNIT: Eni OPP PAD Erd P ROPOSED WELL LOCATIONS CADD FILE NO. DRAWING NO: PART: REV: LK601D715 8/1 9/08 I NSK 6.01 —d715 I 2 OF 2 I 0 • • OP03 -P05 Days vs. Depth 13 -3/8" CSG @ 2436' MD/ 2152' TVD I - - - ; . - - 2000 1 1 1 I I I I I I 1 11 12 -1/4 Plug Back 1 16" Hole II - , -'- - I 1 I -- - - - -,- - -- 4000 I I I I 1 1 • I 1 I I - - - i - - - - ; - , - 1- - -I I - -- - - - I 1 - , ' - -- r - - I - -- ' ' 1 I I ICI I I 1 I -- I I 1 1, , - - -- - 1 I I I I I I I I 1 I I I 6000 • 1 1 I I i 11 1 I 1 1 1 1 I 1 1 I 1 1 1 1 I - 1 1 8000 _ 12 -1/4" Pilot Hole 1 1 11 1 1 1 '- - -- I 1- - JI, -- - -y - - 1 - - - _ _'_ 1 - - - 4 - I ! - - I I- 1 - - : . 1 - a I ,� @ 9 -5/8 CSG 5962 MD/ 3702 TVD I 10000 I ' 1 1 1 1 1 1 1 1 1 1 1 1 I I , I 1 , 1 I 1 I 1 I 1 I I 1 1 1 1 1 1 1 1 I 11 1 1 1 1 1 1 1 1 1 1 1 12000 I I , I I I 1 1 I I I 1 1 8 -1/2" Hole - - - r 1 1 < - I 1 1 1 I I 14000 1 5 -1/2" Liner @ 12353' MD/ 3892' TVD 1 rr r 16000 1 1 1 1 - 0 5 10 15 20 25 30 35 Days . . Petroleum $cblumberger OP03- OP5PB1 (P5) Proposal Report Date: August 21, 2008 Survey 1 DLS Computation Method: Minimum Curvature / Lubinski Client: ENI Vertical Section Azimuth: 40.000° Field: Nikaitchuq Vertical Section Origin: N 0.000 ft, E 0.000 ft Structure 1 Slot: Oliktok Point I OP03 '' ■ St udy TVD Reference Datum: Rotary Table Well: OP03 -0P5 TVD Reference Elevation: 52.00 ft relative to MSL Borehole: OP03- 0P5PB1 FeaS ■ Sea Bed 1 Ground Level Elevation: 12.00 ft relative to MSL UWIIAPI #: 50029 Magnetic Declination: 22.561° Survey Name/ Date: OP03- OP5PB1 (P5) I August 21, 2008 Total Field Strength: 57659.037 nT Tort I AHD 1 DDI 1 ERD ratio: 135.946° /4047.47 ft / 5.940 / 1.065 Magnetic Dip: 80.929° Grid Coordinate System: NAD27 Alaska State Planes, Zone 04, US Feet ✓ Declination Date: September 21, 2008 Location LatiLong: N 70.51110759, W 149.86296286 Magnetic Declination Model: BGGM 2008 al Location Grid NIE YIX: N 6036573.689 ftUS, E 516746.428 ftUS / North Reference: True North Grid Convergence Angle: +0.12918578° Total Corr Mag North -> True North: +22.561° Grid Scale Factor: 0.99990032 Local Coordinates Referenced To: Well Head Measured Vertical Mag 1 ' Directional Comments Inclination Azimuth Sub -Sea ND ND NS EW DLS Northing Easting Latitude Longitude Depth Section Tool Face Difficulty (ft ) (deg) (deg) (k) (ft) (ft) ( tt) (ft) (deg) (degl100ft) Index (8US) (ftUS) RTE 0.00 0.00 27.00 -52.00 0.00 0.00 0.00 0.00 - -- 0.00 0.00 6036573.69 516746.43 N 70.51110759 W 149.86296286 WRP 40.00 0.00 27.00 -12.00 40.00 0.00 0.00 0.00 -- 0.00 0.00 6036573.69 516746.43 N 70.51110759 W 149.86296286 KOP Bld 1.5/100 350.00 0.00 27.00 298.00 350.00 0.00 0.00 0.00 27.00M 0.00 0.00 6036573.69 516746.43 N 70.51110759 W 149.86296286 400.00 0.75 27.00 348.00 400.00 0.32 0.29 0.15 27.00M 1.50 0.00 6036573.98 516746.58 N 70.51110838 W 149.86296165 Bld 2.5/100 450.00 1.50 27.00 397.99 449.99 1.28 1.17 0.59 27.00M 1.50 0.29 6036574.86 516747.02 N 70.51111077 W 149.86295800 500.00 2.75 27.00 447.95 499.95 3.08 2.82 1.44 27.00M 2.50 0.94 6036576.51 516747.86 N 70.51111529 W 149.86295111 600.00 5.25 27.00 547.70 599.70 9.88 9.03 4.60 HS 2.50 1.73 6036582.73 516751.01 N 70.51113226 W 149.86292520 Gyro Point 650.00 6.50 27.00 597.44 649.44 14.86 13.59 6.93 HS 2.50 2.00 6036587.30 516753.32 N 70.51114472 W 149.86290619 700.00 7.75 27.00 647.05 699.05 20.91 19.12 9.74 HS 2.50 2.22 6036592.83 516756.13 N 70.51115982 W 149.86288316 800.00 10.25 27.00 745.81 797.81 36.15 33.06 16.84 HS 2.50 2.58 6036606.78 516763.19 N 70.51119789 W 149.86282505 Cry 3/100 850.00 11.50 27.00 794.91 846.91 45.34 41.46 21.13 46.64R 2.50 2.73 6036615.19 516767.46 N 70.51122085 W 149.862790* 900.00 12.58 32.01 843.81 895.81 55.59 50.52 26.27 41.74R 3.00 2.87 6036624.26 516772.59 N 70.51124560 W 149.862747 1000.00 14.95 39.78 940.94 992.94 79.27 69.67 40.30 34.19R 3.00 3.11 6036643.44 516786.57 N 70.51129790 W 149.86263311 1100.00 17.51 45.39 1036.96 1088.96 107.15 90.14 59.26 28.81R 3.00 3.32 6036663.96 516805.48 N 70.51135385 W 149.86247795 1200.00 20.19 49.58 1131.59 1183.59 139.15 111.90 83.11 24.84R 3.00 3.50 6036685.77 516829.28 N 70.51141328 W 149.86228280 1300.00 22.94 52.81 1224.59 1276.59 175.17 134.87 111.78 21.83R 3.00 3.66 6036708.80 516857.90 N 70.51147604 W 149.86204822 1400.00 25.75 55.38 1315.69 1367.69 215.13 159.00 145.19 19.49R 3.00 3.80 6036733.00 516891.25 N 70.51154196 W 149.86177483 1500.00 28.59 57.47 1404.64 1456.64 258.91 184.22 183.26 17.63R 3.00 3.93 6036758.30 516929.25 N 70.51161084 W 149.86146339 1600.00 31.47 59.21 1491.21 1543.21 306.40 210.45 225.86 16.12R 3.00 4.04 6036784.63 516971.79 N 70.51168250 W 149.86111476 1700.00 34.36 60.69 1575.16 1627.16 357.45 237.63 272.90 14.88R 3.00 4.15 6036811.91 517018.76 N 70.51175675 W 149.86072988 1800.00 37.26 61.96 1656.25 1708.25 411.94 265.69 324.23 13.85R 3.00 4.26 6036840.08 517070.03 N 70.51183338 W 149.86030982 1900.00 40.18 63.07 1734.26 1786.26 469.71 294.54 379.73 12.98R 3.00 4.35 6036869.05 517125.45 N 70.51191219 W 149.85985571 WellDesign Ver SP 2.1 Bld( doc4ox_100) OP03\ OP03- 0P5 \OP03- OP5PB1 \OP03- OP5PB1 (P5) Generated 8/21/2008 12:35 PM Page 1 of 3 Measured Vertical Mag 1 Grav I Directional Comments Inclination Azimuth Sub -Sea TVD TVD NS EW DLS Northing Easting Latitude Longitude Depth Section Tool Face Difficulty D (ft) (deg) (deg) (ft) (ft) (ft ) (ft) (ft) (deg) (degl100ft ) Index (ftUS) (ftUS) 2000.00 43.11 64.06 1808.98 1860.98 530.61 324.10 439.23 12.25R 3.00 4.44 6036898.75 517184.88 N 70.51199295 W 149.85936882 2100.00 46.04 64.94 1880.20 1932.20 594.46 354.30 502.58 11.62R 3.00 4.52 6036929.09 517248.16 N 70.51207544 W 149.85885046 2200.00 48.99 65.74 1947.73 1999.73 661.10 385.05 569.59 11.08R 3.00 4.60 6036959.99 517315.10 N 70.51215944 W 149.85830207 End Cry 2234.44 50.00 66.00 1970.10 2022.10 684.66 395.76 593.49 - -- 3.00 4.63 6036970.74 517338.96 N 70.51218868 W 149.85810654 13 -3/8" Csg 2436.52 50.00 66.00 2100.00 2152.00 823.80 458.72 734.91 - -- 0.00 4.72 6037034.02 517480.23 N 70.51236066 W 149.85694926 Cry 3/100 2441.19 50.00 66.00 2103.00 2155.00 827.01 460.18 738.18 38.53R 0.00 4.73 6037035.48 517483.49 N 70.51236463 W 149.85692253 2500.00 51.39 67.41 2140.25 2192.25 867.66 478.17 779.97 37.64R 3.00 4.76 6037053.57 517525.24 N 70.51241376 W 149.85658053 2600.00 53.79 69.68 2201.01 2253.01 937.41 507.20 853.89 36.26R 3.00 4.83 6037082.76 517599.09 N 70.51249304 W 149.85597565 2700.00 56.22 71.81 2258.36 2310.36 1007.79 534.19 931.22 35.04R 3.00 4.89 6037109.92 517676.35 N 70.51256675 W 149.85534283 2800.00 58.70 73.83 2312.14 2364.14 1078.62 559.07 1011.76 33.95R 3.00 4.95 6037134.98 517756.82 N 70.51263469 W 149.85468381 2900.00 61.20 75.74 2362.22 2414.22 1149.69 581.77 1095.27 32.99R 3.00 5.01 6037157.86 517840.28 N 70.51269667 W 149.8540003 3000.00 63.73 77.56 2408.45 2460.45 1220.81 602.23 1181.54 32.15R 3.00 5.06 6037178.52 517926.49 N 70.51275253 W 149.8532944 3019.38 64.22 77.90 2416.95 2468.95 1234.59 605.93 1198.56 -- 3.00 5.07 6037182.26 517943.50 N 70.51276263 W 149.85315518 Cry 3/100 3019.53 64.22 77.90 2417.02 2469.02 1234.69 605.95 1198.69 104.90L 0.00 5.07 6037182.28 517943.62 N 70.51276270 W 149.85315414 3100.00 63.62 75.30 2452.40 2504.40 1292.71 622.70 1268.99 103.76L 3.00 5.11 6037199.18 518013.88 N 70.51280842 W 149.85257881 3200.00 62.95 72.03 2497.36 2549.36 1367.04 647.81 1354.70 102.29L 3.00 5.16 6037224.49 518099.52 N 70.51287699 W 149.85187747 3300.00 62.35 68.72 2543.32 2595.32 1443.65 677.64 1438.34 100.77L 3.00 5.21 6037254.50 518183.09 N 70.51295842 W 149.85119297 3400.00 61.83 65.37 2590.14 2642.14 1522.33 712.09 1519.69 99.20L 3.00 5.25 6037289.13 518264.36 N 70.51305249 W 149.85052719 3500.00 61.39 62.00 2637.70 2689.70 1602.88 751.08 1598.54 97.60L 3.00 5.30 6037328.29 518343.10 N 70.51315895 W 149.84988196 3600.00 61.04 58.60 2685.86 2737.86 1685.06 794.49 1674.65 95.96L 3.00 5.34 6037371.87 518419.11 N 70.51327749 W 149.84925904 3700.00 60.77 55.18 2734.51 2786.51 1768.64 842.20 1747.82 94.29L 3.00 5.38 6037419.74 518492.17 N 70.51340780 W 149.84866015 Ugnu 3782.70 60.61 52.34 2775.00 2827.00 1838.68 884.83 1805.98 92.90L 3.00 5.41 6037462.49 518550.23 N 70.51352421 W 149.84818417 3800.00 60.59 51.75 2783.49 2835.49 1853.42 894.10 1817.86 92.61L 3.00 5.41 6037471.79 518562.09 N 70.51354952 W 149.84808691 3900.00 60.49 48.30 2832.68 2884.68 1939.14 950.02 1884.57 90.92L 3.00 5.45 6037527.86 518628.66 N 70.51370226 W 149.84754091 4000.00 60.49 44.85 2881.95 2933.95 2025.58 1009.83 1947.77 89.22L 3.00 5.48 6037587.81 518691.71 N 70.51386560 W 149.84702364 4100.00 60.58 41.41 2931.15 2983.15 2112.49 1073.36 2007.28 87.52L 3.00 5.52 6037651.46 518751.08 N 70.51403910 W 149.84653651 4200.00 60.75 37.97 2980.16 3032.16 2199.64 1140.42 2062.94 85.84L 3.00 5.55 6037718.64 518806.58 N 70.51422228 W 149.84608086 4300.00 61.01 34.55 3028.84 3080.84 2286.80 1210.85 2114.60 84.18L 3.00 5.58 6037789.18 518858.07 N 70.51441463 W 149.84565795 4400.00 61.36 31.15 3077.05 3129.05 2373.72 1284.44 2162.11 82.54L 3.00 5.61 6037862.87 518905.42 N 70.51461563 W 149.8452689 4500.00 61.79 27.78 3124.66 3176.66 2460.16 1360.99 2205.35 80.93L 3.00 5.64 6037939.51 518948.48 N 70.51482474 W 149.8449148 4600.00 62.30 24.43 3171.55 3223.55 2545.88 1440.30 2244.20 79.36L 3.00 5.67 6038018.90 518987.15 N 70.51504137 W 149.84459672 Lower Ugnu 4639.85 62.53 23.10 3190.00 3242.00 2579.80 1472.63 2258.44 78.75L 3.00 5.68 6038051.26 519001.31 N 70.51512966 W 149.84448015 4700.00 62.90 21.12 3217.58 3269.58 2630.66 1522.15 2278.56 77.84L 3.00 5.69 6038100.82 519021.32 N 70.51526493 W 149.84431538 4800.00 63.57 17.84 3262.63 3314.63 2714.26 1606.31 2308.32 76.36L 3.00 5.72 6038185.03 519050.88 N 70.51549481 W 149.84407162 4900.00 64.31 14.61 3306.57 3358.57 2796.45 1692.55 2333.40 74.94L 3.00 5.75 6038271.32 519075.77 N 70.51573039 W 149.84386609 5000.00 65.12 11.41 3349.29 3401.29 2877.00 1780.64 2353.74 73.57L 3.00 5.77 6038359.44 519095.91 N 70.51597101 W 149.84369938 5100.00 66.01 8.26 3390.66 3442.66 2955.70 1870.32 2369.29 72.27L 3.00 5.80 6038449.16 519111.25 N 70.51621602 W 149.84357193 5200.00 66.95 5.16 3430.58 3482.58 3032.33 1961.37 2379.99 71.03L 3.00 5.83 6038540.22 519121.75 N 70.51646474 W 149.84348410 End Cry 5205.10 67.00 5.00 3432.58 3484.58 3036.18 1966.05 2380.41 - -- 3.00 5.83 6038544.90 519122.15 N 70.51647751 W 149.84348068 Schrader Bluff 5224.10 67.00 5.00 3440.00 3492.00 3050.51 1983.47 2381.93 - -- 0.00 5.83 6038562.33 519123.64 N 70.51652511 W 149.84346816 WellDesign Ver SP 2.1 Bld( doc40x_100) OP03\ 0P03- 0P5 \OP03- OP5PB1 \OP03- OP5PB1 (P5) Generated 8/21/2008 12:35 PM Page 2 of 3 Measured Vertical Mag !Gray Directional Comments Inclination Azimuth Sub -SeaTVD TVD NS EW DLS Northing Easting Latitude Longitude Depth Section Tool Face Difficulty (ft) (deg) (deg) (ft) (ft) (ft) (ft ) (ft ) (deg) (deg1100ft ) Index (ftUS) (ftUS) Top N Sand 5416.05 67.00 5.00 3515.00 3567.00 3195.24 2159.49 2397.33 - 0.00 5.86 6038738.36 519138.64 N 70.51700595 W 149.84334166 5449.32 67.00 5.00 3528.00 3580.00 3220.33 2190.00 2400.00 - -- 0.00 5.86 6038768.87 519141.24 N 70,51708930 W 149.84331973 Base N Sand 5518.42 67.00 5.00 3555.00 3607.00 3272.43 2253.37 2405.54 -- 0.00 5.87 6038832.24 519146.64 N 70.51726240 W 149.84327419 Top OA Sand 5761.56 67.00 5.00 3650.00 3702.00 3455.76 2476.32 2425.05 - -- 0.00 5.91 6039055.22 519165.64 N 70.51787146 W 149.84311394 5863.93 67.00 5.00 3690.00 3742.00 3532.96 2570.20 2433.26 - -- 0.00 5.92 6039149.10 519173.64 N 70.51812791 W 149.84304647 TD , 6013.93 67.00 5.00 3748.61 3800.61 , 3646.06 2707.75 2445.30 - -- 0.00 5.94 6039286.67 519185.37 N 70.51850366 W 149.84294760 Survey Error Model: SLB ISCWSA version 24*** 3 -D 95.00% Confidence 2.7955 sigma Surveying Proq: MD From (ft ) MD To (ft ) EOU Freq Survey Tool Type Borehole -> Survey 0.00 40.00 1/100.00 SLB_NSG +SSHOT -Depth Only OP03- OP5PB1 -> OP03- OP5PB1 (P5) 40.00 650.00 1/100.00 SLB_NSG +SSHOT OP03- OP5PB1 -> OP03- OP5PB1 (P5) • 650.00 6013.93 1/100.00 SLB_MWD +GMAG OP03- OP5PB1 -> OP03- OP5PB1 (P5) Legal Description: Northing (Y) [ftUS1 Eastinq (X) [ftUSl Surface : 3220 FSL 1533 FEL S5 T13N R9E UM • 6036573.69 516746.43 BHL : 648 FSL 4360 FEL S33 T14N R9E UM 6039286.67 519185.37 Ilk WellDesign Ver SP 2.1 Bld( doc40x_100) OP03\ 0P03- 0P5 \0P03- OP5PB1 \0P03- OP5PB1 (P5) Generated 8/21/2008 12:35 PM Page 3 of 3 1 l Petroleum $chlumberger OP03 -0P5 (P8) Proposal Report Date: August 21, 2008 Survey 1 DLS Computation Method: Minimum Curvature / Lubinski Client: ENI Vertical Section Azimuth: 1.000° Field: Nikaitchuq Vertical Section Origin: N 0.000 ft, E 0.000 ft Structure 1 Slot: Oliktok Point / OP03 St udy TVD Reference Datum: Rotary Table Well: OP03 -0P5 TVD Reference Elevation: 52.00 ft relative to MSL Borehole: OP03 -0P5 FeasibilitY Sea Bed 1 Ground Level Elevation: 12.00 ft relative to MSL UWIIAPI #: 50029 Magnetic Declination: 22.549° Survey Name/ Date: OP03 -0P5 (P8) / August 21, 2008 Total Field Strength: 57660.026 nT Tort 1 AHD 1 DDI 1 ERD ratio: 192.401° / 11423.79 ft / 6.869 / 2.877 Magnetic Dip: 80.929° Grid Coordinate System: NAD27 Alaska State Planes, Zone 04, US Feet Declination Date: September 30, 2008 Location LatlLong: N 70.51110759, W 149.86296286 Magnetic Declination Model: BGGM 2008 III Location Grid NIE YIX: N 6036573.689 ftUS, E 516746.428 ftUS North Reference: True North Grid Convergence Angle: +0.12918578° Total Corr Mag North a True North: +22.549° Grid Scale Factor: 0.99990032 Local Coordinates Referenced To: Well Head Measured Vertical I Mag /Gray Directional Comments Inclination Azimuth Sub -Sea TVD TVD NS EW DLS Northing Easting Latitude Longitude Depth Section Tool Face Difficulty ry (ft ) (deg) (deg) (ft) (ft) (ft) (ft ) (ft ) (deg) (deg1100ft ) Index (ftUS) (ftUS) KOP Cry 4/100 5449.32 67.00 5.00 3528.00 3580.00 2231.55 2190.00 2400.00 40.51L 0.00 5.86 6038768.87 519141.24 N 70.51708929 W 149.84331973 5500.00 68.55 3.59 3547.17 3599.17 2278.38 2236.78 2403.51 39.98L 4.00 5.88 6038815.65 519144.64 N 70.51721708 W 149.84329090 5600.00 71.63 0.88 3581.22 3633.22 2372.36 2330.71 2407.15 39.05L 4.00 5.90 6038909.58 519148.07 N 70.51747369 W 149.84326086 5602.93 71.73 0.80 3582.15 3634.15 2375.15 2333.49 2407.19 - -- 4.00 5.91 6038912.37 519148.10 N 70.51748129 W 149.84326052 5606.04 71.73 0.80 3583.12 3635.12 2378.10 2336.45 2407.23 2.91L 0.00 5.91 6038915.32 519148.14 N 70.51748936 W 149.84326017 5700.00 75.48 0.60 3609.64 3661.64 2468.22 2426.56 2408.33 2.85L 4.00 5.93 6039005.42 519149.04 N 70.51773553 W 149.84325090 5800.00 79.47 0.40 3631.32 3683.32 2565.82 2524.15 2409.19 2.81L 4.00 5.96 6039103.01 519149.67 N 70.51800215 W 149.84324364 5900.00 83.47 0.20 3646.15 3698.15 2664.68 2623.03 2409.71 2.78L 4.00 5.99 6039201.88 519149.97 N 70.51827226 W 149.84323910 End Cry / Heel Tgt 5938.32 85.00 0.13 3650.00 3702.00 2702.81 2661.16 2409.82 - -- 4.00 6.00 6039240.00 519150.00 N 70.51837642 W 149.84323809 9 -5/8" Csg 5938.44 85.00 0.13 3650.01 3702.01 2702.92 2661.27 2409.82 - -- 0.00 6.00 6039240.11 519150.00 N 70.51837672 W 149.84323809 Cry 4/100 5958.32 85.00 0.13 3651.74 3703.74 2722.73 2681.08 2409.87 180.00L 0.00 6.00 6039259.92 519150.00 N 70.51843084 W 149.84323767 6000.00 83.33 0.13 3655.98 3707.98 2764.18 2722.54 2409.96 180.00L 4.00 6.01 6039301.38 519150.00 N 70.51854411 W 149.84323679 End Cry 6056.51 81.07 0.13 3663.65 3715.65 2820.16 2778.52 2410.09 - -- 4.00 6.03 6039357.36 519150.00 N 70.51869705 W 149.84323561 Cry 4/100 6078.53 81.07 0.13 3667.06 3719.06 2841.92 2800.28 2410.14 HS 0.00 6.03 6039379.11 519150.00 N 70.51875648 W 149.84323515 6100.00 81.93 0.13 3670.24 3722.24 2863.14 2821.51 2410.18 HS 4.00 6.04 6039400.34 519150.00 N 70.51881448 W 149.84323471 O -P5 Tgt 1 6189.22 85.50 0.13 3680.00 3732.00 2951.80 2910.18 2410.38 HS 4.00 6.06 6039489.00 519150.00 N 70.51905672 W 149.84323283 6200.00 85.93 0.13 3680.81 3732.81 2962.55 2920.93 2410.41 HS 4.00 6.06 6039499.75 519150.00 N 70.51908608 W 149.84323260 6300.00 89.93 0.13 3684.41 3736.41 3062.45 3020.84 2410.63 HS 4.00 6.09 6039599.65 519150.00 N 70.51935903 W 149.84323049 End Cry 6304.85 90.12 0.13 3684.41 3736.41 3067.30 3025.69 2410.64 - -- 4.00 6.09 6039604.50 519150.00 N 70.51937227 W 149.84323039 Cry 4/100 6492.24 90.12 0.13 3684.00 3736.00 3254.68 3213.09 2411.07 179.53R 0.00 6.12 6039791.88 519150.00 N 70.51988421 W 149.84322644 O -P5 Tgt 2 6495.37 90.00 0.13 3684.00 3736.00 3257.80 3216.21 2411.07 180.00L 4.00 6.13 6039795.00 519150.00 N 70.51989275 W 149.84322637 6500.00 89.81 0.13 3684.01 3736.01 3262.43 3220.84 2411.08 180.00L 4.00 6.13 6039799.63 519150.00 N 70.51990540 W 149.84322627 WellDesign Ver SP 2.1 Bld( doc40x_100) OP03 \OP03- 0P5 \OP03- 0P5 \OP03 -0P5 (P8) Generated 8/21/2008 12:38 PM Page 1 of 3 I Measured Vertical Mao 1 ace Directional Comments Inclination Azimuth Sub -Sea ND ND NS EW DLS Northing Fasting Latitude Longitude Depth Section Tool Face Difficulty (ft ) (deg) I (deg) I (ft) I (8) (8) (ft) (ft ) (deg) I (deg1100ft ) Index I (8US) I (8US) End Cry 6522.32 88.92 0.13 3684.25 3736.25 3284.75 3243.16 2411.13 - 4.00 6.13 6039821.95 519150.00 N 70.51996637 W 149.84322580 Cry 4/100 6758.39 88.92 0.13 3688.70 3740.70 3520.75 3479.19 2411.67 LS 0.00 6.17 6040057.96 519150.00 N 70.52061117 W 149.84322082 O -P5 Tgt 3 6771.44 88.40 0.13 3689.00 3741.00 3533.80 3492.24 2411.70 180.00L 4.00 6.17 6040071.00 519150.00 N 70.52064681 W 149.84322054 End Cry 6785.66 87.83 0.13 3689.47 3741.47 3548.01 3506.45 2411.73 - -- 4.00 6.18 6040085.21 519150.00 N 70.52068564 W 149.84322024 Cry 4/100 7045.90 87.83 0.13 3699.32 3751.32 3808.03 3766.50 2412.31 LS 0.00 6.21 6040345.24 519150.00 N 70.52139606 W 149.84321475 O -P5 Tgt 4 7061.68 87.20 0.13 3700.00 3752.00 3823.79 3782.27 2412.35 180.00L 4.00 6.22 6040361.00 519150.00 N 70.52143913 W 149.84321442 End Cry 7075.88 86.63 0.13 3700.76 3752.76 3837.97 3796.45 2412.38 - -- 4.00 6.22 6040375.18 519150.00 N 70.52147787 W 149.84321412 Cry 4/100 7303.85 86.63 0.13 3714.16 3766.16 4065.52 4024.02 2412.89 LS 0.00 6.25 6040602.73 519150.00 N 70.52209956 W 149.84320931 O -P5 Tgt 5 7317.15 86.10 0.13 3715.00 3767.00 4078.79 4037.29 2412.92 180.00L 4.00 6.26 6040616.00 519150.00 N 70.52213582 W 149.84320903 End Cry 7327.50 85.69 0.13 3715.74 3767.74 4089.12 4047.62 2412.95 - -- 4.00 6.26 6040626.33 519150.00 N 70.52216403 W 149.84320881 Cry 4/100 8023.40 85.69 0.13 3768.09 3820.09 4782.96 4741.54 2414.51 HS 0.00 6.34 6041320.18 519150.00 N 70.52405972 W 149.8431941 O -P5 Tgt 6 8036.25 86.20 0.13 3769.00 3821.00 4795.78 4754.36 2414.54 HS 4.00 6.35 6041333.00 519150.00 N 70.52409475 W 149.84319388 End Cry 8050.58 86.77 0.13 3769.88 3821.88 4810.08 4768.66 2414.57 - -- 4.00 6.35 6041347.30 519150.00 N 70.52413381 W 149.84319358 Cry 4/100 8338.62 86.77 0.13 3786.09 3838.09 5097.63 5056.24 2415.22 HS 0.00 6.38 6041634.85 519150.00 N 70.52491944 W 149.84318751 0-P5 Tgt 7 8356.79 87.50 0.13 3787.00 3839.00 5115.77 5074.40 2415.26 HS 4.00 6.39 6041653.00 519150.00 N 70.52496903 W 149.84318712 End Cry 8374.54 88.21 0.13 3787.66 3839.66 5133.51 5092.13 2415.30 - -- 4.00 6.39 6041670.74 519150.00 N 70.52501749 W 149.84318675 Cry 4/100 8762.79 88.21 0.13 3799.79 3851.79 5521.52 5480.19 2416.18 HS 0.00 6.43 6042058.75 519150.00 N 70.52607760 W 149.84317855 O -P5 Tgt 8 8770.04 88.50 0.13 3800.00 3852.00 5528.77 5487.44 2416.19 HS 4.00 6.44 6042066.00 519150.00 N 70.52609740 W 149.84317840 End Cry 8773.65 88.64 0.13 3800.09 3852.09 5532.37 5491.04 2416.20 - -- 4.00 6.44 6042069.61 519150.00 N 70.52610725 W 149.84317832 Cry 4/100 9133.29 88.64 0.13 3808.60 3860.60 5891.88 5850.59 2417.01 HS 0.00 6.48 6042429.11 519150.00 N 70.52708947 W 149.84317072 O -P5 Tgt 9 9167.18 90.00 0.13 3809.00 3861.00 5925.76 5884.48 2417.09 90.00L 4.00 6.48 6042463.00 5191 50.00 N 70.52718205 W 149.84317001 End Cry 9167.20 90.00 0.13 3809.00 3861.00 5925.78 5884.50 2417.09 - -- 4.00 6.48 6042463.02 519150.00 N 70.52718211 W 149.84317000 Cry 4/100 9486.20 90.00 0.13 3809.00 3861.00 6244.74 6203.49 2417.81 90.00R 0.00 6.52 6042781.98 519150.00 N 70.52805354 W 149.84316326 O -P5 Tgt 10 9486.22 90.00 0.13 3809.00 3861.00 6244.76 6203.51 2417.81 180.00L 4.00 6.52 6042782.00 519150.00 N 70.52805360 W 149.84316326 End Cry 9498.73 89.50 0.13 3809.05 3861.05 6257.27 6216.02 2417.84 - -- 4.00 6.52 6042794.51 519150.00 N 70.52808777 W 149.84316300 Cry 4/100 9833.76 89.50 0.13 3811.98 3863.98 6592.25 6551.03 2418.59 0.47R 0.00 6.55 6043129.49 519150.00 N 70.52900299 W 149.84315592 O -P5 Tgt 11 9836.27 89.60 0.13 3812.00 3864.00 6594.75 6553.54 2418.60 HS 4.00 6.55 6043132.00 519150.00 N 70.52900984 W 149.84315587 End Cry 9840.01 89.75 0.13 3812.02 3864.02 6598.50 6557.29 2418.61 - -- 4.00 6.55 6043135.75 519150.00 N 70.52902008 W 149.84315579 Cry 4/100 10292.07 89.75 0.13 3813.99 3865.99 7050.50 7009.34 2419.63 179.06R 0.00 6.60 6043587.75 519150.00 N 70.53025501 W 149.843146230 O - P5 Tgt 12 10293.32 89.70 0.13 3814.00 3866.00 7051.75 7010.59 2419.63 178.75L 4.00 6.60 6043589.00 519150.00 N 70.53025842 W 149.84314620 End Cry 10294.28 89.66 0.13 3814.01 3866.01 7052.71 7011.55 2419.63 - -- 4.00 6.60 6043589.96 519150.00 N 70.53026104 W 149.84314618 Cry 4/100 10796.34 89.66 0.13 3816.97 3868.97 7554.70 7513.60 2420.76 LS 0.00 6.64 6044091.96 519150.00 N 70.53163257 W 149.84313557 10800.00 89.52 0.13 3817.00 3869.00 7558.36 7517.26 2420.77 LS 4.00 6.64 6044095.62 519150.00 N 70.53164257 W 149.84313549 O -P5 Tgt 13 10800.38 89.50 0.13 3817.00 3869.00 7558.74 7517.64 2420.77 179.60L 4.00 6.64 6044096.00 519150.00 N 70.53164360 W 149.84313549 End Cry 10803.21 89.39 0.13 3817.03 3869.03 7561.58 7520.47 2420.78 - -- 4.00 6.64 6044098.84 519150.00 N 70.53165136 W 149.84313543 Cry 4/100 11265.29 89.39 0.13 3821.98 3873.98 8023.57 7982.52 2421.82 179.47R 0.00 6.68 6044560.84 519150.00 N 70.53291360 W 149.84312566 O -P5 Tgt 14 11267.45 89.30 0.13 3822.00 3874.00 8025.73 7984.68 2421.83 179.41L 4.00 6.68 6044563.00 519150.00 N 70.53291950 W 149.84312561 End Cry 11269.45 89.22 0.13 3822.03 3874.03 8027.73 7986.68 2421.83 -- 4.00 6.68 6044565.00 519150.00 N 70.53292497 W 149.84312557 Cry 4/100 11702.04 89.22 0.13 3827.91 3879.91 8460.23 8419.23 2422.80 LS 0.00 6.72 6044997.50 519150.00 N 70.53410661 W 149.84311642 O -P5 Tgt 15 11707.54 89.00 0.13 3828.00 3880.00 8465.73 8424.73 2422.82 179.47L 4.00 6.72 6045003.00 519150.00 N 70.53412163 W 149.84311631 WellDesign Ver SP 2.1 Bld( doc40x_100) OP03 \OP03 0P5 \OP03 0P5 \OP03 - 0P5 (P8) Generated 8/21/2008 12:38 PM Page 2 of 3 I Measured Vertical Mag 1 Grav Directional Comments Inclination Azimuth Sub-Sea ND ND NS EW DLS Northing Easting Latitude Longitude Depth Section Tool Face Difficulty (ft) (deg) I (deg) (ft) (ft) (ft) (k) (ft) (deg) (deg1100ft ) Index (kUS) (ftUS) Latitude End Cry 11709.76 88.91 0.13 3828.04 3880.04 8467.96 8426.95 2422.82 - 4.00 6.72 6045005.23 519150.00 N 70.53412772 W 149.84311626 Cry 4/100 12232.16 88.91 0.13 3837.97 3889.97 8990.20 8949.26 2424.00 179.22R 0.00 6.76 6045527.48 519150.00 N 70.53555457 W 149.84310521 O -P5 Tgt 16 12233.69 88.85 0.13 3838.00 3890.00 8991.72 8950.78 2424.00 178.93L 4.00 6.76 6045529.00 519150.00 N 70.53555873 W 149.84310518 End Cry 12234.80 88.81 0.13 3838.02 3890.02 8992.83 8951.89 2424.01 - -- 4.00 6.76 6045530.11 519150.00 N 70.53556177 W 149.84310516 5-1/2" Lnr Pt 12329.64 88.81 0.13 3840.00 3892.00 9087.64 9046.71 2424.22 - 0.00 6.77 6045624.93 519150.00 N 70.53582081 W 149.84310315 Cry 4/100 12602.17 88.81 0.13 3845.68 3897.68 9360.08 9319.18 2424.83 LS 0.00 6.79 6045897.37 519150.00 N 70.53656515 W 149.84309739 O -P5 Tgt 17 12614.81 88.30 0.13 3846.00 3898.00 9372.72 9331.82 2424.86 180.00L 4.00 6.79 6045910.00 519150.00 N 70.53659967 W 149.84309712 End Cry 12628.11 87.77 0.13 3846.46 3898.46 9386.01 9345.11 2424.89 - -- 4.00 6.79 6045923.30 519150.00 N 70.53663599 W 149.84309684 Cry 4/100 12805.79 87.77 0.13 3853.38 3905.38 9563.53 9522.66 2425.29 LS 0.00 6.81 6046100.82 519150.00 N 70.53712101 W 149.84309309 O -P5 Tgt 18 12819.98 87.20 0.13 3854.00 3906.00 9577.71 9536.84 2425.32 180.00L 4.00 6.81 6046115.00 519150.00 N 70.53715975 W 149.8430927 End Cry 12832.06 86.72 0.13 3854.64 3906.64 9589.76 9548.89 2425.35 -- 4.00 6.81 6046127.05 519150.00 N 70.53719268 W 149.843092 Cry 4/100 12976.90 86.72 0.13 3862.94 3914.94 9734.35 9693.50 2425.68 LS 0.00 6.82 6046271.64 519150.00 N 70.53758772 W 149.8430894 13000.00 85.79 0.13 3864.44 3916.44 9757.40 9716.55 2425.73 LS 4.00 6.82 6046294.69 519150.00 N 70.53765069 W 149.84308898 O -P5 Tgt 19 13007.33 85.50 0.13 3865.00 3917.00 9764.71 9723.86 2425.75 180.00L 4.00 6.83 6046302.00 519150.00 N 70.53767066 W 149.84308883 End Cry 13031.76 84.52 0.13 3867.12 3919.12 9789.05 9748.20 2425.80 - -- 4.00 6.83 6046326.34 519150.00 N 70.53773715 W 149.84308831 Cry 4/100 13108.30 84.52 0.13 3874.43 3926.43 9865.22 9824.38 2425.97 LS 0.00 6.83 6046402.51 519150.00 N 70.53794528 W 149.84308670 O -P5 Tgt 20 13123.86 83.90 0.13 3876.00 3928.00 9880.71 9839.87 2426.01 180.00L 4.00 6.84 6046418.00 519150.00 N 70.53798758 W 149.84308637 End Cry 13132.84 83.54 0.13 3876.98 3928.98 9889.63 9848.79 2426.03 - -- 4.00 6.84 6046426.92 519150.00 N 70.53801195 W 149.84308618 Cry 4/100 13165.69 83.54 0.13 3880.68 3932.68 9922.27 9881.43 2426.10 LS 0.00 6.84 6046459.56 519150.00 N 70.53810114 W 149.84308550 13200.00 82.17 0.13 3884.94 3936.94 9956.31 9915.47 2426.18 LS 4.00 6.84 6046493.60 519150.00 N 70.53819413 W 149.84308478 13300.00 78.17 0.13 3902.02 3954.02 10054.81 10013.99 2426.40 LS 4.00 6.86 6046592.10 5191 50.00 N 70.53846325 W 149.84308269 O -P5 Tgt 21 13314.22 77.60 0.13 3905.00 3957.00 10068.71 10027.89 2426.43 LS 4.00 6.86 6046606.00 519150.00 N 70.53850122 W 149.84308240 TD 13373.80 • 75.22 0.13 3919.00 3971.00 . 10126.61 10085.79 2426.56 - -- 4.00 6.87 6046663.90 519150.00 N 70.53865941 W 149.84308116 Survey Error Model: SLB ISCWSA version 24*** 3 -D 95.00% Confidence 2.7955 sigma Surveying Proq: MD From (ft 1 MD To (ft ) EOU Freq Survey Tool Type Borehole -> Survey 0.00 40.00 1/100.00 SLB_NSG + SSHOT -Depth Only OP03- OP5PB1 -> OP03- OP5PB1 (P5) 40.00 650.00 1/100.00 SLB_NSG +SSHOT OP03- OP5PB1 -> OP03- OP5PB1 (P5) 650.00 5449.32 1/100.00 SLB_MWD +GMAG OP03- OP5PB1 -> OP03- OP5PB1 (P5) i 5449.32 13373.80 1/100.00 SLB_MWD +GMAG OP03 -0P5 -> OP03 -0P5 (P8) Legal Description: Northing (Y) fftUSl Eastinq (X) fftUS1 Surface : 3220 FSL 1533 FEL S5 T13N R9E UM • 6036573.69 516746.43 Target : 601 FSL 4395 FEL S33 T14N R9E UM 6039240.00 519150.00 BHL : 2746 FSL 4356 FEL S28 T14N R9E UM - 6046663.90 519150.00 WellDesign Ver SP 2.1 Bld( doc40x_100) OP03 \OP03- 0P5 \OP03- 0P5\0P03 -0P5 (P8) Generated 8/21/2008 12:38 PM Page 3 of 3 Ps En! Petroleum Schlumberger 1 WE LL FIELD STRUCTURE OP03- OP5PB1 (P5) / OP5 (P8) I Nikaitchuq I Oliktok Point MaBnelic Pa,ametera Surface Localbn NAD27 Alaska SOle Planes, Zone 04, US Feet I MisceMiscellaneous R+lery Motlet. BGGM2008 Dip: 80.929° Dale'. Seplem0er 30.2008 L91'. N70 30 39287 Northing ° 6036573.691 (US Grid Cons. .0.12918578• Slot: Slot: OP 03 ND Ref: TM (52.006 above MSL) Mag Dec: +22.549• FS. 57660.0 nT Lon'. W149 51 46.666 Ea0in99 516746.43 RUS Scale Fad: 0.9999003186 Pb, : OP030P5 (Pe) SOy Dale: 7+9;9121,2008 0 1200 2400 3600 RTE 0 $..1.---* YVRP 0 ,......_KOP Bld 1.51100 • a"""nBid 2.5/100 Gyro Point Cry 3/100 . 0 1200 1200 0 0 1200 )0 9600 S • ` - ' End Crd 0 • 0 RTE II 1 34/8" Csg WRP Cro 3/100 KOP Bid 1.5 /100 8 . Bld 2.5/100 CO Gyro Point 0 2400 0 •••• 2400 Cry 3/100 Cry 3/100 1200 End Cry /Heel Tgt • cr vc 1200 _.._.._.._.._.._. _.. -.. _..- .. -.... .. _.._ ._.._.._. . KOP Cry 4 /100 - lowerTlgnu• - •• ~ • - • - •• '•_••_" End Cry Cry 4/100 N 3600 - .._.._.._.._.._ _.._..-.._.._.. _..- : : : : : : : : : : : : : : : : lZ a n d f =::: .: ._::_:: ! 3600 Cry _ - End C _..- ..- .._.._.._. .._.._.._.._.._.._.. -..- .- .... -.._.. 7dp Ol{S'a'i8' Cry ••- •• -•• -• / , 0P03 -0P5 (PS) • C 13418" Csg • D k" Cry 3/104 0P03 -0P5PB1 (P D II at 2400 Cry 3100 0 1200 2400 3600 2400 8 Vertical Section (ft) Azim = 40 °, Scale = 1(in):1200(ft) Origin = 0 N / -S, 0 E / -V to 0 - ..- .._.._._.._.._.._.._.._.. ._.._.._.._.._.._..__.._.._.._.._.._.._.._.._.._.._.._. ._..___.._.._.._.._.._.._.._.._ _.._.._.._.._.._.._.._.._.._.._.._.._..-.._.._.._.. _.._.._.._.._.._.._.._.._.._ Cry 4/100 F- a.nu : End Cry /HdelTgt KOP Cry 4/100 9 -5/8" Cog C, 41100 C End Cry Cry 4 /100 10-E 5 Tgt 3 End Cry nd Cry 0-PS Tgt 5 O -PS Tgt 19 9 I O -PS Tgt 1 . .._.. Cry 4/100 End Cry 0.F.5 Tgt Tgt 11 0-P5 Tgt 17 End Cry End Cry Cr a 4!100 End Crs ..p5 Tgt 9 Cry 4!100 End C -P,5 Tgt 13 0 -P5 Tgt 15 Cry 41100 End Cry Cry 41100 Ivzder. �liE�':::::_ ::_::_::;.._.._.._.:_::_::_.. -' . �PO3 -oasl • ! PS .._.._.. _.._.._.._.._ •_.._ ,..._:.�cvaiao_. rte_..- • -..-.7,,: m.ccv._cw.4uo� Eoa�cnr.._.._..- - - - ;,. t 2 , 3 6 0 0 _.. - .._.._.._ ._.._.._. :ase a " an' .._. .._.. .._..� �`� - .._.._.._.._5_. L r *-TD �l l l � � Iii • TO Cry 4/100 End Cry End C ' •P03 - 0P5 (P8) • 0 -P5 Tgt 2 Cry 41100 End Cry Cry 4/100 Cry x/10 Cry 4/100 E Cry Cry 4 Cry 4!100 Cry 4/100 0- PS.Tgt 4 Cry 4/100 End Cry End Cry : End Cry O -PS Tot 12 0-P5 Tgt 14 0 -P5 Tgt 16 End Cry 0-P5 Tgt 6 0 -P5 Tgt 18 9 O -PS Tgt8 0-P5 Tgt 10 End Cry End &v Cl-PS TO 20 5-1/2" Lnr Pt Cry 4/100 0 1200 2400 3600 4800 6000 7200 8400 9600 Vertical Section (ft) Azim = 1°, Scale = 1(in):1200(ft) Origin = 0 N / -S, 0 E/ -V • • it Eni Petroleum Schlumberger Eni WELL FIELD STRUCTURE OP03- OP5PB1 (P5) / OP5 (P8) Nikaitchuq Oliktok Point !Pape. Parameter su4aca Location 5424027 Alaska Slate Plan., zone 04. US Feet 7Mecelbnaaus Mal 6GGM2008 Op 60929' Dale September 30. 2000 Lal 54703009921 Notbrg: 603657369 RUS G. Cons .012918578' I Sld: OP03 7V0 Pal RMary Table (SC 00 R above MSL) Ma9 Da. .22549' FS'. 576900 nT Lon W1495146.666 Ea9.g: 516746 43 PUS Scab Feol 0 90 99903186 Plan: 0P030P5 (P8) Srvy Date'. Aug.121.2008 ' -1500 0 1500 3000 4500 10500 10500 OP03 -0P5 (P8) TO End Cry 075 Tgt 21 07S Tgt 20 Cry 4/100 C 4/100 EnQ Cry dry 0 -P5 Tgt 19 End Cry Cry < /100 9-P5 Tgt 18 Eno Cry Cry 4/100 54/2" Lnr Pt O;P5 Tgt 17 9000 ... Grv 9000 End Cry 045 Tgt 16 N .Cry 4/100 End Cry ' End Cry _ O-P5 tgt 15 Cry 41160 - Q75 Tgt 14 ry C 4/100 End (.7v 7500 "'tr75 ro-13 7500 End Cry Cry 44100 075 Tgt 12 Cry 4/100 End Cry 075 Tgt 11 A End Cry Cry 41 00 A Q75 Tgt 10 A Z 6000 0 : Cry 41100 .... EOC dx a 6000 0- P5(fgt 9 0= End Cry ry C4/i00 O O 075 Tgt 8 LO Cry 41100 End Qry C 0 -05 rgt 7 End Cry Cry 41 00 075 Tgt 6 N Cry 4/100 U 4500 4500 U CO End Ctv Cl) End Cry 075 tgt 5 V 0-P5 Tgt 4 Cry 4/'(00 V Cry 4/100 End Gry V 075 Tgt 3 End Cry Cry 4/100 0-P5 Tgt2 End E re 3000 Grl.4/.19R tr7rrgrl 3000 End Cry Cry 4100 Cry 41100 948" Csg 0P03 -0P5PB1 (P5) End Cni I Heel Tgt T b KOp Cry 4/100 End Cry 1500 1500 Cry 3/100 13-3/8" Cs. E8d Cry Cry 3/100 Gyro Point ...0 Cry-3/100 0 4- Bld 2.5/10 0 KOP Bld 1.5/100 RTE -1500 0 1500 3000 4500 :« W Scale = 1(in):1500(ft) E »> • 0 ANTICOLLISION SUMMARY REPORT Client: ENI Slot: OP03 Field: Nikaitchuq Well: OP03 -0P5 Structure: Oliktok Point Borehole: OP03- OP5PB1 Subject Trajectory: OP03- OP5PB1 (P5) (PLAN) Rpt Date: August 21, 2008 Analysis Method: Normal Plane Depth Interval: Every 5.00ft MD EOU Type: Oriented EOU used. Min Pts: All local minima indicated. ProbColMax: 1:25959 Mag Model: BGGM 2008 • Offset Trajectory Sep. Allow Sep. Subject Trajectory Separation Factor Alert Status Ct -Ct (ft) Dev. (ft) Fact. _ MD (ft) I TVD (ft) Alert 1 Minor 1 Major Oliktok t -1 (DEF SW) PASS 15.98 13.47 2904.61 39.00 39.00 MinPt -CtCt 16.08 13.37 96.74 84.00 84.00 MinPt -O -ADP 16.231 13.381 58.42 109.00 109.00 MinPt -O -ADP 26.10 21.011 13.641 348.71 348.71 MinPt -O -SF 200.18 186.281 26.011 1370.14 1340.70 MinPt -O -SF 1 1 359.8511 320.66 14.61 3111.66 2509.58 MinPt -CtCt 360.4211 320.101 14.19 3173.59 2537.38 MinPt -O -ADP 385.78 341.02 13.60 3356.36 2621.61 MinPt -O -SF 3528.79 3435.581 58.311 6013.21 3800.33 MinPt -O -SF Oliktok 1 -2 (DEF SW) PASS 1 1 8.2011 5.70 1229.55 38.35 38.35 MinPt-CtCt 7.96 3.79 4.91 243.33 243.33 5.00 Enter Alert 7.92 3.51 4.25 263.31 263.31 MinPt -CtCt 8.21 318 3.38 308.25 308.25 MinPt -O -ADP 8.77 3.38 3.2 333.20 333.20 MinPt -O -SF 15.54 9.04 4.89 447.98 447.97 5.00 Exit Alert 6901.61 6857.801 250.481 1667.69 1600.33 MinPt -O -SF 7416.70 7293.831 92.391 6012.48 3800.04 MinPt -O -SF Version DO 4.0 (doc40x_100) SP 2.1 - ANTICOLLISION SUMMARY REPORT Generated 8/21/2008 1:17 PM Page 1 of 1 • S chlumberger TRAVELING CYLINDER PLOT Client: ENI NoGo Region EOUs based on: Well: OP03 -0P5 Oriented EOU Dimension • Field: Nikaitchuq Structure: Oliktok Point NoGo Region Anticollision rule used: Minor Risk - Separation Factor Date: September 21, 2008 North 350 0 10 340 20 330 -- ,..„ 30 i - t 140' ``- i. 320 i - 40 120 ,--, T ` 310 50 100 300 60 80 290 60 70 40 _� 280 \ _� - 80 v •o a , ° • . E► .1�., .0 A0 '�� p . `i 110402,0`` 270 NI u4 � , , __ , 90 o 14 / 1r . s 0 o ti Ni � ► A 260 0 0 100 0 o � 0 o 250 0 ` oo � � • 110 0 a oti ., 1.0liktokl -1 o 240 120 . 230 130 220 -, , 140 210 150 200 160 190 180 170 Well Ticks Type: MD on OP03- OP5PB1(P5) Calculation Method: Normal Plane Ring Interval: 20.00 ft Azimuth Interval: 10.0 deg Scale: 1 INCH = 50.00 ft • • Oliktok Point Slot 3 to Producing Lateral 5 En nI Petroleum Nikaitchuq Field North Slope - Alaska to#1 Spud Date : Sep / 15 / 2008 RKB = TVD - TVDss = 52' (12' GLE + 40' DF) MD TVD ° F BHST Rig : Nabors 245E Vetco Gray 5k Multi Bowl WH on 20", Lands 13 5/8" and 9 5/8" ° lnclin. OP03- P05PB1 GR / Res / PWD / Dir BHA : Directioanl Motor 160' 160' 23 °F 0.0° 20" Conductor Driven KOP @350' 36 -160' ( 120' of 178.89ppf, 0.812" Wall, X -65, Weld 20" Csg) Build 1.5° DogLeg Water Base Mud 9.2ppg (Hi 350 -400 Funnel Vis) Max Dog = 3.0° Water Base Mud - Thick Spud Mud through Permafrost - Low annular velocities - Rely on Viscosity to clean hole & stabilize permafrost. Slightly thinner below permafrost, with slightly higher annular velocities. The Base of Base of Permafrost 1,921' 1,802' 40.8° Permafrost is estimated at 1,921 16" hole 2,437 2,152' 59 °F 50.0° 134/8" Surface Casing GR / Res / Den Neu / PWD / Dir 35 -2437' ( 2,402' of 68.ppf, 0.480" Wall, L -80, BTC 13 3/8" Csg) BHA : Rotary Steerable 9.2 ppg Mineral Oil Base Mud Max Dog = 4.0° 12 -1/4" Pilot Hole to 6,014' MD / 3,801" TVD with 67.0° of inclination to locate the Offset Well: OP -11 OA Sand. Then Plug and sidetrack to drill 12 -1/4" hole 9 -5/8" Intermediate Casing to 5,938' MD / 3,702' TVD with 85.0° of inclination at interval TD. Ugnu 3,783' 2,827' 60.6° Lower Ugnu 4,640' 3,242' 62.5° Schrader Bluff , a€€'s'xr a.4 ° ° ° 5,224' 3,492' 67.0° ° ;>, i ; i mi€ i < ;:� z , s Estimated TOP of Plug at 4,799 Cross into ENI Lease 5,320' 3,529' 67.0° MM ' s "' '# .f. Future ESP at 5,538' (200' above TOL) s< N Sand 5,416' 3,567' 67.0° IINNOMAN 500' into ENI Lease 5,848' 3,690' 81.4° Future Top of Liner at 5,738' (200' above Shoe) €i iiiftliiintk ISMONISWONE OA Sand 5,938' 3,702' 85.0° OA Sand The Objective of the Pilot Hole is to locate the Top & ,, €tt l> f ii: :: Wailinli Bottom of the OA Sand for the placement of the 8 1/2" hole 6,014' 3,801' 88 °F 67.0° Lateral. Cement Program: 12 -1/4" OH KICK OFF PLUG Cement Type Interval (MD) Footage Casing Hole bL / Ft bL Excess Density Yield Ft °/ Sx Sacks Class G 5,114 - 6,014 900 Plug 12 1/4 0.1458 131.2 16.50 ppg 1.07 688.4 Lead 45.9 35% 241 Estimated TOP of plug at 4,799 W/ EXCESS 177.1 929 • • Oliktok Point Slot 3 to ni Petro d Producing Lateral 5 Nikaitchuq Field North Slope - Alaska Spud Date : Sep / 15 / 2008 RKB = TVD - TVDss = 52' (12' GLE + 40' DF) MD TVD ° F BHST Rig : Nabors 245E Vetco Gray 5k Multi Bowl WH on 20 ", Lands 13 5/8" and 9 5/8" ° Inclin. OP03- P05PB1 GR / Res / PWD / Dir BHA : Directioanl Motor 160' 160' 23 °F 0.T 20" Conductor Driven KOP @350' 36 -160' ( 124' of 178.89ppf, 0,812" Wall, X -65, Weld 20" Csg) Build 1.5° Dogleg Water Base Mud 9.2ppg (Hi 350 -400 Funnel Vis) Max Dog = 3,0° Water Base Mud - Thick Spud Mud through Permafrost - Low annular velocities - Rely on Viscosity to clean hole & stabilize permafrost. Slightly thinner below permafrost, with slightly higher annular velocities, The Base of Base of Permafrost 1,921' 1,802' 40.8° Permafrost is estimated at 1,921 16" hole 2,437' 2,152' 59 °F 50.0° 134/8" Surface Casing GR / Res / Den Neu / PWD / Dir 35 -2437' ( 2,402' of 68.ppf, 0.480" Wall, L -80, BTC 13 3/8" Csg) BHA : Rotary Steerable 9.2 ppg Mineral Oil Base Mud Max Dog = 4.0° 12 -1/4" Pilot Hole to 6,014' MD / 3,801" TVD with 67.0° of inclination to locate the Offset Well: OP -11 OA Sand. Then Plug and sidetrack to drill 12 -1/4" hole 9 -5/8" Intermediate Casing to 5,938' MD / 3,702' TVD with 85.0° of inclination at interval TD. Ugnu 3,783' 2,827' 60.6° Lower Ugnu 4,640' 3,242' 62.5° Schrader Bluff 5,224' 3,492' 67.0° Cross into ENI Lease 5,320' 3,529' 67.0° Future ESP at 5,538' (200' above TOL) N Sand 5,416' 3,567' 67.0° 500' into ENI Lease 5,848' 3,690' 81.4° Future Top of Liner at 5,738' (200' above Shoe) igaMENPROMENS OA Sand 5,938' 3,702' 85.0° OA Sand The Objective of the Pilot Hole is to locate the Top & ```` ` Bottom of the OA Sand for the placement of the 8 1/2" hole 6,014' 3,801' 88 °F 67.0° Lateral. • 0 Oliktok Point Slot 3 to V A Eni Petroleum Producing Lateral 5 Nikaitchuq Field North Slope - Alaska A Spud Date : Sep / 15 / 2008 RKB = TVD - TVDss = 52' (12' GLE + 40' DF) MD TVD ° F BHST Rig : Nabors 245E 1 Vetco Gray 5k Multi Bowl WH on 20 ", Lands 13 5/8" and 9 5/8" ° Indio. OP03 -P05 - GR / Res / PWD / Dir BHA : Directioanl Motor 160' 160' 23 °F 0.0° : 1 20" Conductor Driven KOP 0350' 36 -160' ( 124' of 178.89ppf, 0.812" Wall, X -65, Weld 20" Csg) Build 1.5° DogLeg Water Base Mud 9.2ppg (Hi 350 -400 Funnel Vis) Max Dog = 3.0° Water Base Mud - Thick Spud Mud through Permafrost - Low annular " velocities - Rely on Viscosity to clean hole & stabilize permafrost. Slightly thinner below permafrost, with slightly higher annular velocities. The Base of Base of Permafrost 1,921' 1,802' 40.8 Permafrost is estimated at 1,921' MD / 1,802' TVD. x ra � I III 16" hole 2,437' 2,152' 59 °F 50.0° g E , 13 -3/8" Surface Casing GR / Res / Den Neu / PWD / Dir 35 -2437' ( 2,402' of 68.ppf, 0.480" Wall, L -80, BTC 13 3/8" Csg) BHA : Rotary Steerable 9.2 ppg Mineral Oil Base Mud Max Dog = 4.0° :it 12 -1/4" Pilot Hole to 6,014' MD / 3,801" TVD with 67.0° of inclination to locate the Offset Well: OP -11 OA Sand. Then Plug and sidetrack to drill 12 -1/4" hole 9 -5/8" Intermediate Casing to 5,938' MD / 3,702' TVD with 85.0° of inclination at interval TD. Ugnu 3,783' 2,827' 60.6° `l - Lower Ugnu 4,640' 3,242' 62.5° £ su Schrader Bluff 5,224' 3,492' 67.0° :,� '` Cross into ENI Lease 5,320' 3,529' 67.0° a i ESP at 5,538' (200' abov e TOL) N Sand `i ` :' 5,416' 3,567' 67.0° 500' into ENI Lease 5,848' 3,690' 81.4° 6. n Top of Liner at 5,738' (200' abov e Shoe) = , =' M 12 -1/4" hole # 5,938' 3,702' 87 °F 85.0° 9 -5/8" Intermediate Casing OA Sand 33 -5938' ( 5,905' of 47.ppf, 0.472" Wall, L -80, BTC -M 9 5/8" Csg) i 9.2 ppg Mineral Oil Base Mud (No Barite - 80ppb CaCO3) r BHA : Rotary Steerable 1 m Max Dog = 4.0° z a r 8 -1/2" Hole - Tail to 13,374' MD / 3,971" TVD with 75.2- 90 1° of inclination GR / Res / Den Neu / PWD / Dir m over the interval. This interval is the horizontal lateral and extends the well c) from 2,703 to 10,127 ft verical section, adding 7,424' of horizontal lateral, + PeroScope (Geo- Steering) = hopefully all within the primary objective, the Offset Well: OP -11 OA Sand. 8 1/2" hole 12,330' 6,391' 88.8° I 5 1/2" Slotted Liner 5,738- 12330' ( 6,592' of 17.ppf, 0.304" Wall, L -80, IBT -M 5 1/2" Csg) Displace to 9.5ppg 50/50 Mineral Oil / CaCI solids free to run Liner 8 1/2" hole 13,374' 3,971' 91 °F 75.2° Optional Tail to Evaluate OA sand section / thickness 1 • 0 Shallow Drilling Hazards Evaluation ENI US Operating Co. Inc. OP03 -P05, OP03- P05PB1 Summary Pursuant to 20AAC 25.061, all available data from proximal wells and pertinent geophysical data have been evaluated for evidence of any shallow to intermediate depth drilling hazards. Mudlogs and wireline logs from these offset wells indicate minor amounts of natural gas hydrates in sands and gravels of the Sagavanirktok Formation associated with ice in the permafrost wedge. The Oliktok Point 1 -1 and 1 -2 wells were drilled with no evidence of hydrocarbons in the Ugnu Sand or any major hydrate accumulations. Seismic data does not suggest or define any anomalous shallow hazard zones. Geology: Shallow and Intermediate Depth Horizons Oliktok Point OP03 -P05 will penetrate strata ranging from the Gubik Formation (Pleistocene) at the surface, to the Schrader Bluff Formation of the Colville Group (Cretaceous). The Gubik Formation and the superficial covering of Quaternary sediments, are comprised of approximately 800' of interbedded sand, gravel, mud, and some low -grade coals deposited in marine and marginal marine settings. Geophysics The 3D seismic grid covering the leases of interest was analyzed for potential shallow and intermediate depth drilling hazards. The seismic data is of varying vintage and quality. The utility of some volumes for shallow hazard interpretation is questionable. The seismic data, that was judged suitable, was then compared to wireline logs, mud logs and scout information from uphole sections in wellbores drilled in the Oliktok Point and Nikaitchuq areas. There is no geophysical evidence, such as amplitude anomalies or velocity sags, suggesting the proposed OP03 -P05 will encounter any form of shallow entrapped natural gas, or intersect any conductive faults. Potential Shallow Drilling Hazards Permafrost OP03 -P05 surface location is on a man made gravel pad at the northern end of the Oliktok Point promontory approximately 1.2 miles NNW of the Kuparuk River Field 3R pad. Direct offsets OP -I1, OP -12, and OP -I2PB1 encountered the permafrost to a TVD of approximately 1750'. The OP03 -P05 should encounter permafrost to approximately the same depth interval as encountered in Oliktok Point #1 and #2 wells. • • Shallow Hydrocarbon Accumulations There is no evidence of any significant accumulations of gas hydrates in the shallow sands of the Oliktok Point area. No oil or gas hydrates accumulations were encountered in the shallow sands of the direct offsets OP -I1, OP -12, or OP- I2PB1. Mudlogs from the Nikaitchuq #1 well showed the presence of minor gas hydrates within the permafrost from 1200 - 1750' TVD, with a maximum hotwire reading of 400 units gas (1280' TVD). The Exxon Thetis Island well (6 miles west of proposed location) was characterized by similar indications of gas hydrates contained within the permafrost wedge. The Nikaitchuq #1, 2, 3 and 4, wells along with the Tuvaaq #1 and Kigun #1 wells penetrated Schrader Bluff sands with shows of heavy oil in the Kigun #1 well at approximately 3,650 - 3,750' TVD. No well control problems were encountered while drilling through these show zones in any of the aforementioned wells. Oliktok Point 2 (1.5 miles SSE) encountered hydrocarbon shows in the Schrader Bluff (3350- 3550'TVD) but, again, no well control issues were noted. No hydrocarbon shows are associated with this interval in the Exxon Thetis Island well or the East Harrison Bay well (4 miles WSW) Conclusions No drilling hazards associated with natural gas hydrates or shallow trapped natural gas or oil are anticipated in the drilling of the OP03 -P05 well. Although minor amounts of gas hydrates are associated with the permafrost layer, these amounts can and will be dealt with by prudent drilling operations and practices. Heavy oil entrapped in either the Ugnu and /or Schrader Bluff intervals is not considered to present any drilling risks. . ( 1 J l I HYDRIL 13 -5/8" 5K PSI ' GK ANNULAR BOP 4' -61�" LATCHED HEAD 5K FLANGE CONNECTION I 54 -1/2" LENGTH J • -41 - 4" MO- 4" 10,000/ WP CAMERON TYPE "F" HYDRIL 13 -5/8" 5K PSI 13' - 44" GATE VALVE 3' -4" MPL DOUBLE GATE 4" 10,000# WP STUDDED CONNECTION 4" 10,000/ WP CAMERON HCR VALVE 42 - 7/8" LENGTH CAMERON HCR VALVE \ - 110 ■ ' DRILLING SPOOL 4" CHOKE LINE 1�i 1 ∎1 + III I III � �C - 3" KILL LINE 2' - 13 - 5/8 " - PSI FLANGED ■ 1 \I ± 4 " - 10K PSI FLANGED OUTLETS 4 "x3 " - 1 - I 26" EST. LENGTH 4" 10,000// WP "F" J ! - CAMERON TYPE " HYDRIL 13 -5/8" 5k PSI GATE VALVE i _ - + _ - _ 1 3' -04" MPL SINGLE GATE FLANGED CONNECTION "1 f'-- 36 -1/4" LENGTH II NABORS ALASKA RIG 245E 13-5/8" 5K wax= '"NIATE1721 """'1' BOP STACK CONFIGURATION 0 .M "OYMVY 4"' %I 11 Ahb 59503 -2639 907- -,000 ' " 'EC ' NABORS ALASKA RIG 245E mu BLOW —OUT PREVENIER 13 -5/8' 5K STUDDED STACK CONFIGURATION ' ., NMI 13184R08 A 44 Si ISSUED J OE NSIQN JOE A (STGN VI JOE ASTON A 5910 ' II' DESCAVIIN MIME DU N/A I0'.%W 2008 245L0002 -5K - I of I • I i a1 .i. = 0 o _ CLAMP �I o __ o CONNECTOR 1 CELLAR It ��I WEL I HYDRIL ANNULAR PSI i• -- GK K TCH D H BOO I UP I P — a' -64" LATCHED HEAD OEM 5K FIANCE CONNECTION + .� IMO 54 -1/2" LENGTH t--I 42i] I 111 !' °® 4' 101 VP _41 0 �— C AM 0 HYDRIL 13 -5/8' SK PSI ' :;71781 '. _ 13'- 3 • -�" MPL DOUBLE GATE ;t1`dlllgi 4" 10,000 / WP STUDDED CONNECTION 4' 10,000/ W AIL ': 42 -7/8' LENGTH A11IIde ' 11 CAMERON HCR 10 �� — C AMERON HER VALVE ON A ■ n • DRILLING SPOOL I 4" CHOKE LINE 1\ I in, 1\ 1 ,.,.••• _ 3' KILL LINE 2. 1" 13- 5/8 " -5K PSI FLANGED MIDI " 1`` ' ■ II III II_ II VIII % I 4 " -10K PSI FLANGED OUTLETS 26" EST LENGTH 4' 10,000 / WP ESTIMATED CAMERON TYPE "F" — �— HYDRIL 13 -5/8" 5k PSI 90• -0. � M PL SINGLE GATE LENGTH GATE VALVE OF' FLANGED CONNECTION 16' ONERTER LINE 1 36 -1/4" LENGTH 1 5K BOP STACK CONFIGURATION DIVERTER LINE ROUTING NABORS ALASKA RIG 245E ENI NIKAITCHUQ PROJECT a' -4 1/2" 11 -I/4" 2,000/ WP SHAFFER 2,000 / STUDDED TOP BY 2 1 -1/4' 2,000/ FLANGED BOTTOM H2S TRIMMED ANNULAR DIVERTER SYSTEM \ 3/16" 1 SURFACE DIVERTER m 16" -150# FLG PIPING CONFIGURATION 1 ill 2 • 0" _ PLAN VIEW 111 2 -O. 24" DIA. ns a � .m.xanar onion a warns ww+�� wvxoaciw a we or 6ESgN 6 AN649F ORS i W6MOfa N BY IMB616 MAtYA -- \--16' KNIFE GATE f 4mU Nabors AbM DONN In sob�s c aro. zoo W/ HYD. ACTUATOR awrm �.. �s-263- esso3 -z6x %1OJECT NABORS ALASKA RIG 245E IMF BOP STACK AND SNORTER CONFIGURATION ENI NIKAICHUQ PROJECT SURFACE DIVERTER CONFIGURATION BY RES 9JULY08 A JA JA ISSUED J OE ALSTON JOE � �rr.om Al5@N JOE AISTON A CROMER n > E g ' DESCRIPTION scut N / A D M 2008 245EOJ01 -/W TCHUO 9 1 of 7 i - DI 0 Material List > Item Description 1 -15 4- 1/16" 10M Cameron Manual Gate Valve 16 2- 1/16" 10M Cameron Manual Gate Valve A,B 4- 1/16" 10M Cameron H2 Manual Choke C 3- 1/16" 10M Shaffer Hydraulic Choke • t Y 0 To Gas __ 1 1 4P All- 4 fi Buster © .' � - O . s .... ......10 °F _ ....... ....,..---- ilD i tA ...--- 0 lay Igor . , ..., ,., _ , _, .. , r To Shaker 04 7° :------ - - 1°' ® From 'y ESOP s `ddiiii h Legend ,, cilL White Handle Valves. aL7 Normally Open -� 6 €31 Red Handle Valves Normally Closed Date: 6-1-01 Rev. 1 I CODS • • AIN /CL • •3.50 / x 37.10 I 1 4 ) -- ' _I r ;az 1 `I li - �' u r . • ID i �� \; �� T.O.S. EL 26' S 3/4" iv N i B.O.S. EL 25' 7 -1/4" 1.062 OFFSET C/L O TOP OF WELLHEAD 5.00" EL 25' 2 -1/4" 1 Cs o ` PFT o � l ELECTRICAL Nom p p a I FEEDTHRU 21.81 13 -5/8" 5000 PSI ° r 1 , T �! VG S137 CLAMP 111161111-11 —.- � w V 0 0o a O E nu I o a 4 -1/16" _!e ciaM "' 5000 PSI j _,- -. _- G f-1 I �II !!! 11,e1.4.----,--. 3.437 OFFSET 108.0 2 -1/16" 1 01 11 11 5000 PSI fl ! ® 2- 1/16" ' i_ c; - A= ,, j 3S S 1 5000 PSI = 1; B . - - • j . . R: 66.71 OUT a POSITION � �) I 13" 5000 PSI '' VG 134 MOD. 52.96" Hu I �� i81811 26.5. ! u1 i 34.00" 2_1/16" 1 1l i 5000 PS1 1. _� OuT OF - -24.24 I - POSITION ■ � I � i 1 J rt • 15.25" r I ! r}' TOG TOP OF GRADING I i 1 j - EL 16' 1 -1/4" k I, - I I! I ! 1.00 ! ! jl I I !! I! I PROPRIETARY NOTICE CO ;,n.m:; `. ; vetcog Dam 20" OD 133# K -55 I a, . ; Whir aGE QI6 Gas business I 13 -3/8" OD 68# L -80 j I DRAM BY' ENI ALASKA J. ALVARADO HORIZONTAL MULTI -BOWL SYSTEM I 9 -5/8" OD 53.5# L -80 j I R ENEWED FM 4 -1/2" OD WITH 6 -5/8 VIT 20 X 13 -3/8 X 9 -5/8 X "'°ROVED ST, X 4-1/2 WITH 6 -5/8 VIT E. BORA( RELEASE DATE AND ESP FLAT CABLE 23 APRIL 08 PRO E ON 0 -E3- SU NU H 173370 -1 A DO NOT SCALE DRAWING MST. CODE X X Xi MG. (LOS.) X I SHEET 1 or 1 0 • Eni Petroleum 3800 Centerpoint Drive Suite 300 Anchorage, AK 99503 REcEIV (907) 865 -3300 �, J (907) 865 -3380 (Fax) AUG 2620 August 25, 2008 Alaska Oil & Gas Cans, omm Mr. John Norman, Chair Anchorage Alaska Oil and Gas Conservation Commission 333 West 7 Ave., Suite 100 Anchorage, Alaska 99501 Subject: Background information for Application for Permit to Drill OP03 -P05 Dear Mr. Norman, Eni US. Operating Co. Inc. intends to permit OP03 -P05. ENI US Operating Co. Inc and I sincerely apologize for the tardiness of the submittal of this APD. As of recent, Eni US Operating Co. Inc has been alerted by the Environmental Protection Agency that the drilling of the OP25- DSP01 /OP26 -DSP02 Disposal well will be suspended until the UIC Class 1 Permit is granted. Eni US Operating Co. Inc. was operating under the impression that after obtaining a Class 2 Non - Hazardous Waste Injection Permit granted by the AOGCC, as well as an approved APD, drilling of the disposal well would commence and it could then be permitted as a Class 1 Non - Hazardous Waste Injection well once the permit was approved by the EPA. Due to this recent notification Eni US Operating Co. Inc has decided to drill the OP03 -P05 well to mitigate rig standby costs. Again, Eni US Operating Co. Inc. apologizes and we will strive to provide you with ample review time for future submissions. Due to the fact that our point of origin, Oliktok Point Pad, sits within the Kuparuk River Unit the following has been provided: 1. Survey Plat 2. Wellbore Survey 3. Azimuthal deviation schematics 4. Previous/ Amended Land Use Permits If there are any questions that you may have please contact me at (907) 865- 3323 Sincerely, En' US Operating o. Inc. ose +h Longo r Drillin• nginee • REV DATE BY CK APP DESCRIPTION REV DATE BY CK APP DESCRIPTION oa OLIKTOK OINT \ OLIKTOK C %., INTAKE DOCK �it A � '" THIS \, P e P PROJECT JO N `y N ,, q 1 DS -3R O DE Lk 111 0 SITE STP 1 a S AGIN P ARREA•, . 1 � MODULES 0 + T13N, R9E 4 D , , ; f -� 18, 15 SCALE: � '' i„. 150' Di-3o 1s 0 S TP PAD \ VICINITY MAP / \ \ SCALE: 1" = 1 Mile / °, 0 \ \ \ / / \ a' \ \ / o \ 0 2 ..:-____( i. \ \ OLIKTOK POINT PAD \ \ a asoa \ \ /\ \ / \ \ \ / 1 0 �� \ / • As Built Conductor \ \ \ o Proposed Well Locations \ / / \ / / LOUNSBURY \ \ / /� ,j & ASSOCIATES� G , INC. SEE SHEET 2 FOR NOTES / p AREA: MODULE: UNIT: � Sitt ■ OPP PAD P ROPOSED WELL LOCATIONS CADD FILE NO. DRAWING NO: PART: REV: LK601D715 8/19/08 NSK 6.01 —d715 1 OF 2 I 0 I 0 0 'REV DATE BY CK APP DESCRIPTION REV DATE BY CK APP DESCRIPTION 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. PROTRACTED SECTION 5, T. 13 N., R. 9 E., UMIAT MERIDIAN Well Ak State Plane Sec Line PAD O.G. No. 'Y' 'X' Latitude(N) Longitude(W) Offset F.E.L. ELEV. ELEV. OP -11 6,036,332.70 1,656,791.89 70' 30' 39.015" 149' 51' 57.587" 2,052' 1,519' 12.1' 4.0' OP -12 6,036,328.85 1,656,784.83 70' 30' 38.977" 149' 51' 57.795" 2,056' 1,526' 12.2' 4.0' 0P03 —P05 6,036,325.09 1,656,777.67 70' 30' 38.940" 149' 51' 58.006" 2,059' 1,534' 12.2' 4.0' Bold Indicates Proposed Well Locations. PROPOSED DISPOSAL WELLS Well Ak State Plane Sec Line PAD O.G. No. 'Y' 'X' Latitude(N) Longitude(W) Offset F.E.L. ELEV. ELEV. OP -25 6,036,006.04 1,656,514.94 70' 30' 35.808" 149' 52' 05.767" 2,378' 1,798' OP -26 6,036,013.56 1,656,529.09 70' 30' 35.881" 149' 52' 05.349' 2,370' 1,784' LOUNSBURY & ASSOCIATES, INC. IW ENGINEERS PLANNERS ... AREA: MODULE: UNIT: t OPP PAD mum PROPOSED WELL LOCATIONS CADD FILE NO. DRAWING NO: PART: REV: LK601D715 8/19/08 I NSK 6.01 —d715 2 OF 2 I 0 leum Schiumberger OP03- OP5PB1 (P5) Proposal Report Date: August 21, 2008 Survey 1 DLS Computation Method: Minimum Curvature I Lubinski Client: ENI Vertical Section Azimuth: 40.000° Field: Nikaitchuq Vertical Section Origin: N 0.000 ft, E 0.000 ft Structure 1 Slot: Oliktok Point / OP03 �� u � TVD Reference Datum: Rotary Table Well: OP03 -0P5 �; �; I i TVD Reference Elevation: 52.00 ft relative to MSL Borehole: OP03- OP5PB1 Sea Bed 1 Ground Level Elevation: 12.00 ft relative to MSL UWIIAPI #: 50029 �� Magnetic Declination: 22.561° Survey Name I Date: OP03- OP5PB1 (P5) / August 21, 2008 Total Field Strength: 57659.037 nT Tort I AHD I DDI I ERD ratio: 135.946° / 4047.47 ft 15.940 / 1.065 Magnetic Dip: 80.929° Grid Coordinate System: NAD27 Alaska State Planes, Zone 04, US Feet Declination Date: September 21, 2008 • Location LatiLong: N 70.51110759, W 149.86296286 Magnetic Declination Model: BGGM 2008 Location Grid NIE YIX: N 6036573.689 ftUS, E 516746.428 ftUS North Reference: True North Grid Convergence Angle: +0.12918578° Total Corr Mag North .> True North: +22.561° Grid Scale Factor: 0.99990032 Local Coordinates Referenced To: Well Head Measured Vertical Mag I Gray Directional Comments Inclination Azimuth Sub -Sea ND TVD NS EW DLS Northing Easting Latitude Longitude Depth Section Tool Face Difficulty _ (ft ) (deg) (deg) (ft) (ft ) (ft) (ft ) (ft) ( deg) (deg1100ft ) Index (ftUS) (KIS) RTE 0.00 0.00 27.00 -52.00 0.00 0.00 0.00 0.00 - -- 0.00 0.00 6036573.69 516746.43 N 70.51110759 W 149.86296286 WRP 40.00 0.00 27.00 -12.00 40.00 0.00 0.00 0.00 -- 0.00 0.00 6036573.69 516746.43 N 70.51110759 W 149.86296286 KOP Bld 1.5/100 350.00 0.00 27.00 298.00 350.00 0.00 0.00 0.00 27.00M 0.00 0.00 6036573.69 516746.43 N 70.51110759 W 149.86296286 400.00 0.75 27.00 348.00 400.00 0.32 0.29 0.15 27.00M 1.50 0.00 6036573.98 516746.58 N 70.51110838 W 149.86296165 Bld 2.5/100 450.00 1.50 27.00 397.99 449.99 1.28 1.17 0.59 27.00M 1.50 0.29 6036574.86 516747.02 N 70.51111077 W 149.86295800 500.00 2.75 27.00 447.95 499.95 3.08 2.82 1.44 27.00M 2.50 0.94 6036576.51 516747.86 N 70.51111529 W 149.86295111 600.00 5.25 27.00 547.70 599.70 9.88 9.03 4.60 HS 2.50 1.73 6036582.73 516751.01 N 70.51113226 W 149.86292520 Gyro Point 650.00 6.50 27.00 597.44 649.44 14.86 13.59 6.93 HS 2.50 2.00 6036587.30 516753.32 N 70.51114472 W 149.86290619 700.00 7.75 27.00 647.05 699.05 20.91 19.12 9.74 HS 2.50 2.22 6036592.83 516756.13 N 70.51115982 W 149.86288316 800.00 10.25 27.00 745.81 797.81 36.15 33.06 16.84 HS 2.50 2.58 6036606.78 516763.19 N 70.51119789 W 149.86282505 Cry 3/100 850.00 11.50 27.00 794.91 846.91 45.34 41.46 21.13 46.64R 2.50 2.73 6036615.19 516767.46 N 70.51122085 W 149.8627900 900.00 12.58 32.01 843.81 895.81 55.59 50.52 26.27 41.74R 3.00 2.87 6036624.26 516772.59 N 70.51124560 W 149.862747 1000.00 14.95 39.78 940.94 992.94 79.27 69.67 40.30 34.19R 3.00 3.11 6036643.44 516786.57 N 70.51129790 W 149.86263311 1100.00 17.51 45.39 1036.96 1088.96 107.15 90.14 59.26 28.81R 3.00 3.32 6036663.96 516805.48 N 70.51135385 W 149.86247795 1200.00 20.19 49.58 1131.59 1183.59 139.15 111.90 83.11 24.84R 3.00 3.50 6036685.77 516829.28 N 70.51141328 W 149.86228280 1300.00 22.94 52.81 1224.59 1276.59 175.17 134.87 111.78 21.83R 3.00 3.66 6036708.80 516857.90 N 70.51147604 W 149.86204822 1400.00 25.75 55.38 1315.69 1367.69 215.13 159.00 145.19 19.49R 3.00 3.80 6036733.00 516891.25 N 70.51154196 W 149.86177483 1500.00 28.59 57.47 1404.64 1456.64 258.91 184.22 183.26 17.63R 3.00 3.93 6036758.30 516929.25 N 70.51161084 W 149.86146339 1600.00 31.47 59.21 1491.21 1543.21 306.40 210.45 225.86 16.12R 3.00 4.04 6036784.63 516971.79 N 70.51168250 W 149.86111476 1700.00 34.36 60.69 1575.16 1627.16 357.45 237.63 272.90 14.88R 3.00 4.15 6036811.91 517018.76 N 70.51175675 W 149.86072988 1800.00 37.26 61.96 1656.25 1708.25 411.94 265.69 324.23 13.85R 3.00 4.26 6036840.08 517070.03 N 70.51183338 W 149.86030982 1900.00 40.18 63.07 1734.26 1786.26 469.71 294.54 379.73 12.98R 3.00 4.35 6036869.05 517125.45 N 70.51191219 W 149.85985571 WellDesign Ver SP 2.1 Bld( doc40x_100) OP03\ OP03- 0P5 \OP03- OP5PB1 \OP03- OP5PB1 (P5) Generated 8/21/2008 12:35 PM Page 1 of 3 Measured Vertical Mag I Gray Directional Comments Inclination Azimuth Sub•SeaTVD TVD NS EW DLS Northing Easting Latitude Longitude Depth Section Tool Face Difficulty (ft ) (deg) (deg) (ft) (ft ) (ft) (ft) (ft ) (deg) (deg1100ft ) Index (ftUS) (ftUS) 2000.00 43.11 64.06 1808.98 1860.98 530.61 324.10 439.23 12.25R 3.00 4.44 6036898.75 517184.88 N 70.51199295 W 149.85936882 2100.00 46.04 64.94 1880.20 1932.20 594.46 354.30 502.58 11.62R 3.00 4.52 6036929.09 517248.16 N 70.51207544 W 149.85885046 2200.00 48.99 65.74 1947.73 1999.73 661.10 385.05 569.59 11.08R 3.00 4.60 6036959.99 517315.10 N 70.51215944 W 149.85830207 End Cry 2234.44 50.00 66.00 1970.10 2022.10 684.66 395.76 593.49 - -- 3.00 4.63 6036970.74 517338.96 N 70.51218868 W 149.85810654 13 -3/8" Csg 2436.52 50.00 66.00 2100.00 2152.00 823.80 458.72 734.91 - -- 0.00 4.72 6037034.02 517480.23 N 70.51236066 W 149.85694926 Cry 3/100 2441.19 50.00 66.00 2103.00 2155.00 827.01 460.18 738.18 38.53R 0.00 4.73 6037035.48 517483.49 N 70.51236463 W 149.85692253 2500.00 51.39 67.41 2140.25 2192.25 867.66 478.17 779.97 37.64R 3.00 4.76 6037053.57 517525.24 N 70.51241376 W 149.85658053 2600.00 53.79 69.68 2201.01 2253.01 937.41 507.20 853.89 36.26R 3.00 4.83 6037082.76 517599.09 N 70.51249304 W 149.85597565 2700.00 56.22 71.81 2258.36 2310.36 1007.79 534.19 931.22 35.04R 3.00 4.89 6037109.92 517676.35 N 70.51256675 W 149.85534283 2800.00 58.70 73.83 2312.14 2364.14 1078.62 559.07 1011.76 33.95R 3.00 4.95 6037134.98 517756.82 N 70.51263469 W 149.85468381 2900.00 61.20 75.74 2362.22 2414.22 1149.69 581.77 1095.27 32.99R 3.00 5.01 6037157.86 517840.28 N 70.51269667 W 149.8540003 3000.00 63.73 77.56 2408.45 2460.45 1220.81 602.23 1181.54 32.15R 3.00 5.06 6037178.52 517926.49 N 70.51275253 W 149.8532944 3019.38 64.22 77.90 2416.95 2468.95 1234.59 605.93 1198.56 - -- 3.00 5.07 6037182.26 517943.50 N 70.51276263 W 149.85315518 Cry 3/100 3019.53 64.22 77.90 2417.02 2469.02 1234.69 605.95 1198.69 104.90L 0.00 5.07 6037182.28 517943.62 N 70.51276270 W 149.85315414 3100.00 63.62 75.30 2452.40 2504.40 1292.71 622.70 1268.99 103.76L 3.00 5.11 6037199.18 518013.88 N 70.51280842 W 149.85257881 3200.00 62.95 72.03 2497.36 2549.36 1367.04 647.81 1354.70 102.29L 3.00 5.16 6037224.49 518099.52 N 70.51287699 W 149.85187747 3300.00 62.35 68.72 2543.32 2595.32 1443.65 677.64 1438.34 100.77L 3.00 5.21 6037254.50 518183.09 N 70.51295842 W 149.85119297 3400.00 61.83 65.37 2590.14 2642.14 1522.33 712.09 1519.69 99.20L 3.00 5.25 6037289.13 518264.36 N 70.51305249 W 149.85052719 3500.00 61.39 62.00 2637.70 2689.70 1602.88 751.08 1598.54 97.60L 3.00 5.30 6037328.29 518343.10 N 70.51315895 W 149.84988196 3600.00 61.04 58.60 2685.86 2737.86 1685.06 794.49 1674.65 95.96L 3.00 5.34 6037371.87 518419.11 N 70.51327749 W 149.84925904 3700.00 60.77 55.18 2734.51 2786.51 1768.64 842.20 1747.82 94.29L 3.00 5.38 6037419.74 518492.17 N 70.51340780 W 149.84866015 Ugnu 3782.70 60.61 52.34 2775.00 2827.00 1838.68 884.83 1805.98 92.90L 3.00 5.41 6037462.49 518550.23 N 70.51352421 W 149.84818417 3800.00 60.59 51.75 2783.49 2835.49 1853.42 894.10 1817.86 92.61L 3.00 5.41 6037471.79 518562.09 N 70.51354952 W 149.84808691 3900.00 60.49 48.30 2832.68 2884.68 1939.14 950.02 1884.57 90.92L 3.00 5.45 6037527.86 518628.66 N 70.51370226 W 149.84754091 4000.00 60.49 44.85 2881.95 2933.95 2025.58 1009.83 1947.77 89.22L 3.00 5.48 6037587.81 518691.71 N 70.51386560 W 149.84702364 4100.00 60.58 41.41 2931.15 2983.15 2112.49 1073.36 2007.28 87.52L 3.00 5.52 6037651.46 518751.08 N 70.51403910 W 149.84653651 4200.00 60.75 37.97 2980.16 3032.16 2199.64 1140.42 2062.94 85.84L 3.00 5.55 6037718.64 518806.58 N 70.51422228 W 149.84608086 4300.00 61.01 34.55 3028.84 3080.84 2286.80 1210.85 2114.60 84.18L 3.00 5.58 6037789.18 518858.07 N 70.51441463 W 149.84565795 4400.00 61.36 31.15 3077.05 3129.05 2373.72 1284.44 2162.11 82.54L 3.00 5.61 6037862.87 518905.42 N 70.51461563 W 149.845268 4500.00 61.79 27.78 3124.66 3176.66 2460.16 1360.99 2205.35 80.93L 3.00 5.64 6037939.51 518948.48 N 70.51482474 W 149.844914 4600.00 62.30 24.43 3171.55 3223.55 2545.88 1440.30 2244.20 79.36L 3.00 5.67 6038018.90 518987.15 N 70.51504137 W 149.84459672 Lower Ugnu 4639.85 62.53 23.10 3190.00 3242.00 2579.80 1472.63 2258.44 78.75L 3.00 5.68 6038051.26 519001.31 N 70.51512966 W 149.84448015 4700.00 62.90 21.12 3217.58 3269.58 2630.66 1522.15 2278.56 77.84L 3.00 5.69 6038100.82 519021.32 N 70.51526493 W 149.84431538 I 4800.00 63.57 17.84 3262.63 3314.63 2714.26 1606.31 2308.32 76.36L 3.00 5.72 6038185.03 519050.88 N 70.51549481 W 149.84407162 4900.00 64.31 14.61 3306.57 3358.57 2796.45 1692.55 2333.40 74.94L 3.00 5.75 6038271.32 519075.77 N 70.51573039 W 149.84386609 5000.00 65.12 11.41 3349.29 3401.29 2877.00 1780.64 2353.74 73.57L 3.00 5.77 6038359.44 519095.91 N 70.51597101 W 149.84369938 5100.00 66.01 8.26 3390.66 3442.66 2955.70 1870.32 2369.29 72.27L 3.00 5.80 6038449.16 519111.25 N 70.51621602 W 149.84357193 5200.00 66.95 5.16 3430.58 3482.58 3032.33 1961.37 2379.99 71.03L 3.00 5.83 6038540.22 519121.75 N 70.51646474 W 149.84348410 End Cry 5205.10 67.00 5.00 3432.58 3484.58 3036.18 1966.05 2380.41 - -- 3.00 5.83 6038544.90 519122.15 N 70.51647751 W 149.84348068 Schrader Bluff 5224.10 67.00 5.00 3440.00 3492.00 3050.51 1983.47 2381.93 - -- 0.00 5.83 6038562.33 519123.64 N 70.51652511 W 149.84346816 WellDesign Ver SP 2.1 Bld( doc40x_100) OP03\ OP03- 0P5 \OP03- OP5PB1 \OP03- OP5PB1 (P5) Generated 8/21/2008 12:35 PM Page 2 of 3 Measured Vertical Mag 1 Gray Directional Comments Inclination Azimuth Sub -Sea ND TVD NS EW DLS Northing Easting Latitude Longitude Depth Section Tool Face Difficulty (ft) (deg) (deg) (ft) (0) (ft) (ft ) (ft ) (deg) (deg/100ft ) Index (BUS) (ftUS) Top N Sand 5416.05 67.00 5.00 3515.00 3567.00 3195.24 2159.49 2397.33 - -- 0.00 5.86 6038738.36 519138.64 N 70.51700595 W 149.84334166 5449.32 67.00 5.00 3528.00 3580.00 3220.33 2190.00 2400.00 - -- 0.00 5.86 6038768.87 519141.24 N 70.51708930 W 149.84331973 Base N Sand 5518.42 67.00 5.00 3555.00 3607.00 3272.43 2253.37 2405.54 -- 0.00 5.87 6038832.24 519146.64 N 70.51726240 W 149.84327419 Top OA Sand 5761.56 67.00 5.00 3650.00 3702.00 3455.76 2476.32 2425.05 -- 0.00 5.91 6039055.22 519165.64 N 70.51787146 W 149.84311394 5863.93 67.00 5.00 3690.00 3742.00 3532.96 2570.20 2433.26 - -- 0.00 5.92 6039149.10 519173.64 N 70.51812791 W 149.84304647 TD 6013.93 67.00 5.00 3748.61 3800.61 3646.06 2707.75 2445.30 - -- 0.00 5.94 6039286.67 519185.37 N 70.51850366 W 149.84294760 Survey Error Model: SLB ISCWSA version 24 * ** 3 -D 95.00% Confidence 2.7955 sigma Surveying Proq: MD From (ft) MD To (ft ) EOU Freq Survey Tool Type Borehole -> Survey 0.00 40.00 1/100.00 SLB_NSG +SSHOT -Depth Only OP03- OP5PB1 -> OP03- OP5PB1 (P5) 40.00 650.00 1/100.00 SLB_NSG +SSHOT OP03- OP5PB1 -> OP03- OP5PB1 (P5) • 650.00 6013.93 1/100.00 SLB_MWD+GMAG OP03- OP5PB1 -> OP03- OP5PB1 (P5) Legal Description: Northing (Y) lftUS1 Eastinq (X) fftUS1 Surface : 3220 FSL 1533 FEL S5 T13N R9E UM 6036573.69 516746.43 BHL : 648 FSL 4360 FEL S33 T14N R9E UM 6039286.67 519185.37 s WellDesign Ver SP 2.1 Bld( doc40x_100) OP03\ OP03- OP5 \0P03- OP5PB1 \0P03- OP5PB1 (P5) Generated 8/21/2008 12:35 PM Page 3 of 3 1 um Schlumberger eV OP03 -0P5 (P8) Proposal Report Date: August 21, 2008 Survey 1 DLS Computation Method: Minimum Curvature / Lubinski Client: ENI Vertical Section Azimuth: 1.000° Field: Nikaitchuq Vertical Section Origin: N 0.000 ft, E 0.000 ft Structure 1 Slot: Oliktok Point / OP03 U �y TVD Reference Datum: Rotary Table Well: OP03 -0P5 Foss" I ii r� ND Reference Elevation: 52.00 ft relative to MSL Borehole: OP03 -0P5 F Sea Bed 1 Ground Level Elevation: 12.00 ft relative to MSL UWIIAPI#: 50029 Magnetic Declination: 22.549° Survey Name I Date: OP03 -0P5 (P8) / August 21, 2008 Total Field Strength: 57660.026 nT Tort 1 AHD I DDI I ERD ratio: 192.401° / 11423.79 ft / 6.869 / 2.877 Magnetic Dip: 80.929° Grid Coordinate System: NAD27 Alaska State Planes, Zone 04, US Feet Declination Date: September 30, 2008 Location Lat/Long: N 70.51110759, W 149.86296286 Magnetic Declination Model: BGGM 2008 • Location Grid NIE YIX: N 6036573.689 ftUS, E 516746.428 ftUS North Reference: True North Grid Convergence Angle: +0.12918578° Total Corr Mag North .> True North: +22.549° Grid Scale Factor: .0.99990032 Local Coordinates Referenced To: Well Head Measured Vertical Mag /Gray Directional Comments Inclination Azimuth Sub -Sea TVD ND NS EW DLS Northing Easting Latitude Longitude Depth Section Tool Face Difficulty (ft) (deg) (deg) (ft) (ft ) (ft) (ft) (ft) (deg) (deg/100ft ) Index (NUS) (ftUS) KOP Cry 4/100 5449.32 67.00 5.00 3528.00 3580.00 2231.55 2190.00 2400.00 40.51 L 0.00 5.86 6038768.87 519141.24 N 70.51708929 W 149.84331973 5500.00 68.55 3.59 3547.17 3599.17 2278.38 2236.78 2403.51 39.98L 4.00 5.88 6038815.65 519144.64 N 70.51721708 W 149.84329090 5600.00 71.63 0.88 3581.22 3633.22 2372.36 2330.71 2407.15 39.05L 4.00 5.90 6038909.58 519148.07 N 70.51747369 W 149.84326086 5602.93 71.73 0.80 3582.15 3634.15 2375.15 2333.49 2407.19 - -- 4.00 5.91 6038912.37 519148.10 N 70.51748129 W 149.84326052 5606.04 71.73 0.80 3583.12 3635.12 2378.10 2336.45 2407.23 2.91L 0.00 5.91 6038915.32 519148.14 N 70.51748936 W 149.84326017 5700.00 75.48 0.60 3609.64 3661.64 2468.22 2426.56 2408.33 2.85L 4.00 5.93 6039005.42 519149.04 N 70.51773553 W 149.84325090 5800.00 79.47 0.40 3631.32 3683.32 2565.82 2524.15 2409.19 2.81L 4.00 5.96 6039103.01 519149.67 N 70.51800215 W 149.84324364 5900.00 83.47 0.20 3646.15 3698.15 2664.68 2623.03 2409.71 2.78L 4.00 5.99 6039201.88 519149.97 N 70.51827226 W 149.84323910 End Cry / Heel Tgt 5938.32 85.00 0.13 3650.00 3702.00 2702.81 2661.16 2409.82 - -- 4.00 6.00 6039240.00 519150.00 N 70.51837642 W 149.84323809 9 -5/8" Csg 5938.44 85.00 0.13 3650.01 3702.01 2702.92 2661.27 2409.82 - 0.00 6.00 6039240.11 519150.00 N 70.51837672 W 149.84323809 Cry 4/100 5958.32 85.00 0.13 3651.74 3703.74 2722.73 2681.08 2409.87 180.00L 0.00 6.00 6039259.92 519150.00 N 70.51843084 W 149.843237 6000.00 83.33 0.13 3655.98 3707.98 2764.18 2722.54 2409.96 180.00L 4.00 6.01 6039301.38 519150.00 N 70.51854411 W 149.843236 End Cry 6056.51 81.07 0.13 3663.65 3715.65 2820.16 2778.52 2410.09 - -- 4.00 6.03 6039357.36 519150.00 N 70.51869705 W 149.84323561 Cry 4/100 6078.53 81.07 0.13 3667.06 3719.06 2841.92 2800.28 2410.14 HS 0.00 6.03 6039379.11 519150.00 N 70.51875648 W 149.84323515 6100.00 81.93 0.13 3670.24 3722.24 2863.14 2821.51 2410.18 HS 4.00 6.04 6039400.34 519150.00 N 70.51881448 W 149.84323471 O -P5 Tgt 1 6189.22 85.50 0.13 3680.00 3732.00 2951.80 2910.18 2410.38 HS 4.00 6.06 6039489.00 519150.00 N 70.51905672 W 149.84323283 6200.00 85.93 0.13 3680.81 3732.81 2962.55 2920.93 2410.41 HS 4.00 6.06 6039499.75 519150.00 N 70.51908608 W 149.84323260 6300.00 89.93 0.13 3684.41 3736.41 3062.45 3020.84 2410.63 HS 4.00 6.09 6039599.65 519150.00 N 70.51935903 W 149.84323049 End Cry 6304.85 90.12 0.13 3684.41 3736.41 3067.30 3025.69 2410.64 - -- 4.00 6.09 6039604.50 519150.00 N 70.51937227 W 149.84323039 Cry 4/100 6492.24 90.12 0.13 3684.00 3736.00 3254.68 3213.09 2411.07 179.53R 0.00 6.12 6039791.88 519150.00 N 70.51988421 W 149.84322644 O -P5 Tgt 2 6495.37 90.00 0.13 3684.00 3736.00 3257.80 3216.21 2411.07 180.00L 4.00 6.13 6039795.00 519150.00 N 70.51989275 W 149.84322637 6500.00 89.81 0.13 3684.01 3736.01 3262.43 3220.84 2411.08 180.00L 4.00 6.13 6039799.63 519150.00 N 70.51990540 W 149.84322627 WellDesign Ver SP 2.1 Bld( doc40x_100) OP03 \OP03- 0P5 \OP03- 0P5 \OP03 -0P5 (P8) Generated 8/21/2008 12:38 PM Page 1 of 3 Measured Vertical Mao /Gray Directional Comments Inclination Azimuth Sub-Sea ND TVD NS EW DLS Northing Easting Latitude Longitude Depth Section Tool Face Difficulty (k) (deg) I (deg) (k) (ft) (k) (k) (k) ( deg) (deg1100ft ) Index (kUS) (ftUS) End Cry 6522.32 88.92 0.13 3684.25 3736.25 3284.75 3243.16 2411.13 -- 4.00 6.13 6039821.95 519150.00 N 70.51996637 W 149.84322580 Cry 4/100 6758.39 88.92 0.13 3688.70 3740.70 3520.75 3479.19 2411.67 LS 0.00 6.17 6040057.96 519150.00 N 70.52061117 W 149.84322082 O -P5 Tgt 3 6771.44 88.40 0.13 3689.00 3741.00 3533.80 3492.24 2411.70 180.00L 4.00 6.17 6040071.00 519150.00 N 70.52064681 W 149.84322054 End Cry 6785.66 87.83 0.13 3689.47 3741.47 3548.01 3506.45 2411.73 - -- 4.00 6.18 6040085.21 519150.00 N 70.52068564 W 149.84322024 Cry 4/100 7045.90 87.83 0.13 3699.32 3751.32 3808.03 3766.50 2412.31 LS 0.00 6.21 6040345.24 519150.00 N 70.52139606 W 149.84321475 O -P5 Tgt 4 7061.68 87.20 0.13 3700.00 3752.00 3823.79 3782.27 2412.35 180.00L 4.00 6.22 6040361.00 519150.00 N 70.52143913 W 149.84321442 End Cry 7075.88 86.63 0.13 3700.76 3752.76 3837.97 3796.45 2412.38 - -- 4.00 6.22 6040375.18 519150.00 N 70.52147787 W 149.84321412 Cry 4/100 7303.85 86.63 0.13 3714.16 3766.16 4065.52 4024.02 2412.89 LS 0.00 6.25 6040602.73 519150.00 N 70.52209956 W 149.84320931 O -P5 Tgt 5 7317.15 86.10 0.13 3715.00 3767.00 4078.79 4037.29 2412.92 180.00L 4.00 6.26 6040616.00 519150.00 N 70.52213582 W 149.84320903 End Cry 7327.50 85.69 0.13 3715.74 3767.74 4089.12 4047.62 2412.95 - -- 4.00 6.26 6040626.33 519150.00 N 70.52216403 W 149.84320881 Cry 4/100 8023.40 85.69 0.13 3768.09 3820.09 4782.96 4741.54 2414.51 HS 0.00 6.34 6041320.18 519150.00 N 70.52405972 W 149.8431941 O -P5 Tgt 6 8036.25 86.20 0.13 3769.00 3821.00 4795.78 4754.36 2414.54 HS 4.00 6.35 6041333.00 519150.00 N 70.52409475 W 149.8431938 End Cry 8050.58 86.77 0.13 3769.88 3821.88 4810.08 4768.66 2414.57 - -- 4.00 6.35 6041347.30 519150.00 N 70.52413381 W 149.84319358 Cry 4/100 8338.62 86.77 0.13 3786.09 3838.09 5097.63 5056.24 2415.22 HS 0.00 6.38 6041634.85 519150.00 N 70.52491944 W 149.84318751 O -P5 Tgt 7 8356.79 87.50 0.13 3787.00 3839.00 5115.77 5074.40 2415.26 HS 4.00 6.39 6041653.00 519150.00 N 70.52496903 W 149.84318712 End Cry 8374.54 88.21 0.13 3787.66 3839.66 5133.51 5092.13 2415.30 - -- 4.00 6.39 6041670.74 519150.00 N 70.52501749 W 149.84318675 Cry 4/100 8762.79 88.21 0.13 3799.79 3851.79 5521.52 5480.19 2416.18 HS 0.00 6.43 6042058.75 519150.00 N 70.52607760 W 149.84317855 O -P5 Tgt 8 8770.04 88.50 0.13 3800.00 3852.00 5528.77 5487.44 2416.19 HS 4.00 6.44 6042066.00 519150.00 N 70.52609740 W 149.84317840 End Cry 8773.65 88.64 0.13 3800.09 3852.09 5532.37 5491.04 2416.20 - -- 4.00 6.44 6042069.61 519150.00 N 70.52610725 W 149.84317832 Cry 4/100 9133.29 88.64 0.13 3808.60 3860.60 5891.88 5850.59 2417.01 HS 0.00 6.48 6042429.11 519150.00 N 70.52708947 W 149.84317072 O -P5 Tgt 9 9167.18 90.00 0.13 3809.00 3861.00 5925.76 5884.48 2417.09 90.00L 4.00 6.48 6042463.00 519150.00 N 70.52718205 W 149.84317001 End Cry 9167.20 90.00 0.13 3809.00 3861.00 5925.78 5884.50 2417.09 - -- 4.00 6.48 6042463.02 519150.00 N 70.52718211 W 149.84317000 Cry 4/100 9486.20 90.00 0.13 3809.00 3861.00 6244.74 6203.49 2417.81 90.00R 0.00 6.52 6042781.98 519150.00 N 70.52805354 W 149.84316326 O -P5 Tgt 10 9486.22 90.00 0.13 3809.00 3861.00 6244.76 6203.51 2417.81 180.00L 4.00 6.52 6042782.00 519150.00 N 70.52805360 W 149.84316326 End Cry 9498.73 89.50 0.13 3809.05 3861.05 6257.27 6216.02 2417.84 - -- 4.00 6.52 6042794.51 519150.00 N 70.52808777 W 149.84316300 Cry 4/100 9833.76 89.50 0.13 3811.98 3863.98 6592.25 6551.03 2418.59 0.47R 0.00 6.55 6043129.49 519150.00 N 70.52900299 W 149.84315592 O -P5 Tgt 11 9836.27 89.60 0.13 3812.00 3864.00 6594.75 6553.54 2418.60 HS 4.00 6.55 6043132.00 519150.00 N 70.52900984 W 149.84315587 End Cry 9840.01 89.75 0.13 3812.02 3864.02 6598.50 6557.29 2418.61 - -- 4.00 6.55 6043135.75 519150.00 N 70.52902008 W 149.84315579 Cry 4/100 10292.07 89.75 0.13 3813.99 3865.99 7050.50 7009.34 2419.63 179.06R 0.00 6.60 6043587.75 519150.00 N 70.53025501 W 149.843146 O -P5 Tgt 12 10293.32 89.70 0.13 3814.00 3866.00 7051.75 7010.59 2419.63 178.75L 4.00 6.60 6043589.00 519150.00 N 70.53025842 W 149.843146 End Cry 10294.28 89.66 0.13 3814.01 3866.01 7052.71 7011.55 2419.63 - -- 4.00 6.60 6043589.96 519150.00 N 70.53026104 W 149.84314618 Cry 4/100 10796.34 89.66 0.13 3816.97 3868.97 7554.70 7513.60 2420.76 LS 0.00 6.64 6044091.96 519150.00 N 70.53163257 W 149.84313557 10800.00 89.52 0.13 3817.00 3869.00 7558.36 7517.26 2420.77 LS 4.00 6.64 6044095.62 519150.00 N 70.53164257 W 149.84313549 O -P5 Tgt 13 10800.38 89.50 0.13 3817.00 3869.00 7558.74 7517.64 2420.77 179.60L 4.00 6.64 6044096.00 519150.00 N 70.53164360 W 149.84313549 End Cry 10803.21 89.39 0.13 3817.03 3869.03 7561.58 7520.47 2420.78 - -- 4.00 6.64 6044098.84 519150.00 N 70.53165136 W 149.84313543 Cry 4/100 11265.29 89.39 0.13 3821.98 3873.98 8023.57 7982.52 2421.82 179.47R 0.00 6.68 6044560.84 519150.00 N 70.53291360 W 149.84312566 O -P5 Tgt 14 11267.45 89.30 0.13 3822.00 3874.00 8025.73 7984.68 2421.83 179.41L 4.00 6.68 6044563.00 519150.00 N 70.53291950 W 149.84312561 End Cry 11269.45 89.22 0.13 3822.03 3874.03 8027.73 7986.68 2421.83 - -- 4.00 6.68 6044565.00 519150.00 N 70.53292497 W 149.84312557 Cry 4/100 11702.04 89.22 0.13 3827.91 3879.91 8460.23 8419.23 2422.80 LS 0.00 6.72 6044997.50 519150.00 N 70.53410661 W 149.84311642 O -P5 Tgt 15 11707.54 89.00 0.13 3828.00 3880.00 8465.73 8424.73 2422.82 179.47L 4.00 6.72 6045003.00 519150.00 N 70.53412163 W 149.84311631 WellDesign Ver SP 2.1 Bld( doc4ox_100) OP03 \OP03- 0P5 \OP03- 0P5 \0P03 -0P5 (P8) Generated 8/21/2008 12:38 PM Page 2 of 3 Measured Vertical Mag /Gray Directional Comments Inclination Azimuth Sub -Sea ND TVD NS EW DLS Northing Easting Latitude Longitude Depth Section Tool Face Difficulty ty (ft) (deg) (deg) (ft) (ft) (ft) (ft) (ft) (deg) (deg1100ft ) Index (ftUS) (ftUS) End Cry 11709.76 88.91 0.13 3828.04 3880.04 8467.96 8426.95 2422.82 -- 4.00 6.72 6045005.23 519150.00 N 70.53412772 W 149.84311626 Cry 4/100 12232.16 88.91 0.13 3837.97 3889.97 8990.20 8949.26 2424.00 179.22R 0.00 6.76 6045527.48 519150.00 N 70.53555457 W 149.84310521 O -P5 Tgt 16 12233.69 88.85 0.13 3838.00 3890.00 8991.72 8950.78 2424.00 178.93L 4.00 6.76 6045529.00 519150.00 N 70.53555873 W 149.84310518 End Cry 12234.80 88.81 0.13 3838.02 3890.02 8992.83 8951.89 2424.01 -- 4.00 6.76 6045530.11 519150.00 N 70.53556177 W 149.84310516 5 -1/2" Lnr Pt 12329.64 88.81 0.13 3840.00 3892.00 9087.64 9046.71 2424.22 - -- 0.00 6.77 6045624.93 519150.00 N 70.53582081 W 149.84310315 Cry 4/100 12602.17 88.81 0.13 3845.68 3897.68 9360.08 9319.18 2424.83 LS 0.00 6.79 6045897.37 519150.00 N 70.53656515 W 149.84309739 O -P5 Tgt 17 12614.81 88.30 0.13 3846.00 3898.00 9372.72 9331.82 2424.86 180.00L 4.00 6.79 6045910.00 519150.00 N 70.53659967 W 149.84309712 End Cry 12628.11 87.77 0.13 3846.46 3898.46 9386.01 9345.11 2424.89 - -- 4.00 6.79 6045923.30 519150.00 N 70.53663599 W 149.84309684 Cry 4/100 12805.79 87.77 0.13 3853.38 3905.38 9563.53 9522.66 2425.29 LS 0.00 6.81 6046100.82 519150.00 N 70.53712101 W 149.84309309 0-P5 Tgt 18 12819.98 87.20 0.13 3854.00 3906.00 9577.71 9536.84 2425.32 180.00L 4.00 6.81 6046115.00 519150.00 N 70.53715975 W 149.84309278 End Cry 12832.06 86.72 0.13 3854.64 3906.64 9589.76 9548.89 2425.35 - -- 4.00 6.81 6046127.05 519150.00 N 70.53719268 W 149.8430925 Cry 4/100 12976.90 86.72 0.13 3862.94 3914.94 9734.35 9693.50 2425.68 LS 0.00 6.82 6046271.64 519150.00 N 70.53758772 W 149.84308947 13000.00 85.79 0.13 3864.44 3916.44 9757.40 9716.55 2425.73 LS 4.00 6.82 6046294.69 519150.00 N 70.53765069 W 149.84308898 0-P5 Tgt 19 13007.33 85.50 0.13 3865.00 3917.00 9764.71 9723.86 2425.75 180.00L 4.00 6.83 6046302.00 519150.00 N 70.53767066 W 149.84308883 End Cry 13031.76 84.52 0.13 3867.12 3919.12 9789.05 9748.20 2425.80 - 4.00 6.83 6046326.34 519150.00 N 70.53773715 W 149.84308831 Cry 4/100 13108.30 84.52 0.13 3874.43 3926.43 9865.22 9824.38 2425.97 LS 0.00 6.83 6046402.51 519150.00 N 70.53794528 W 149.84308670 0-P5 Tgt 20 13123.86 83.90 0.13 3876.00 3928.00 9880.71 9839.87 2426.01 180.00L 4.00 6.84 6046418.00 519150.00 N 70.53798758 W 149.84308637 End Cry 13132.84 83.54 0.13 3876.98 3928.98 9889.63 9848.79 2426.03 4.00 6.84 6046426.92 519150.00 N 70.53801195 W 149.84308618 Cry 4/100 13165.69 83.54 0.13 3880.68 3932.68 9922.27 9881.43 2426.10 LS 0.00 6.84 6046459.56 519150.00 N 70.53810114 W 149.84308550 13200.00 82.17 0.13 3884.94 3936.94 9956.31 9915.47 2426.18 LS 4.00 6.84 6046493.60 519150.00 N 70.53819413 W 149.84308478 13300.00 78.17 0.13 3902.02 3954.02 10054.81 10013.99 2426.40 LS 4.00 6.86 6046592.10 519150.00 N 70.53846325 W 149.84308269 0 Tgt 21 13314.22 77.60 0.13 3905.00 3957.00 10068.71 10027.89 2426.43 LS 4.00 6.86 6046606.00 519150.00 N 70.53850122 W 149.84308240 TD 13373.80 75.22 0.13 3919.00 3971.00 10126.61 10085.79 2426.56 - -- 4.00 6.87 6046663.90 519150.00 N 70.53865941 W 149.84308116 Survey Error Model: SLB ISCWSA version 24*** 3 -D 95.00% Confidence 2.7955 sigma Surveying Proq: MD From (ft ) MD To (ft 1 EOU Freq Survey Tool Type Borehole -> Survey 0.00 40.00 1/100.00 SLB_NSG +SSHOT -Depth Only OP03- OP5PB1 -> OP03- OP5PB1 (P5) 40.00 650.00 1/100.00 SLB_NSG +SSHOT OP03- 0P5P81 -> OP03- OP5PB1 (P5) 650.00 5449.32 1/100.00 SLB_MWD +GMAG OP03- OP5PB1 -> OP03- OP5PB1 (P5) 5449.32 13373.80 1/100.00 SLB_MWD +GMAG OP03 -0P5 -> OP03 -0P5 (P8) Legal Description: Northing (Y) fftUSl Easting (X) fftUSj Surface : 3220 FSL 1533 FEL S5 T13N R9E UM 6036573.69 516746.43 Target : 601 FSL 4395 FEL S33 T14N R9E UM 6039240.00 519150.00 BHL : 2746 FSL 4356 FEL S28 T14N R9E UM 6046663.90 519150.00 WellDesign Ver SP 2.1 Bld( doc40x_100) OP03 \OP03- OP5 \OP03- 0P5 \OP03 -0P5 (P8) Generated 8/21/2008 12:38 PM Page 3 of 3 int End Petroleum Schlumberger I VVELL OP03- OP5PB1 (P5) / OP5 (P8) I FIELD Nikaitchuq 16TRDDTDRE Oliktok Point Magnetic Parameters Model BGGM 2000 Dip: 0929 Surface Location NA02]Apda Stale Planes, Zone US Fab MicceWneous Dale'. Se ]ember 30, 2006 Lel - N]03039.98] Noribin 60365]3.69 BUS NO x0.129185]8' SW: OP03 TVD Ref. Rotary Table (52.008 above MSL) Meg Dec: 822049• FS: 5]6600 nT Lon'. W149 51 46.666 Easting9 516746.43 BUS Scale Fad: 0.9999003186 I Plan: OP03- 0P5 (PS) S,sy Date: August21, 2008 0 1200 2400 3600 RTE 0 1NRP 0 KOP Bid 1.5/100 a • Bid 2.5/100 Gyro Point Cry 3/100 0 1200 1200 0 0 1200 N )0 9600 C_ • End Cry 0 RTE 0 • ii 13 -3/8" C sg WRP y - CrV 3/100 KOP Bid 1.5/100 0 Bid 2.5/100 Cl) D Gyro Point 0 2400 •••• 2400 Cry 3/100 Cry 31100 1200 End Cry /Heel Tgt 95 1200 Cry M 00 KOP Cry 4/100 End Cry E _.._.._.._.._.. _. _.._ .. Lower Ugnu._.. -.._ _.._.._. _.. •_• / Crv4 /100 O _.._.._.._.._.._. _.._.._.._.._.._.._.._.._ ._.. _.._.._.._.._.._. _.._.. ._ -- : : 0 3600 - ' - ' - - --- - -- -- - - - - - Sctv3ii"BW(f._.._. _.. • _.. _ N .. .. .. .;.. .. .. - - .. .. .. .. .. .. 'C:.;B• BaseNSand End C 3600 Cry . _.._.._.._.._.._. _.. _.._.._.._..- ..- .._.._ ._.._.._.._. .. _.._.._.. -. Z • dp OA SadO " Enrl Cry OP03 -0P S (P8) C 13 - 3/8• Csf ),`' Cry 3 /10d OP03 OP5PB1 (P D II 0 1200 2400 3600 a) 2400 Cry 3.100 2400 m Vertical Section (ft) Azim = 40 °, Scale = 1(in):1200(ft) Origin = 0 N / -S, 0 E / -V to 0 _.._.._.. ._.._.._.._.._. _.._.._.._.._.._.._.._.._.._.._.._.._.._. ._..___.._.._.._.._.._.._.._.._ ._.._.._.._.._.._.._.._.._.._.._.._.._.._.._.._.._.._.._.._.._.._ .._.._.._.._.._.._.._.._.._.._. • • u End Cry / H4el Tgt 9 Csg Cry 41100 Cry 4 /100 KOP Cry 41100 End Cry Cry 4/100 I e -p5 Tgt 3 • End Cry 0.P5 Tgt 5 O -P5 Tgt 19 �� :End Cry - • - Ugriu •• -•• I • O -P5 Tgt 1 ' Cry 41100 End Cry O- i5 Tgt 1 0-P5 Tgt 11 : O -PS Tgt 17 Cry End Cry End Cry . End C - - - O -p.5 Tgt 13 0-P5 Tgt Cry 4/100 End • Cry 41100 .._.. CrV 41100 nO-P5 Tgt Crv4 /100 E Cry 9 gt i5 _ .. _.._.._. ..t - .._.. .._.._..- .. -.._.. .._.._.._.._. > -.._ v :: ._.. .. a.._.._. ._ .._.._.._ .. ._..> -.. _ _.._. 3600 - - _..S(�aderOlQ�: � : - :: - :: - ° ase ' ':14.`',101,11 . I. _ .._.._.. _.._.. _.._.._.._.._.: -.._ .._..�rv4/1no_. o._.._ Oadc Eodc�.:c ; ;a ; ;s - - - 1213600 _ _ ._ ._ ._ _ . I 1 f/ I .._.._.._.._.._.. _.._.._.._.._.._ I - TM. _.._.._.._ ._.._.._.. _.. _.._.._.._.. _.. - ••fop OA Sand • Ili TD Cry 4/100 End Cry End Cry .e P03 -0P5 (P8) End Cry Cry 4 /100 Cry Cry 4/100 Crv4/100 0.P5 Tgt2 Cry 4L700 Cry 4/100 Crv4 /100 EndCry O -P t 4 Cry 41100 End Cry End Cry : End Cry 0.P5 41100 Tgt 14 0-P5 Tgt 16 End Cry g 0-P5 Tgt 6 0.P5 Tgt 12 End Cry O -PS Tgt t9 O -PS T9t 8 O -PS Tgt 10 5-112" Lnr Pt End iry Cry 4!100 t 20 0 1200 2400 3600 4800 6000 7200 8400 9600 Vertical Section (ft) Azim = 1 °, Scale = 1(in):1200(ft) Origin = 0 N / -S, 0 E / -V • • rfk E ni Petroleum Schlumberger Eni WELL FIELD OP03- OP5PB1 (P5) / OP5 (P8) I Nikaitchuq I s '''''''' Oliktok Point Magn1ic Paramelers Surface Location NAD27 Masi. State Planes, zone 04 US Feel � an os Model ROOM 2008 Dip 80929' Dale September 30, 2008 Lal N70 30 39 987 Northing 6036573 69 Gnd Cony: «0 12918578 OP03 TVD Ref'. Rotary Table (52001t above MSL) Mag Dec'. +22.549' FS'. 576600 nT Lon W149 51 46 666 E.9189. 516746 438US Scale Fan: 09999003188 Plan. OP03 -035 (P8) Sr, Dale' 09926121, 2008 1 -1500 0 1500 3000 4500 10500 • 10500 OP03 -0P5 (P8) TO End Cry 0-PS Tgt 21 O -P Tgt 20 Cry 4/100 Cry 4/100 End Cry 045 Tgt 19 End Cry Cry 41100 9-P5 Tgt 18 Emil Cry : Cry 4/100 5%1 /2" Lnr Pt O:P5 Tgt 17 9000 ...p. Gr.! 9000 ;End Cry I 045 Tgt 16 N Cr/ 4/100 End CN O-P5 Tgt 15 End Cry Cry 4/100 —.MI /- P5Tgt14 Cry 4/100 End Cry 7500 ""a Psrgt'1s 7500 End Cry 4100 0-P5 Tgt 12 Cry 4/100 End Ccv O-P5 Tgt 11 A End Cry Cry 4/ 00 ^ p -Ps Tgt 10 ^ : Cry 4/100 Z 6000 r Eodix s 6000 0-P5 igt 9 ' End Cry Cry 4/i00 O O O- P5 Tgt 8 1t7 Cry 4/100 End Ctry — O- P5!rgt 7 End Cry Cry 4/100 O- P5 Tgt 6 II Cry 4/100 O 4500 4500 co 0 (p End Cry (I) End Cry 0-P5 tgt 5 V O- P5 Tgt 4 C 4 /i 00 V Cry 4/100 End )rry ✓ 0-Pi Tgt 3 End Cry Cry 4/100 O-P5 Tgt 2 End Cry 3000 Cry 9!194 0 igty 3000 End Cry Cry 4100 Cry 4/100 948" Csg OP03- 0P5PB1 (P5) End Croe / Heel Tgt lb KOP Cry 4/100 End Cry 1500 r 1500 Cry 3/100 133/8" Cs Epd Cry Cry 3/100 ..p Cr/ 3/100 Gyro Point 0 Bld 2.5/100 0 0 KOP Bld 1.5/100 RTE - 1500 0 1500 3000 4500 c« W Scale = 1(in):1500(ft) E »> • 0 ANTICOLLISION SUMMARY REPORT Client: ENI Slot: 0P03 Field: Nikaitchuq Well: 0P03 -0P5 Structure: Oliktok Point Borehole: 0P03- 0P5PB1 Subject Trajectory: 0P03- 0P5PB1 (P5) (PLAN) Rpt Date: August 21, 2008 Analysis Method: Normal Plane Depth Interval: Every 5.00ft MD EOU Type: Oriented EOU used. Min Pts: All local minima indicated. ProbColMax: 1:25959 Mag Model: BGGM 2008 Offset Trajectory Sep. Allow Sep. Subject Trajectory Separation Factor Alert Status Ct -Ct (ft) Dev. (ft) Fact. MD (ft) I TVD (ft) Alert I Minor 1 Major Oliktok I -1 (DEF SVY) PASS 15.98 13.47 2904.61 39.00 39.00 MinPt -CtCt 16.08 13.37 96.74 84.00 84.00 MinPt -O -ADP 16.231 13.381 58.42 109.00 109.00 MinPt -O -ADP 26.10 21.011 13.641 348.71 348.71 MinPt -O -SF 200.18 186.28 1 26.011 1370.14 1340.70 MinPt -0-SF 11 359.8511 320.66 14.61 3111.66 2509.58 MinPt -CtCt 360.4211 320.101 14.19 3173.59 2537.38 MinPt -O -ADP 385.78 341.02 13.60 3356.36 2621.61 MinPt -O -SF 3528.79 3435.581 58.311 6013.21 3800.33 MinPt-O-SF Oliktok 1-2 (DEF SVY) PASS I I 8.2011 5.70 1229.55 38.35 38.35 MinPt-CtCt 7.96 3.79 4.91 243.33 243.33 5.00 Enter Alert 7.92 3.51 4.25 263.31 263.31 MinPt-CtCt 8.21 3.18 3.38 308.25 308.25 MinPt -O -ADP 8.77 3.38 325 333.20 333.20 MinPt -O -SF 15.54 9.04 4.89 447.98 447.97 5.00 Exit Alert 6901.61 6857.80 1 250.481 1667.69 1600.33 MinPt -O -SF 7416.70 7293.831 92.391 6012.48 3800.04 MinPt -O -SF Version DO 4.0 (doc40x_100) SP 2.1 - ANTICOLLISION SUMMARY REPORT Generated 8/21/2008 1:17 PM Page 1 of 1 • • S cbiumberger TRAVELING CYLINDER PLOT Client: ENI NoGo Region EOU's based on Well: OP03 -0P5 Oriented EOU Dimension Field: Nikaitchuq N Structure: Oliktok Point NoGo Region Anticollision rule used: Minor Risk - Separation Factor A Date: September 21, 2008 North I 350 0 10 340 .11# 330 30 140 320 40 120 / 50 100 300 . 60 80 290 60 70 40 280 if ' BPS - 80 a 1t'; . <►si:41%Pi� . p 270 ir ` .r WI „ A 260 d► �►' ' 1 1ir► ` 250 �� po v �1 � .110 °a w 11POliktok 1 -1 o 2 40 120 " a . 230 130 220 140 210 150 200 160 190 180 170 Well Ticks Type: MD on OP03- OP5PB1(P5) Calculation Method: Normal Plane Ring Interval: 20.00 ft Azimuth Interval: 10.0 deg Scale: 1 INCH = 50.00 ft Elm ■ .I Project: NIKAITCHUQ IPeiIroIIeUI i Site: OLIKTOK POINT Well: OP03 -P05 REFERENCE INFORMATION Co- ordinate (N /E) Reference: Well OP03 -P05, True North PROJECT DETAILS: NIKAITCHUO Vertical (TVD) Reference: 245 E @ 52.0ft (Nabors 245 E) Geodetic System: US State Plane 1927 (Exact solution) Datum: NAD 1927 (NADCON CONUS) Measured Depth Reference: 245 E @ 52.0ft (Nabors 245 E) Zone: Alaska Zone 04 Calculation Method: Minimum Curvature System Datum: Mean Sea Level • 6100000 6048000 6090000 6046500 O P03 -P05 - 6080000 0 ° 6045000 0° 6070000 —� - 0 ° 0 - 0 0 6043500 0 6060000 0° c 6042000 6050000 • 0 Z 0° 0 Z - 6040500 0° 6040000 6039000 OP03- P05PB1 6030000 20° -_ 6037500 6020000 5 72 56° I I 1 1 I I 1 1 I I I I� ° I I - 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 -, 1 1 1 1 1 1 1 1 1 1 1 1 I I I ! 1 1 1 1 1 1 1 1 1 1 1 1 I I I 513000 514500 516000 517500 519000 520500 522000 523500 525000 470000 480000 490000 500000 510000 520000 530000 540000 Easting (3000 ft/in) Easting (20000 ft/in) • • AKA FRANK H. MURKOWSKI, GOVERNOR 0 v 550 WEST 7 AVENUE, SUITE 1400 ANCHORAGE, ALASKA 99501 -3650 PHONE: (907) 269 -8800 FAX (907) 269 -8918 DEPARTMENT OF NATURAL RESOURCES Division of Oil and Gas November 3, 2006 Roger Smith Kerr McGee Oil and Gas Corporation 3900 C Street Anchorage, AK 99503 Re: Land Use Permit Amendment (ADL 417493) for the Addition of Nine Wellbores at Oliktok Point Dear Mr. Smith: The Division of Oil and Gas (DO &G) has reviewed the Kerr McGee Oil and Gas Corporation request for amendment of ADL 417493 dated Septem ber 29, 2006. The purpose of this amendment is to authorize the additional easement necessary to include nine well bores for Nikaitchuq Development within the Kuparuk River Unit. A map depicting the general planned location of these well bores is attached. The Division of Oil and Gas has no o bjection to the addition of these wellbores to ADL 417493. The LUP is hereby amended to authorize these wellbores. All other terms and conditions of the permit remain unchanged Please note that this permit applies to State -owned land only. Authorization of non -State land should be obtained from the landowner. A person affected by this Decision may appeal it, in accordance with 11 AAC 02. Any appeal must be received by the Commissioner's office within 20 calendar days after issuance of the Decision, as determined under 11 AAC 02.040, and may be mailed or delivered to Michael Menge, Commissioner, Department of Natural Resources, 550 W. 7th Avenue, Suite 1400, Anchorage, Alaska 99501; faxed to 1- 907 - 269 -8918; or sent by electronic mail to dnr appeals a,dnr.state.ak.us. This Decision takes effect immediately. An eligible person must first appeal this Decision to the Commissioner in accordance with 11 AAC 02 before appealing this Decision to state Superior Court. A copy of 11 AAC 02 may be obtained from any regional information office of the Department of Natural Resources. Should you have any questions, please contact me at (907) 269 -8777. Sincerely, Steven Schmitz Natural Resource Special ist "Develop, Conserve, and Enhance Natural Resources for Present and Future Alaskans." • 1 R. Smith /Nik LUP EEA Well Bore Amendment 11 /3/06 Page 2 of 2 Enclosures: Map of Additional Easement Operation Overview cc: John Cookson, ConocoPhillips Alaska, Inc. Johnny Aiken, NSB Leon Lynch, Gary Schultz, Patricia Bettis, ADNR /Division of Mining, Land & Water Ben Greene, Shane Walker ADNR /OPMP Jack Winters, ADNR /OHMP Lydia Miner, ADEC /SPAR Terry Carpenter, USCOE Temple Davidson, DO &G • • Operational Overview Wellbores for Nikaitchuq Development Program Within Kuparuk River Unit Kerr McGee Oil and Gas Corporation (KMG) proposes to drill up to nine wells from the Kerr McGee Processing Pad located at Oliktok Point previously approved under Land Use Permit (LUP) ADL 417493 The wells will pass through two leases of the Kuparuk River Unit (KRU) to targets on leases operated by KMG. KMG has changed the Development Plan to include these wellbores in the LUP. A public notice for the proposed well bores and activities began on October 11, 2006 and no comments were received during the public notice period. Access to the development activities will be over existing KRU gravel roads. The maps included with this permit application show the general wellbore paths. The final wellbores will be specifically located once drilled and be included in the A s -Built as stipulated for the other facilities of this project. This amendment to the original LUP will add approximately 48,000' of easement (25' each side of centerline), for a total additional acreage of approximately 55 acres. The land added to the LUP by this amendment is entirely subsurface. 1 The activity will be located on T. 13N., R.9 E., Secs. 4, 5, & 6 Umiat Meridian and the wells will pass through ADL 0337701 and 0355023 within the KRU. The drilling program to be initiated in November of 2006 and will utilize the Nabors 245 (or equivalent) rig. KMG will initially drill two wells from a gravel pad constructed at Oliktok Point. A portion of the gravel pad originally approved under ADL 417493 has been constructed to support these wells. Maximum estimated flow rate for any well is 2,000 barrels per day using artificial lift. Water use for the project will be from permitted water sources. • • nal (3p SARAH FALIN, GOVERNOR ❑ 550 WEST 7"' AVENUE, SUITE 1400 ANCHORAGE ALASKA 99501 -3650 PHONE: (9071269 -8800 FAX.. (907) 269 -8918 DEPARTMENT OF NATURAL RESOURCES Division of 011 and Gas David Moles February 25, 2008 Eni US Operating Co. Inc. 1201 Louisiana, Suite 3500 Houston TX 77002 Re: Land Use Permit Amendment (ADL 417493) for the Reduction in Scope of Previously Planned Facilities Dear Mr. Moles; The Division of Oil and Gas (DO&G) has reviewed the Eni US Operating Co. Inc.(Eni) request for amendment of ADL 417493 dated November 13, 2007. The purpose of this amendment is to authorize the • Change in location of the westem offshore production island approximately 1 mile east • elimination of the two eastern pads from the original plan; • elimination of end point option of the gathering line tie-in from Oliktok Point to KRU CPF 1 and establishing the tie -in point to be the shorter 14 mile route near the KRU Spine Road Y • elimination of the option involving the use of KRU VSM's for the gathering line route from Oliktok Point to the Kuparuk Extension tie -in. Enclosed is a copy of the original Director's Decision and a revised Land Use Permit (LUP) that revises the description of the area being developed by Eni. I am also including a copy of the original Directors Decision and LUP stipulations. Please sign and retum a copy of the LUP to the Division along with proof of insurance as outlined in the Decision. Upon receipt, we will countersign and return a copy to you. Once you receive a countersigned copy, the amendment will be considered complete. Eni's failure to sign and retum the permit within 30 days of receipt constitutes rejection of the conditions of the permit and voids the permit, as well as all activities authorized under this permit. As a reminder, fees for the LUP are due March 29, 2008 ($20,900 annually). Additionally, a survey and appraisal are required upon completion of construction activities to convert the LUP into an easement, and performance guarantees and insurance, as described in the March 23, 2006, Director's Decision are also required. This permit applies to State -owned land only. Authorization of non -State land must be obtained from the landowner. A person affected by this Decision may appeal it, in accordance with 11 AAC 02. Any appeal must be received by the Commissioner's office within 20 calendar days after issuance of the Decision, as determined under 11 AAC 02.040, and may be mailed or delivered to Tom Irwin, Commissioner, Department of Natural Resources, 550 W. 7th Avenue, Suite 1400, Anchorage, Alaska 99501; "Develop, Conserve, and Enhance Natural Resources for Present and Future Alaskans." • D. MAolesIENI Nik Amendment 07 08 Cover letter 11 2125108 Page 2 of 2 faxed to 1 -907- 269 -8918; or sent by electronic mail to dnr appealsQdnr.state.ak.us. This Decision takes effect immediately. An eligible person must first appeal this Decision to the Commissioner in accordance with 11 AAC 02 before appealing this Decision to state Superior Court. A copy of 11 AAC 02 may be obtained from any regional information office of the Department of Natural Resources. Should you have any questions, please contact Steven Schmitz at (907) 269 -8777. Sincerely, r Kevintits Acting Director, Division of Oil and Gas Enclosures: Amended Land Use Permit/Early Entry Authorization 417493 Maps and figures of Revisions to LUP 417493 Operation Overview ADL 417493 Director's Decision Attachment A. Standard and Special Stipulations cc: John Cookson, ConocoPhillips Alaska, Inc. Johnny Aiken, Gordon Brower NSB Leon Lynch, Gary Schultz, Patricia Bettis, ADNR/Division of Mining, Land & Water Ben Greene, Jodi Plikat ADNR/DCOM Jack Winters, ADNR/OHMP Laurie Silfven/Patrick Dunn, ADEC Julie Woodke, Keith Gordon, USCOE Temple Davidson, DO &G • • STATE OF ALASKA DEPARTMENT OF NATURAL RESOURCES DIVISION OF OIL AND GAS Division of Oil and Gas 550 W. 7 Ave Anchorage, AK 99501 -3560 (907) 269-8777 LAND USE PERMIT Under AS 38.05.850 Nikaitchuq ADL 417493 (Ent) The Division of Oil and Gas (Division) is issuing this permit to Eni US Operating Co. Inc. (Eni) for the following described state owned uplands: the onshore pad and pipeline will be within: T. 13 N., R. 9 E., Sec. 4, 5: 16, 21, 28, 33; U.M. T. 12 N., R. 9 E., Sec. 2, 3, 10, 11, 15, 22, 23, 25, 26, 36; U.M. T. 11 N., R. 9 E., Sec. 1; U.M., (as depicted on the attached maps).and The offshore pads and pipeline will be on state owned tide and submerged lands within: T. 13 N., R. 9 E., Sec 5; U.M. and T. 14 N., R. 9 E., Sec. 19, 29, 30, 31, 32, U.M., (as depicted on the attached maps). The welibores in State subsurface are within: T. 13 N., R. 9 E., Sec. 4'5, ° 6 This permit is issued for the sole purpose of gaining early access to construct onshore and offshore pads, pipelines and welibores in support of the Nikaitchuq Unit development project as described in • KMG's July 7, 2005 plan of operations, • As amended by KMG's November 14, 2005 Mitigation Measure Analysis, • January 27 and March 3, 2006 correspondence with the Division, • KMG's acceptance of the November 7, 2005 Office of Project Management and Permitting Final Consistency Response Concurrence, • As supplemented by the February 16, 2006, United States Army Corps of Engineers (POA 2005- 1243 Simpson Lagoon) decision and permit, • As amended September 29,2006 to include well bores within the KRU, • As amended January 11, 2008 (plan dated November 13, 2007), • As amended February 18, 2008, Correspondence Eni with the Division. This permit is conditioned on Eni submitting proof of insurance as set out in the Division's March 23, 2006 Decision authorizing this permit and the attached stipulations (Attachment A). Eni is responsible for obtaining approvals or permits from other persons or governmental agencies that may also be required to undertake this project. This permit is a temporary authorization revocable by the Division with or without cause. This permit is effective upon countersignature by the state, and terminates on March 23, 2010, unless sooner terminated at the Division's sole discretion. Eni is responsible for maintaining a current address with the division during the life of this permit. Signature of Authorized State Representative Title Date Kevin Banks Acting Director, Division of Oil & Gas ./ - k .0eiro 40. 9 / 9 G70r ignature of Permittee or Authorized Representative Title Dat David Motes Eni US Operating Co. Inc. 1201 Louisiana, Suite 3500 Houston TX 77002 Fax Work Phone Contact Person • Operational Overview Nikaitchuq Development Program 2007/8 Project Amendment February 25, 2008 On February 6, 2007 with KMG concurrence, ADL 417493 was transferred to Eni US Operating Co. Inc. (Eni). On February 27, 2007, the Division of Oil and Gas (DO &G) approved that transfer request. In November 2007, Eni submitted an amended plan for the Nikaitchuq Development (dated November, 13 2007) that reduced the scope by eliminating or modifying prior approved options of the project that were proposed by KMG, and relocated one offshore island. Additional detail (maps and legal descriptions) were requested and subsequently provided February 18, 2008. The November 13, 2007 amended plan deleted the two eastern offshore production islands; relocated the Westem Production Island approximately 1 mile to the east; and the eliminated the option of tying the gathering line into the KRU CPF 1. Additionally, the amended plan established that the option of constructing gathering lines between Oliktok Point and the Kuparuk Extension tie - in would be done on new VSM's installed by Eni. On January 22, 2008 the Office of Project Management and Permitting consulted with Resource Agencies regarding the significance of the proposed amendments and established that they were not sufficient to warrant a new consistency review. Overall, the amendments were viewed as a reduction of the project resulting in fewer impacts to the area. This amendment adds; T. 14 n. R. 9 E. Sec. 29 This amendment deletes; T.14N. R8E.Sec.24and T. 11 N. R 10 E., Sections 5, 6, 8, 9, 10 The maps included with the Amended LUP show the reduced project and in combination with the applicable previous submittals constitute the current project. Maunder, Thomas E (DOA) From: joe.longo @enipetroleum.com Sent: Friday, August 29, 2008 11:12 AM To: Maunder, Thomas E (DOA) Subject: Re: Nikaitchuq OP03 -P-05 Attachments: 03 01 Plug Back Procedure.pdf POf � 03 01 Plug Back Procedure.pdf... Tom, Sorry for the late reply we had our pre spud /project overview meeting yesterday and I was out of the office. I reference to your questions: 1.) We are planning on setting one (1) 900' plug with 35% XS. We are planning on underdisplacing putting the tubing on vaccuum, POOH to approx. 5200' MD and circulating. Planned KOP is at approximatly 5450' MD. Our procedure is below. (See attached file: 03 01 Plug Back Procedure.pdf) 2.) We are not planning on running liner past our setting depth. Once we reach setting depth we are going to turn up at max DLS the tools can handle come out of the top of the sand and drop until we come out of the sand. This is to characterize the reservoir throughout the entire lateral section. 3.) The thinking behind the scavenger slurry: Due to the hole angles that we have (9 -5/8" at 85 deg and 13 -3/8" at 50 deg) the chances of us not getting cement into the surface casing are slim. We are going to run a retarder in the lead in order to provide ample time to bullhead diesel for freeze protect. Also, we can simplify things by calculating cement volumes to the previous shoe and including cement excess only in the tail. In addition by pumping a larger volume we are decreasing the chances of contaimination at the shoe. Lastly by running a large spacer we will be able to displace and reuse a lot of the MOBM that we have in the intermediate hole section. If you have any other questions please do not hesisitate to ask. Thank You, Joseph Longo Associate Drilling Engineer Eni Petroleum Anchorage, AK Office: (907) 865 -3323 Cell: (504) 952 -5520 E -Mail: Joseph.Longo @EniPetroleum.com "Maunder, Thomas E (DOA)" <tom.maunder @alas To ka.gov> joe.longo @enipetroleum.com cc 08/28/2008 01:25 PM Subject Nikaitchuq OP03 -P -05 1 Page 1 of 1 • • Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA) Sent: Thursday, August 28, 2008 1:26 PM To: 'joe.longo ©enipetroleum.com' Subject: Nikaitchuq OP03 -P -05 Joe, I am reviewing the permit application and have the following questions. 1. Please submit the planned plug back procedure for the pilot hole. I am particularly interested in how long the individual plugs might be. 2. You plan to drill beyond the intended setting depth for the slot liner. If that hole section is still "good" will the slotted liner be set deeper? 3. When you cement the 9 -5/8" casing, it is stated that you will use scavenger slurry and bring the TOC high (to the 13 -3/8" shoe) to enhance having a quality cement job at the shoe. I am not sure I understand this. With the top of the Ugnu at -3780', cement is only required to -3280 by the regulations. Thanks in advance. I look forward to your reply. Call or message with any questions. Tom Maunder, PE AOGCC 8/28/2008 1 • Eni Petroleum OP03- P05PB1 - Plug back procedure 1. 11H to desired depth with cement stinger. 2. Rig up cement line, Ensure well is static, It is recommended to use a side entry swivel and rotate the pipe at 10.20 rpm. Break circulation with the rig pumps, slowly ramp up the pumps to the maximum circulation rate with no losses, 3. Continue to circulate at max rate for at least 1.5x hole capacity. (This will circulate fluid at TD and ensure hole is circulated to uniform mud, making it easier to balance the plug as well as cooling the well to BHCT.) Condiction mud to lower Ty <30 for better mud removal. 4. Close Top Drive TtW valve. Open low torque valve on pump-in sub (prior to pumping with the cement unit op pu pump ng unit, pressure up to 1000 psi with the rig pumps through the Top Drive, against the Top Drive TIW valve, to ensure no fluid is pumped back into the Top Drive). 5. Break Circulation with Base Oil from the cement unit. 6. Close low torque valve and test lines to approx 1,000 psi over planned well head pressure, or maximum rated pressure of surface equipment. While pressure testing, monitor well for flow. Ensure there are no leaks, then bleed pressure off back to the cement unit. 7. Open low torque valve and finish pumping Base 00. Drop Foam wiper ball. Pump spacer as per pumping schedule with cement unit. 8. Shut down and clean the displacement tanks and flush the mixing lines on the cement unit. (Ensure the downhole valve on the cement unit is closed during this operation.) 9. Open the downhole valve. 10. Mix and pump cement slurry 11. Pump spacer behind at max rate to clear the cement from the lines. 12. Displace with mud and maintain pipe rotation. Ensure displacement pressure, flowrate, and volume are recorded. 14. Underdisplace by recommended volume. Note final pressure. If no pressure is observed, then begin to POOH, If pressure is observed in the line, bleed back to the displacement tank and allow plug to equalize. If excessive ttowback is observed, consider circulating the plug out and repeating the operation. 15. Shut down. POOH slowly to ±5,200' (< 30 ft/min, to minimize disturbance and avoid contamination of the plug) 16. Conventionally circulate clean, consider dropping a wiper ball to wipe the drill string and stinger (If pressure restrictions are low, reverse circulate 2x tubing volumes with the rig pumps or until clean returns are seen at surface). 17. Wait -On- Cement 390616 390615 355018 ENI I ENI BP OP03 -P05 • ,„. 29 BHL 27 1 a 0 „v.,. 2 I 34 .., . .. ,.........., ... N • . , ,.... . .. . . .. ... • ...... .... • ... . , .,.„,.. e . ,..,„ ..„...,,.......,..,.....,„.,..„,.,...... . „ , „ ... , .. '., p PB1 . 023 111r 381 X01 • (<1 * •re on -Phil L 6 4 355024 OP .• (Offs Conoc I -- r= -- _ r ---), , , bP 0 3 - PAS 5.-' ,46 L,() c M -77 S 21. c`a • • Ot N . .• . * . *. 411 ‘ 0 .44 t , i '''' 1, . . . ... • .-..el r dy . i , ' te f ". .tt ' ! t . ADL 355024 (Offshi , . * H 1 ADL 373301 • � II 4 ,. (Onshore) • 0, • Ow* OP03 -P -05 Surf Location '. l "' 11041011. I 1 38.94, -149 51 58.006 S. • . I 410.11 it. J ADL 355024 ilk. , ,•• (Offshore) \ . p .. , L,opy,rig, Protected Mat le, ,, Net SCAN INTO . i• t k -QCInL C • a ■ ,' Image © 2008 D*gitalGlobe ; 1# 281 ft "l► • 1 GOO SIC I s 4 4 . :30'39.453N , _ 149'51'38. W elev 0 ft Eye alt 969 It • OP 03 - POs 1 ,.ju Rf4 cc Loc4710A/ A i-EcT D 4 1. X7.02 TRANSMITTAL LETTER CHECKLIST WELL NAME A//,-4 /C-444.9 Or,5� -' r �� PTD# & ^ 3 7 /Development Service Exploratory Stratigraphic Test Non-Conventional Well ,,��� /day /Y�G4 PO OL: ! -� FIELD: /1, /Z.4 t'da d �� a Circle Appropriate Letter / Paragraphs to be Included in Transmittal Letter CHECK ADD -ONS WHAT (OPTIONS) TEXT FOR APPROVAL LETTER APPLIES MULTI LATERAL The permit is for a new wellbore segment of existing well (If last two digits in Permit No. , API No. 50- - - API number are between 60 -69) Production should continue to be reported as a function of the original API number stated above. PILOT HOLE In accordance with 20 AAC 25.005(0, all records, data and Togs acquired for the pilot hole must be clearly differentiated in both well name (r)? -953 Q(iS S PH) and API number (50- 0 $t - 335 to -1c) - Qv) from records, data and logs acquired for well .1e SPACING The permit is approved subject full compliance with 20 AAC EXCEPTION 25.055. Approval to perforate produce tOrpit4s contingent upon issuance of a conservation order approva a spacing ex . �yy'=' assumes the lability of any protest to the spacing exception that may occur. can /'dmti G4-$i �t Sat5 L ar ,'a DRY DITCH • V 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 1 program. Rev: 1/11/2008 WELL PERMIT CHECKLIST Field & Pool NIKAITCHUQ, UNDEFINED OIL - 561100 Well Name: NIKAiTCHUQ OP03 -P05 Program DEV Well bore seg ❑ PTD#: 2081370 Company ENI PETROLEUM Initial Class/Type DEV / PEND GeoArea leg Unit 11400 On/Off Shore On Annular Disposal ❑ Administration 1 Permit fee attached NA 2 Lease number appropriate No Surf in ADL 373301, wellbore_passes thru ADL 355024 and ADL 355023,_top of prod int & TD_in ADL 390615. _ 3 Unique well name and number Yes 4 Well located in a definedpool No NIKAITCHUQ, UNDEFINED OIL - 561100,_govemed_by statewide regulations 5 Well located proper distance from drilling unitboundary Yes A qualified "yes" here: primary target is the_Schrader Biuff_QA sand; however, _N sands will likely bear oil. i6 Well located proper distance from other wells Yes The Schrader Biuff_NA intercept Millie -125' from the exterior unit boundary. The approval letter will 7 Sufficient acreage available in_drilling unit Yes contain an appropriate_caution that a spacing exception will be needed toperf, test orproduce any reservoir 8 lfdeviated, is wellbore plat_included Yes closer than 500' from any property_line where ownership or landownership changes. 9 Operator only affected party Yes Unless perforating, testing orproducingfronr sands less than 500' from a_property line. 10 Operator has_appropriate bond in force Yes 11 Permit can be issued without co_nservation order Yes Unless perforating, testing orproducingfrom sands less than 500' from a property line. Appr Date 12 Perm itcan be issued without adrninistrative_approval Yes SFD 8/28/2008 13 Can permit _be approved before 15 -day wait Yes 14 Well located within area and_strata authorized by injection Order # (put IO# in comments) (For NA 15 All weiis_within 1/4 mile area of review identified (For service well only) NA 16 Pre- produced injector; duration_of pre -production less than 3 months (For service well only) _ _ NA 17 Nonconven, gas_conforrns to A$31,05.030(1.1.A),(j.2.A -0) NA Engineering 18 Conductor string provided Yes 19 Surfac_e_casingprotects all_known USDWs Yes 20 CMT vol adequate to circulate_on conductor& surf csg Yes 21 CMT_vol adequate to tie -in long string to surf csg NA 22 CMT_wiil cover all known_ productive horizons Yes 23 Casing designs adequate for C, T B & permafrost Yes 24 Adequate tankage_or reserve pit Yes Rig equipped with steel pits, Noreserve pit planned._ Alt waste_to approved disposal well(s). 25 its re -drill, has_) 10-403 for abandonment been approved NA 26 Adequate wellbore separation proposed Yes Proximity analysis performed. Traveling cylinder path calculated, Gyros possible in shallow surface hole. 27 if_diverter required, does it meet regulations Yes Appr Date 28 Drilling fluid program schematic & equip list adequate Yes Maximum expected formation pressure 8.7 EMW. MW planned up to 9,2_ppg. TEM 8/29/2008 29 BOPEs,_do theymeet regulation Yes k/ /‘ 30 BQPE_press rating appropriate; test to_(put psig in comments) Yes MASP calculated at 1256 psi. 5000_psi_cmrn oissioning test_planned_followed by_ 3_500 psi tests. IIIIk T ly 31 Choke_manifold compiiesw /API_ RP -53 (May 84) Yes 32 Work will occur without operation shutdown Yes 33 is presence of H2S gas probable No H2S is no known in SS. _ Rig equipped with sensors and alarms. 34 Mechanical condition of wells within AOR verified (For service well only) NA Geology 35 Permit can be issued wlo hydrogen_ sulfide measures Yes None expected in this new reservoir, H2S detectors will be utilized. 36 Data_ presented on potential overpressure zones Yes Norrnal_gradient expected_based_on nearby wells Oliktok 1 -1 & 1 -2. Appr Date 37 Seismic analysis of shallow gas_z_ones NA SFD 8/28/2008 38 Seabed condition survey_(if off - shore) NA 39 Contact name /phone for weekiy_p_rogress reports [exploratory only) NA Geologic Engineering Publ' Commissioner: Date: Commissioner: Date Co„ •,,0•ner Date 9a iii ,..,, _ o ff r
